UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 6-K

REPORT OF FOREIGN PRIVATE ISSUER PURSUANT TO RULE 13A-16 OR 15D-16 UNDER THE

SECURITIES EXCHANGE ACT OF 1934

For the month of March, 2019

Commission File Number 32297

CPFL Energy Incorporated

(Translation of Registrant's name into English)

Rodovia Engenheiro Miguel Noel Nascentes Burnier, km 2,5, parte
CEP 13088-140 - Parque São Quirino, Campinas - SP
Federative Republic of Brazil

(Address of principal executive office)

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

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1): [ ]

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7): [ ]

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____

If "Yes" is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b): 82-_________________

Campinas, March 28, 2019 – CPFL Energia S.A. (B3: CPFE3 and NYSE: CPL), announces its4Q18/2018 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 4Q17/2017, unless otherwise stated.

CPFL ENERGIA ANNOUNCES ITS 2018 RESULTS

Indicators (R$ Million)	4Q18	4Q17	Var.	2018	2017	Var.
Sales within the Concession Area - GWh	17,026	16,827	1.2%	67,213	65,576	2.5%
Captive Market	11,512	11,464	0.4%	45,589	45,358	0.5%
Free Client	5,513	5,363	2.8%	21,624	20,218	7.0%
Gross Operating Revenue	10,314	11,093	-7.0%	42,626	40,053	6.4%
Net Operating Revenue	6,686	7,460	-10.4%	28,137	26,745	5.2%
EBITDA⁽¹⁾	1,354	1,366	-0.9%	5,637	4,864	15.9%
Net Income	670	498	34.7%	2,166	1,243	74.2%
Investments⁽²⁾	693	694	-0.1%	2,066	2,617	-21.0%

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 investments related to the transmission segment; according to the requirements of IFRIC 15, it was recorded as “Contractual Asset of Transmission Companies” (in other credits). Does not include special obligations.

2018 HIGHLIGHTS

• Increase of2.5% in sales within the concession area, highlighting the growths of the residential (+2.6%) and industrial (+2.6%) classes;

• Growth of15.9% in EBITDAand of74.2% in Net Income;

• Net debt ofR$ 16.3 billionand leverage of3.05x Net Debt/EBITDA;

• Investments ofR$ 693 millionin4Q18and ofR$ 2,066 millionin2018;

• Tariff Revisions: CPFL Paulista andRGE Sul, in Apr/18, andRGE, in Jun/18;

• Grouping of the concessions of the distribution companiesRGEandRGE Sul;

• CPFL Renováveis: (i) winning projects in the A-6 Auction (Aug-18) -Cherobim SHPP (28.0 MW) andGameleira Wind Complex (69.3 MW); and (ii) anticipation of commercial start-up ofBoa Vista II SHPP (29.9 MW), in Nov-18;

• Transmission Auctions: CPFL Geraçãowon one lot in Jun-18 (CE - Investment estimated by ANEEL: R$ 102 MM) and two lots in Dec-18 (SC - Invest.: R$ 366 MM and RS - Invest.: R$ 349 MM);

• CPFL Renováveis’ Mandatory Tender Offer: auction occurred on Nov 26, 2018; State Grid (directly and indirectly) now holds 99.94% of the shares.

4Q18/2018 Results | March 28, 2019

INDEX


1) MESSAGE FROM THE CEO	4

2) ENERGY SALES	6
2.1) Sales within the Distributors Concession Area	6
2.1.1) Sales by Segment Concession Area	7
2.1.2) Sales to the Captive Market	8
2.1.3) Free Clients	8
2.2) Generation Installed Capacity	9

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
3.4) Consolidation of Transmission Companies	12

4) ECONOMIC-FINANCIAL PERFORMANCE	13
4.1) Opening of economic-financial performance by business segment	13
4.2) Sectoral Financial Assets and Liabilities	14
4.3) Operating Revenue	14
4.4) Cost of Electric Energy	15
4.5) Operating Costs and Expenses	17
4.6) EBITDA	19
4.7) Financial Result	20
4.8) Net Income	22

5) INDEBTEDNESS	23
5.1) Debt (IFRS)	23
5.1.1) Debt Amortization Schedule in IFRS (Dec-18)	24
5.2) Debt in Financial Covenants Criteria	25
5.2.1) Indexation and Debt Cost in Financial Covenants Criteria	25
5.2.2) Net Debt in Financial Covenants Criteria and Leverage	26

6) INVESTMENTS	26
6.1) Actual Investments	26
6.2) Investments Forecasts	27

7) ALLOCATION OF RESULTS	28

8) STOCK MARKETS	28
8.1) Stock Performance	28
8.2) Daily Average Volume	29

9) CORPORATE GOVERNANCE	30

10) SHAREHOLDERS STRUCTURE	31
10.1) CPFL Renováveis Tender Offer	31
10.2) Merger of RGE and RGE Sul distribution companies	31

11) PERFORMANCE OF THE BUSINESS SEGMENTS	33
11.1) Distribution Segment	33
11.1.1) Economic-Financial Performance	33
11.1.1.1) Sectoral Financial Assets and Liabilities	33
11.1.1.2) Operating Revenue	34
11.1.1.3) Cost of Electric Energy	36

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11.1.1.4) Operating Costs and Expenses	37
11.1.1.5) EBITDA	39
11.1.1.6) Financial Result	40
11.1.1.7) Net Income	42
11.1.2) Tariff Events	42
11.1.3) Operating Performance of Distribution	44
11.2) Commercialization and Services Segments	45
11.2.1) Commercialization Segment	45
11.2.2) Services Segment	46
11.3) Conventional Generation Segment	47
11.3.1) Economic-Financial Performance	47
11.3.1.1) Operating Revenue	47
11.3.1.2) Cost of Electric Power	48
11.3.1.3) Operating Costs and Expenses	48
11.3.1.4) Equity Income	50
11.3.1.5) EBITDA	51
11.3.1.6) Financial Result	51
11.3.1.7) Net Income	53
11.4) CPFL Renováveis	53
11.4.1) Economic-Financial Performance	53
11.4.1.1) Operating Revenue	53
11.4.1.2) Cost of Electric Power	54
11.4.1.3) Operating Costs and Expenses	55
11.4.1.4) EBITDA	56
11.4.1.5) Financial Result	56
11.4.1.6) Net Income	57
11.4.2) Status of Generation Projects 100% Participation	57

12) ATTACHMENTS	59
12.1) Statement of Assets CPFL Energia	59
12.2) Statement of Liabilities CPFL Energia	60
12.3) Income Statement CPFL Energia	61
12.4) Cash Flow CPFL Energia	62
12.5) Income Statement Conventional Generation Segment	63
12.6) Income Statement CPFL Renováveis	64
12.7) Income Statement Distribution Segment	65
12.8) Economic-Financial Performance by Distributor	66
12.9) Sales within the Concession Area by Distributor (In GWh)	67
12.10) Sales to the Captive Market by Distributor (in GWh)	68
12.11) Reconciliation of Net Debt/EBITDA Pro Forma ratio of CPFL Energia for purposes of financial
covenants calculation	69

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1) MESSAGE FROM THE CEO

The CPFL group continued to be very active in 2018, promoting improvements in its operations and management, as well as following the unfolding of the political and economic scenarios of Brazil in its markets.

The 2018 results reflected the growth of energy sales in all consumption classes, our discipline in cost and expense management, as well as the drop in interest rates in Brazil.

The distribution segment had an increase in energy sales (+2.5%) in 2018. Residential, industrial and commercial classes registered market variations of 2.6%, 2.8% and 1.2%, respectively, reflecting the slow recovery of economy activity.

CPFL group’s operating cash generation, measured by EBITDA, reached R$ 5,643 million in 2018 (+15.9%), reflecting the positive results of all business segments. We highlight the distribution segment, whose EBITDA reached R$ 3,004 million in 2018 (+34.5%), mainly reflecting the results coming from the conclusion of the tariff revision process (4^th cycle) of CPFL Paulista, RGE Sul (both in April 2018) and RGE (in June 2018). In addition, the Company is promoting organizational reviews in order to simplify its processes and structure, aiming at greater efficiency and focus on business.

We continue working on value initiatives and in our investment plan in 2018, with financial discipline, efforts and commitment of our teams. We invested R$ 2,066 million in this period.

Among the value initiatives, it is worth mentioning the participation of CPFL Geração in the following transmission auctions: (i) in June 2018, the company won Lot 9 (Maracanaú II substation), in Ceará, and (ii) in December 2018, the company won Lots 5 (Itá substation), in Santa Catarina, and 11 (Osório 3, Porto Alegre 1 and Vila Maria substations), in Rio Grande do Sul.

We also had the creation of CPFL Soluções, which brings together services and products previously offered under the brands CPFL Brasil, CPFL Serviços and CPFL Eficiência. In this way, we have an integrated platform for interaction with customers seeking solutions for energy trading, energy efficiency, distributed generation, energy infrastructure and consulting services.

It should also be noted that CPFL promoted the merger of the distribution company RGE (“Merged Company”) into RGE Sul (“Mergee Company”). The grouping of the concessions of the two companies was carried out through the merger of the assets held by the Merged Company by the Mergee Company on December 31, 2018.

We also had the startup of the Boa Vista II SHPP (installed capacity of 29.9 MW), in November 2018, and the participation of CPFL Renováveis in the A-6 Auction of August 2018. The company won with the following projects: (i) Cherobim SHPP, with 28.0 MW of installed capacity, located in Paraná state, and (ii) Gameleira Wind Complex, with 69.3 MW of installed capacity, located in Rio Grande do Norte state.

Still in relation to CPFL Renováveis, we had the Mandatory Tender Offer of the company on November 26. As a result of the auction, State Grid acquired 243,771,824 common shares issued by the company, representing 48.39% of the capital stock of the company. The common shares were acquired at the price of R$ 16.85, totaling the amount of R$ 4.1 billion. State Grid and CPFL Geração (indirectly controlled by State Grid) jointly held 503,520,623 common shares issued by the company, equivalent to 99.94% of the total share capital of the company.

CPFL Energia’s capital structure and consolidated leverage remained at adequate levels. The Company’s net debt reached 3.05 times EBITDA at the end of the quarter, under the criteria to measure our financial covenants, lower than in the previous year. It is worth mentioning that the reductions in interest rates benefited the Company.

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Finally, CPFL’s management remains optimistic about the advances of the Brazilian electricity sector and remains confident in its business platform, which is increasingly prepared and well positioned to face the challenges and opportunities in the country.

Gustavo Estrella

CEO of CPFL Energia

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2) ENERGY SALES

2.1) Sales within the Distributors’ Concession Area

Sales within the Concession Area - GWh
	4Q18	4Q17	Var.	2018	2017	Var.
Captive Market	11,512	11,464	0.4%	45,589	45,358	0.5%
Free Client	5,513	5,363	2.8%	21,624	20,218	7.0%
Total	17,026	16,827	1.2%	67,213	65,576	2.5%

In 4Q18, sales within the concession area, achieved by the distribution segment, totaled 17,026 GWh, an increase of 1.2%. Sales to the captive market totaled 11,512 GWh in 4Q18, an increase of 0.4%. The quantity of energy, in GWh, which corresponds to the consumption of free clients in the concession area of group’s distributors, billed through the Tariff for the Usage of the Distribution System (TUSD), reached 5,513 GWh in 4Q18, an increase of 2.8%.

In 2018, sales within the concession area totaled 67,213 GWh, an increase of 2.5%. Sales to the captive market totaled 45,589 GWh in 2018, an increase of 0.5%. The quantity of energy billed through TUSD reached 21,624 GWh in 2018, an increase of 7.0%.

Sales within the Concession Area - GWh
	4Q18	4Q17	Var.	Part.	2018	2017	Var.	Part.
Residential	4,970	4,866	2.2%	29.2%	19,618	19,122	2.6%	29.2%
Industrial	6,371	6,316	0.9%	37.4%	25,023	24,346	2.8%	37.2%
Commercial	2,841	2,820	0.7%	16.7%	11,048	10,921	1.2%	16.4%
Others	2,844	2,826	0.6%	16.7%	11,524	11,187	3.0%	17.1%
Total	17,026	16,827	1.2%	100.0%	67,213	65,576	2.5%	100.0%

Note: The tables with sales within the concession area by distributor are attached to this report in item 12.9.

Noteworthy in 4Q18, in the concession area:

· Residential and commercial classes (29.2% and 16.7% of total sales, respectively): increases of 2.2% and 0.7%, respectively. Highlights for RGE (+4.3%) and CPFL Santa Cruz (+2.2%). In New RGE, the effect of the temperature contributed to the growth of consumption.

· Industrial class (37.4% of total sales): increase of 0.9%. Highlight for the growths in CPFL Santa Cruz (+12.5%) and RGE (+3.2%).

Noteworthy in 2018, in the concession area:

· Residential and commercial classes (29.2% and 16.4% of total sales, respectively): increases 2.6% and 1.2%, respectively. One-off effects of temperature increased consumption in some months of the year, contributing to the growth of sales in 2018.

· Industrial class (37.2% of total sales):increase of 2.8%. Highlight for the growths in CPFL Piratininga (+4.0%), RGE (+3.1%) and CPFL Santa Cruz (+7.6%). This positive result come from the performance of the main industrial activities in the concession area of CPFL Energia (chemicals, automotive vehicles, coke and derived petroleum products and metallurgy).

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2.1.1) Sales by Segment – Concession Area

Note: in parentheses, the variation in percentage points from 4Q17/2017 to 4Q18/2018.

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2.1.2) Sales to the Captive Market

Sales to the Captive Market - GWh
	4Q18	4Q17	Var.	2018	2017	Var.
Residential	4,970	4,866	2.2%	19,618	19,122	2.6%
Industrial	1,561	1,618	-3.5%	6,151	6,557	-6.2%
Commercial	2,217	2,244	-1.2%	8,630	8,828	-2.2%
Others	2,763	2,736	1.0%	11,190	10,852	3.1%
Total	11,512	11,464	0.4%	45,589	45,358	0.5%

Note: The tables with captive market sales by distributor are attached to this report in item 12.10.

Sales to the captive market totaled 11,512 GWh in 4Q18, an increase of 0.4% (48 GWh), mainly due to the performance of the residential class (+2.2%); the performance of industrial (-3.5%) and commercial (-1.2%) classes, reflects the migration of customers to the free market.

In 2018, sales to the captive market totaled 45,589 GWh, an increase of 0.5% (231 GWh), mainly due to the performance of the residential class (+2.6%); the performance of industrial (-6.2%) and commercial (-2.2%) classes, also reflects the migration of customers to the free market.

2.1.3) Free Clients

Free Client - GWh
	4Q18	4Q17	Var.	2018	2017	Var.
Industrial	4,809	4,698	2.4%	18,872	17,789	6.1%
Commercial	624	576	8.3%	2,418	2,093	15.5%
Others	80	90	-10.4%	334	335	-0.4%
Total	5,513	5,363	2.8%	21,624	20,218	7.0%

Free Client by Distributor - GWh
	4Q18	4Q17	Var.	2018	2017	Var.
CPFL Paulista	2,593	2,554	1.5%	10,027	9,504	5.5%
CPFL Piratininga	1,548	1,535	0.8%	6,255	5,809	7.7%
New RGE	1,205	1,133	6.3%	4,724	4,396	7.5%
CPFL Santa Cruz	168	141	18.8%	619	509	21.5%
Total	5,513	5,363	2.8%	21,624	20,218	7.0%

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2.2) Generation Installed Capacity

In 4Q18, the Generation installed capacity of CPFL Energia group, considering the proportional stake in each project, is of 3,272 MW.

Note: Take into account CPFL Energia’s 51.56% stake in CPFL Renováveis.

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3) INFORMATION ON INTEREST IN COMPANIES AND CRITERIA OF FINANCIAL STATEMENTS CONSOLIDATION

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 December 31, 2018 and 2017, the participation of non-controlling interests stated in the consolidated statements refers to the third-party interests in the subsidiaries CERAN, Paulista Lajeado and CPFL Renováveis.

Since November 1^st, 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 (in thousands)	Concession term	End of the concession
Companhia Paulista de Força e Luz ("CPFL Paulista")	Publicly-quoted corporation	Direct 100%	Countryside of São Paulo	234	4,496	30 years	November 2027
Companhia Piratininga de Força e Luz ("CPFL Piratininga")	Publicly-quoted corporation	Direct 100%	Countryside and seaside of São Paulo	27	1,756	30 years	October 2028
RGE Sul Distribuidora de Energia S.A. ("RGE") (a)	Publicly-quoted corporation	Direct and Indirect 100%	Countryside of Rio Grande do Sul	381	2,871	30 years	November 2027
Companhia Jaguari de Energia ("CPFL Santa Cruz") (b)	Private corporation	Direct 100%	Countryside of São Paulo, Paraná and Minas Gerais	45	457	30 years	July 2045

Energy generation (conventional and renewable sources)	Company Type	Equity Interest	Location (State)	Number of plants / type of energy	Installed capacity
Energy generation (conventional and renewable sources)	Company Type	Equity Interest	Location (State)	Number of plants / type of energy	Total	CPFL participation
CPFL Geração de Energia S.A. ("CPFL Geração")	Publicly-quoted corporation	Direct 100%	São Paulo and Goiás	3 Hydroelectric (c)	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")	Private corporation	Indirect 51% (d)	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 Thermoelectric	342	182
Paulista Lajeado Energia S.A. ("Paulista Lajeado")	Private corporation	Indirect 59.93% (e)	Tocantins	1 Hydroelectric	903	38
CPFL Energias Renováveis S.A. ("CPFL Renováveis")	Publicly-quoted corporation	Indirect 51.56%	See chapter 11.4.2	See chapter 11.4.2	See chapter 11.4.2	See chapter 11.4.2
CPFL Centrais Geradoras Ltda. ("CPFL Centrais Geradoras")	Limited company	Direct 100%	São Paulo and Minas Gerais	6 MHPPs	4	4
Transmission	Company Type		Core activity		Equity Interest
CPFL Transmissão Piracicaba S.A. ("CPFL Piracicaba")	Private corporation		Electric energy transmission services		Indirect 100%
CPFL Transmissão Morro Agudo S.A. ("CPFL Morro Agudo")	Private corporation		Electric energy transmission services		Indirect 100%
CPFL Transmissão Maracanaú S.A. ("CPFL Maracanaú")	Privately-held corporation		Electric energy transmission services		Indirect 100%

Notes:

(a) On December 31, 2018, was approved the grouping of the concessions of the distribution companies RGE Sul Distribuidora de Energia S.A. (“RGE Sul”) and Rio Grande Energia S.A. (“RGE”), considering RGE Sul as the Merging Company and RGE as the Merged Company;

(b) On December 31, 2017, was approved the merger of the subsidiaries Companhia Luz e Força Santa Cruz, Companhia Leste Paulista de Energia, Companhia Sul Paulista de Energia and Companhia Luz e Força de Mococa into Companhia Jaguari de Energia, whose fancy name became "CPFL Santa Cruz”;

(c) CPFL Geração holds 51.54% of the assured power and power of the Serra da Mesa HPP, whose concession belongs to Furnas. The Cariobinha HPP and the Carioba TPP projects are deactivated pending the position of the Ministry of Mines and Energy on the anticipated closure of its concession and are not included in the table;

(d) The joint venture Chapecoense fully consolidates the interim financial statements of its direct subsidiary, Foz de Chapecó;

(e) Paulista Lajeado has a 7% participation in the installed power of Investco S.A. (5.94% share of its capital).

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Energy commercialization	Company Type	Core activity	Equity Interest
CPFL Comercialização Brasil S.A. ("CPFL Brasil")	Private corporation	Energy commercialization	Direct 100%
Clion Assessoria e Comercialização de Energia Elétrica Ltda. ("CPFL Meridional")	Limited company	Commercialization and provision of energy services	Indirect 100%
CPFL Comercialização Cone Sul S.A. ("CPFL Cone Sul")	Private corporation	Energy commercialization	Indirect 100%
CPFL Planalto Ltda. ("CPFL Planalto")	Limited company	Energy commercialization	Direct 100%
CPFL Brasil Varejista S.A. ("CPFL Brasil Varejista")	Private corporation	Energy commercialization	Indirect 100%

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 100%
NECT Serviços Administrativos Ltda. ("Nect")	Limited company	Provision of administrative services	Direct 100%
CPFL Atende Centro de Contatos e Atendimento Ltda. ("CPFL Atende")	Limited company	Provision of telephone answering services	Direct 100%
CPFL Total Serviços Administrativos Ltda. ("CPFL Total")	Limited company	Billing and collection services	Direct 100%
CPFL Eficiência Energética S.A. ("CPFL Eficiência")	Private corporation	Management in Energy Efficiency	Direct 100%
TI Nect Serviços de Informática Ltda. ("Authi")	Limited company	IT services	Direct 100%
CPFL GD S.A. ("CPFL GD")	Private corporation	Electric energy generation services	Indirect 100%

Others	Company Type	Core activity	Equity Interest
CPFL Jaguari de Geração de Energia Ltda. ("Jaguari Geração")	Limited company	Venture capital company	Direct 100%
Chapecoense Geração S.A. ("Chapecoense")	Private corporation	Venture capital company	Indirect 51%
Sul Geradora Participações S.A. ("Sul Geradora")	Private corporation	Venture capital company	Indirect 99.95%
CPFL Telecom S.A. ("CPFL Telecom")	Private corporation	Telecommunication services	Direct 100%

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3.1) Consolidation of CPFL Renováveis Financial Statements

On December 31, 2018, CPFL Energia indirectly held 51.56% 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 December 31, 2018, CPFL Energia held the following stake in the capital stock of RGE Sul: 89,0107%, directly, and 10,9893%, indirectly, through CPFL Brasil. RGE Sul has been fully consolidated (100%, line by line), in CPFL Energia’s financial statements since November 1^st, 2016.

3.3) Economic-Financial Performance Presentation

In accordance with U.S. SEC (Securities and Exchange Commission) guidelines and pursuant to items 100(a) and (b) of Regulation G, with the disclosure of 4Q16/2016 results, in order to avoid the disclosure of non-GAAP measures, we no longer disclose the economic-financial performance considering the proportional consolidation of the generation projects and the adjustment of the numbers for non-recurring items, focusing the disclosure in the IFRS criterion. Only in chapter 5, of Indebtedness, we continue presenting the information in the financial covenants criterion, considering that the proper reconciliation with the numbers in the IFRS criterion are presented in item 12.11 of this report.

3.4) Consolidation of Transmission Companies

As of 4Q17, the subsidiaries CPFL Transmissão Piracicaba and CPFL Transmissão Morro Agudo are consolidated in the financial statements of the segment "Conventional Generation".

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4) ECONOMIC-FINANCIAL PERFORMANCE

Consolidated Income Statement - CPFL ENERGIA (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Gross Operating Revenue	10,314	11,093	-7.0%	42,626	40,053	6.4%
Net Operating Revenue	6,686	7,460	-10.4%	28,137	26,745	5.2%
Cost of Electric Power	(3,885)	(4,696)	-17.3%	(17,838)	(16,902)	5.5%
Operating Costs & Expenses	(1,943)	(1,844)	5.4%	(6,590)	(6,822)	-3.4%
EBIT	858	920	-6.7%	3,708	3,022	22.7%
EBITDA¹	1,354	1,366	-0.9%	5,637	4,864	15.9%
Financial Income (Expense)	(271)	(290)	-6.7%	(1,103)	(1,488)	-25.9%
Income Before Taxes	681	689	-1.3%	2,940	1,847	59.2%
Net Income	670	498	34.7%	2,166	1,243	74.2%

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.

4.1) Opening of economic-financial performance by business segment

Income Statement by business segment - CPFL Energia (R$ million)
	Distribution	Conventional Generation	Renewable Generation	Commerciali-zation	Services	Others	Eliminations	Total
4Q18
Net operating revenue	5,160	285	516	963	153	-	(391)	�� 6,686
Operating costs and expenses	(4,434)	(66)	(218)	(948)	(137)	(13)	391	(5,426)
Depreciation e amortization	(196)	(29)	(155)	(1)	(6)	(16)	-	(402)
Income from electric energy service	530	190	143	14	10	(29)	-	858
Equity accounting	-	93	-	-	-	-	-	93
EBITDA	726	312	298	14	16	(13)	-	1,354
Financial result	(61)	(43)	(129)	0	1	(38)	-	(271)
Income (loss) before taxes	469	240	14	14	11	(67)	-	681
Income tax and social contribution	42	(5)	93	(4)	(14)	(122)	-	(10)
Net income (loss)	511	234	107	10	(3)	(189)	-	670


4Q17
Net operating revenue	5,750	295	591	1,044	140	0	(360)	7,460
Operating costs and expenses	(5,082)	(80)	(237)	(991)	(113)	(11)	360	(6,153)
Depreciation e amortization	(179)	(30)	(155)	(1)	(5)	(16)	-	(387)
Income from electric energy service	489	185	199	53	21	(27)	-	920
Equity accounting	-	60	-	-	-	-	-	60
EBITDA	668	275	354	53	27	(11)	0	1,366
Financial result	(88)	(63)	(124)	(8)	2	(9)	(0)	(290)
Income (loss) before taxes	401	181	75	45	23	(36)	-	689
Income tax and social contribution	(64)	4	(24)	(15)	(6)	(87)	-	(192)
Net income (loss)	337	185	51	29	17	(123)	-	498

Variation
Net operating revenue	-10.2%	-3.4%	-12.7%	-7.8%	9.7%	-100.0%	8.6%	-10.4%
Operating costs and expenses	-12.7%	-16.7%	-8.1%	-4.3%	21.4%	20.4%	8.6%	-11.8%
Depreciation e amortization	9.5%	-4.6%	-0.2%	-14.5%	6.0%	0.0%	-	4.0%
Income from electric energy service	8.5%	2.5%	-28.0%	-73.7%	-51.7%	8.4%	-	-6.7%
Equity accounting	-	56.2%	-	-	-	-	-	56.2%
EBITDA	8.7%	13.4%	-15.8%	-73.0%	-40.0%	20.4%	-100.0%	-0.9%
Financial result	-30.5%	-31.7%	4.7%	-	-73.8%	312.7%	-100.0%	-6.7%
Income (loss) before taxes	16.9%	32.2%	-81.6%	-68.4%	-53.6%	85.7%	-	-1.3%
Income tax and social contribution	-	-	-	-74.0%	128.9%	41.3%	-	-94.5%
Net income (loss)	51.8%	26.4%	108.4%	-65.5%	-	54.3%	-	34.7%

Note: an analysis of the economic-financial performance by business segment is presented in chapter 11.

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Income Statement by business segment - CPFL Energia (R$ million)
	Distribution	Conventional Generation	Renewable Generation	Commerciali-zation	Services	Others	Eliminations	Total
2018
Net operating revenue	22,467	1,144	1,936	3,496	533	-	(1,441)	28,137
Operating costs and expenses	(19,463)	(207)	(728)	(3,400)	(438)	(39)	1,441	(22,834)
Depreciation e amortization	(767)	(116)	(623)	(2)	(23)	(63)	-	(1,594)
Income from electric energy service	2,237	821	586	94	73	(102)	-	3,708
Equity accounting	-	334	-	-	-	-	-	334
EBITDA	3,004	1,272	1,209	96	95	(39)	-	5,637
Financial result	(310)	(248)	(504)	(13)	(0)	(27)	-	(1,103)
Income (loss) before taxes	1,928	907	82	81	72	(129)	-	2,940
Income tax and social contribution	(495)	(137)	37	(28)	(30)	(122)	-	(774)
Net income (loss)	1,432	770	119	53	43	(251)	-	2,166


2017
Net operating revenue	21,077	1,190	1,959	3,414	486	1	(1,382)	26,745
Operating costs and expenses	(18,842)	(304)	(737)	(3,243)	(398)	(51)	1,382	(22,194)
Depreciation e amortization	(704)	(121)	(617)	(3)	(20)	(65)	-	(1,529)
Income from electric energy service	1,531	766	605	168	68	(115)	-	3,022
Equity accounting	-	312	-	-	-	-	-	312
EBITDA	2,234	1,200	1,222	171	87	(50)	-	4,864
Financial result	(566)	(329)	(511)	(33)	4	(53)	-	(1,488)
Income (loss) before taxes	964	750	94	135	72	(168)	-	1,847
Income tax and social contribution	(300)	(96)	(74)	(45)	(17)	(73)	-	(604)
Net income (loss)	665	654	20	90	55	(241)	-	1,243

Variation
Net operating revenue	6.6%	-3.9%	-1.2%	2.4%	9.7%	-100.0%	4.2%	5.2%
Operating costs and expenses	3.3%	-31.8%	-1.3%	4.8%	9.9%	-23.1%	4.2%	2.9%
Depreciation e amortization	9.0%	-3.5%	1.0%	-23.2%	14.0%	-3.3%	-	4.3%
Income from electric energy service	46.2%	7.2%	-3.1%	-43.9%	7.4%	-11.0%	-	22.7%
Equity accounting	-	7.0%	-	-	-	-	-	7.0%
EBITDA	34.5%	6.1%	-1.1%	-43.5%	8.9%	-21.1%	-	15.9%
Financial result	-45.3%	-24.4%	-1.3%	-60.4%	-	-48.6%	-	-25.9%
Income (loss) before taxes	99.9%	21.0%	-13.1%	-39.9%	0.8%	-22.9%	-	59.2%
Income tax and social contribution	65.3%	43.3%	-	-37.2%	73.8%	67.0%	-	28.2%
Net income (loss)	115.5%	17.7%	504.2%	-41.2%	-21.7%	4.3%	-	74.2%

Note: an analysis of the economic-financial performance by business segment is presented in chapter 11.

4.2) Sectoral Financial Assets and Liabilities

In 4Q18, it was accounted the totalsectoral financial liabilities in the amount of R$ 735 million, compared to the totalsectoral financial assets in the amount of R$ 852 million in 4Q17, a variation of R$ 1,586 million. In 2018, it was accounted the totalsectoral financial assets in the amount of R$ 1,208 million, compared to the totalsectoral financial assets in the amount of R$ 1,901 million in 2017, a reduction of 36.5% (R$ 693 million).

On December 31, 2018, the balance of these sectoral financial assets and liabilities was positive in R$ 1,508 million, compared to a positive balance of R$ 2,207 million on September 30, 2018 and a positive balance of R$ 517 million on December 31, 2017.

As established by the applicable regulation, any sectoral financial assets or liabilities shall be included in the tariffs of the distributors in their respective annual tariff events.

4.3) Operating Revenue

In 4Q18, gross operating revenue reached R$ 10,314 million, representing a reduction of 7.0% (R$ 780 million). Deductions from the gross operating revenue was of R$ 3,627 million in 4Q18, representing a reduction of 0.2% (R$ 7 million). Net operating revenue reached R$ 6,686 million in 4Q18, registering a reduction of 10.4% (R$ 773 million).

The main factors that affected the net operating revenue were:

· Reduction of revenues in the Distribution segment, in the amount of R$ 589 million (for more details, see item 11.1.1.2);

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· Reduction of revenues in the Commercialization segment, in the amount of R$ 81 million;

· Reduction of revenues in the Renewable Generation segment, in the amount of R$ 75 million;

· Reduction of R$ 31 million, due to eliminations;

· Reduction of revenues in the Conventional Generation segment, in the amount of R$ 10 million;

Partially offset by:

· Increase of revenues in the Services segment, in the amount of R$ 14 million.

In 2018, gross operating revenue reached R$ 42,626 million, representing an increase of 6.4% (R$ 2,573 million). Deductions from the gross operating revenue was of R$ 14,490 million in 2018, representing an increase of 8.9% (R$ 1,181 million). Net operating revenue reached R$ 28,137 million in 2018, registering an increase of 5.2% (R$ 1,392 million).

The main factors that affected the net operating revenue were:

· Increase of revenues in the Distribution segment, in the amount of R$ 1,391 million (for more details, see item 11.1.1.2);

· Increase of revenues in the Commercialization segment, in the amount of R$ 82 million;

· Increase of revenues in the Services segment, in the amount of R$ 47 million;

Partially offset by:

· Reduction of R$ 59 million, due to eliminations;

· Reduction of revenues in the Conventional Generation segment, in the amount of R$ 46 million;

· Reduction of revenues in the Renewable Generation segment, in the amount of R$ 23 million;

· Reduction of revenues in Others, in the amount of R$ 1 million.

4.4) Cost of Electric Energy

Cost of Electric Energy (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Cost of Electric Power Purchased for Resale
Energy from Itaipu Binacional	643	587	9.6%	2,668	2,351	13.5%
PROINFA	81	77	5.0%	331	293	12.8%
Energy Purchased through Auction in the Regulated Environment, Bilateral Contracts and Energy Purchased in the Spot Market	2,893	4,071	-28.9%	13,970	14,536	-3.9%
PIS and COFINS Tax Credit	(317)	(428)	-26.1%	(1,503)	(1,563)	-3.8%
Total	3,300	4,306	-23.4%	15,466	15,617	-1.0%

Charges for the Use of the Transmission and Distribution System
Basic Network Charges	485	554	-12.5%	2,115	1,542	37.2%
Itaipu Transmission Charges	68	63	7.5%	266	160	66.5%
Connection Charges	47	32	46.7%	163	123	32.9%
Charges for the Use of the Distribution System	14	10	43.5%	49	39	23.7%
System Service Usage Charges - ESS	32	(229)	-	(106)	(453)	-76.6%
Reserve Energy Charges - EER	(0)	(0)	-48.6%	135	(0)	-
PIS and COFINS Tax Credit	(60)	(39)	54.9%	(249)	(126)	97.6%
Total	585	390	49.9%	2,372	1,284	84.7%

Cost of Electric Energy	3,885	4,696	-17.3%	17,838	16,902	5.5%

In 4Q18, 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$ 3,885 million, registering areduction of 17.3% (R$ 811 million).

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The factors that explain these variations follow below:

· The cost of electric power purchased for resale reached R$ 3,300 million in 4Q18, a reduction of 23.4% (R$ 1,006 million), due to the following factors:

(i) Reduction of 28.9% (R$ 1,178 million) in the cost of energy purchased through auction in the regulated environment, bilateral contracts and energy purchased in the spot market, due to the reductions of 28.2% in the average purchase price (R$ 181.72/MWh in 4Q18 vs. R$ 253.02/MWh in 4Q17) and of 1.1% (170 GWh) in the volume of purchased energy;

Partially offset by:

(ii) Reduction of 26.1% (R$ 112 million) in PIS and COFINS tax credits (cost reducer), generated from the energy purchase;

(iii) Increase of 9.6% (R$ 56 million) in the cost of energy from Itaipu, due to the increase of 16.1% in the average purchase price (R$ 229.13/MWh in 4Q18 vs. R$ 197.38/MWh in 4Q17), partially offset by the reduction of 5.6% (167 GWh) in the volume of purchased energy;

(iv) Increase of 5.0% (R$ 4 million) in the amount of PROINFA cost, due to the increase of 6.1% in the average purchase price (R$ 264.09/MWh in 4Q18 vs. R$ 248.90/MWh in 4Q17), partially offset by the reduction of 1.0% (3 GWh) in the volume of purchased energy;

· Charges for the use of the transmission and distribution system reached R$ 585 million in 4Q18, an increase of 49.9% (R$ 195 million), due to the following factors:

(i) Variation of R$ 261 million in the System Service Usage Charges – ESS, from a revenue of R$ 229 million in 4Q17 to an expense of R$ 32 million in 4Q18;

(ii) Increase of 46.7% (R$ 15 million) in charges for connection;

(iii) Increase of 7.5% (R$ 5 million) in Itaipu transmission charges;

(iv) Increase of 43.5% (R$ 4 million) in charges for usage of the distribution system;

Partially offset by:

(v) Reduction of 12.5% (R$ 69 million) in the basic network charges;

(vi) Increase of 54.9% (R$ 21 million) in PIS and COFINS tax credits (cost reducer), generated from the charges.

In 2018, 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$ 17,838 million, registering an increase of 5.5% (R$ 937 million).

The factors that explain these variations follow below:

· The cost of electric power purchased for resale reached R$ 15,466 million in 2018, a reduction of 1.0% (R$ 151 million), due to the following factors:

(i) Reduction of 3.9% (R$ 566 million) in the cost of energy purchased through auction in the regulated environment, bilateral contracts and energy purchased in the spot market, due to the reduction of 5.5% (3,592 GWh) in the volume of purchased energy, partially offset by the increase of 1.7% in the average purchase price (R$ 227.30/MWh in 2018 vs. R$ 223.45/MWh in 2017);

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Partially offset by:

(ii) Increase of 13.5% (R$ 317 million) in the cost of energy from Itaipu, due to the increase of 20.3% in the average purchase price (R$ 240.03/MWh in 2018 vs. R$ 199.58/MWh in 2017), partially offset by the reduction of 5.6% (662 GWh) in the volume of purchased energy;

(iii) Reduction of 3.8% (R$ 60 million) in PIS and COFINS tax credits (cost reducer), generated from the energy purchase;

(iv) Increase of 12.8% (R$ 37 million) in the amount of PROINFA cost, due to the increase of 15.9% in the average purchase price (R$ 297.52/MWh in 2018 vs. R$ 256.69/MWh in 2017), partially offset by the reduction of 2.7% (31 GWh) in the volume of purchased energy.

· Charges for the use of the transmission and distribution system reached R$ 2,372 million in 2018, an increase of 84.7% (R$ 1,088 million), due to the following factors:

(i) Increase of 37.2% (R$ 573 million) in the basic network charges;

(ii) Reduction of 76.6% (R$ 347 million) in the System Service Usage Charges – ESS (cost reducer), from a revenue of R$ 453 million in 2017 to a revenue of R$ 106 million in 2018;

(iii) Expense of R$ 135 million in 2018, related to Reserve Energy Charges – EER;

(iv) Increase of 66.5% (R$ 106 million) in Itaipu transmission charges;

(v) Increase of 32.9% (R$ 40 million) in charges for connection;

(vi) Increase of 23.7% (R$ 9 million) in charges for usage of the distribution system;

Partially offset by:

(vii) Increase of 97.6% (R$ 123 million) in PIS and COFINS tax credits (cost reducer), generated from the charges.

4.5) Operating Costs and Expenses

Operating costs and expenses reached R$ 1,943 million in 4Q18, compared to R$ 1,844 million in 4Q17, an increase of 5.4% (R$ 100 million). In 2018, operating costs and expenses reached R$ 6,590 million, compared to R$ 6,822 million in 2017, a reduction of 3.4% (R$ 232 million).

The factors that explain these variations follow below:

PMSO

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Reported PMSO (R$ million)
	4Q18	4Q17	Variation		2018	2017	Variação
	4Q18	4Q17	R$ MM	%	2018	2017	R$ MM	%
Reported PMSO
Personnel	(380)	(379)	(1)	0.4%	(1,414)	(1,377)	(37)	2.7%
Material	(70)	(68)	(2)	3.1%	(258)	(250)	(8)	3.2%
Outsourced Services	(193)	(179)	(14)	8.0%	(692)	(727)	35	-4.9%
Other Operating Costs/Expenses	(306)	(210)	(96)	45.8%	(770)	(753)	(17)	2.2%
Allowance for doubtful accounts	(56)	(36)	(19)	53.3%	(169)	(155)	(14)	9.1%
Legal and judicial expenses	(74)	(66)	(8)	11.6%	(187)	(188)	2	-0.9%
Others	(177)	(107)	(69)	64.4%	(414)	(409)	(4)	1.1%
Total Reported PMSO	(950)	(836)	(114)	13.6%	(3,134)	(3,107)	(27)	0.9%

The PMSO item reached R$ 950 million in 4Q18, compared to R$ 836 million in 4Q17, an increase of 13.6% (R$ 114 million), due to the following factors:

(i) Personnel - increase of 0.4% (R$ 1 million), mainly due to the collective bargaining agreement – wages and benefits;

(ii) Material - increase of 3.1% (R$ 2 million), mainly due to the increase in thereplacement of material to the maintenance of lines and grid;

(iii) Outsourced services - increase of 8.0% (R$ 14 million), mainly due to the increases inmaintenance services in lines, network and substations and in outsourced services;

(iv) Other operational costs/expenses-increase of 45.8% (R$ 96 million), mainly due to:

ü Increase of 278.8% (R$ 91 million) of loss on disposal, retirement and other noncurrent assets;

ü Increase of 53.3% (R$ 19 million) in allowance for doubtful account;

ü Increase of 11.6% (R$ 8 million) in legal and judicial expenses;

Partially offset by:

ü Compensation for non-compliance with technical indicators (R$ 16 million), which from January 2018 onwards was classified under Other Revenues;

ü Other effects (R$ 6 million).

In 2018, the PMSO item reached R$ 3,134 million, compared to R$ 3,107 million in 2017, an increase of 0.9% (R$ 27 million), due to the following factors:

(i) Personnel - increase of 2.7% (R$ 37 million), mainly due to the collective bargaining agreement – wages and benefits;

(ii) Material - increase of 3.2% (R$ 8 million), mainly due to the increase in thereplacement of material to the maintenance of lines and grid;

(iii) Outsourced services - reduction of 4.9% (R$ 35 million), mainly due to the reductionsin other outsourced services and in maintenance in machinery and equipment;

(iv) Other operational costs/expenses - increase of 2.2% (R$ 17 million), mainly due to:

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ü Increase of 59.5% (R$ 79 million) of loss on disposal, retirement and other noncurrent assets;

ü Increase of 9.1% (R$ 14 million) in allowance for doubtful account;

Partially offset by:

ü Compensation for non-compliance with technical indicators (R$ 50 million), which from January 2018 onwards was classified under Other Revenues;

ü Provision for impairment (R$ 20 million);

ü Reduction of 0.9% (R$ 2 million) in legal and judicial expenses;

ü Other effects (R$ 4 million).

Other operating costs and expenses

Other operating costs and expenses reached R$ 994 million in 4Q18, compared to R$ 1,008 million in 4Q17, registering a reduction of 1.4% (R$ 14 million), due to the following factors:

· Reduction of 4.0% (R$ 24 million) inCosts of Building the Infrastructure item;

· Reduction of 21.0% (R$ 6 million) inPrivate Pension Fund item, due to the registration of the impacts of the 2018 actuarial report;

Partially offset by:

· Increase of 4.3% (R$ 14 million) inDepreciation and Amortization item;

· Increase of 2.9% (R$ 2 million) inAmortization of Intangible of Concession Asset item.

In 2018, other operating costs and expenses reached R$ 3,456 million, compared to R$ 3,715 million in 2017, registering a reduction of 7.0% (R$ 259 million), due to the following factors:

· Reduction of 14.5% (R$ 300 million) inCosts of Building the Infrastructure item;

· Reduction of 21.1% (R$ 24 million) inPrivate Pension Fund item, due to the registration of the impacts of the 2018 actuarial report;

Partially offset by:

· Increase of 5.2% (R$ 64 million) inDepreciation and Amortization item;

· Increase of 0.2% (R$ 1 million) inAmortization of Intangible of Concession Asset item.

4.6) EBITDA

In 4Q18,EBITDA reached R$ 1,354 million, compared to R$ 1,366 million in 4Q17, registering a reduction of 0.9% (R$ 12 million). In 2018,EBITDA reached R$ 5,637 million, compared to R$ 4,864 million in 2017, registering an increase of 15.9% (R$ 773 million).

EBITDA is calculated according to CVM Instruction no. 527/12 and showed in the table below:

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EBITDA and Net Income conciliation (R$ million)
	4Q18	4Q17	Var.	2018	2017	Var.
Net Income	670	498	34.7%	2,166	1,243	74.2%
De preciation and Amortization	403	387		1,595	1,530
Financial Result	271	290		1,103	1,488
Income Tax / Social Contribution	10	192		774	604
EBITDA	1,354	1,366	-0.9%	5,637	4,864	15.9%

4.7) Financial Result


	4Q18	4Q17	Var.	2018	2017	Var.
Revenues
Income from Financial Investments	47	74	-35.9%	223	457	-51.3%
Additions and Late Payment Fines	73	62	18.6%	276	265	4.1%
Fiscal Credits Update	2	5	-53.0%	15	20	-24.5%
Judicial Deposits Update	9	10	-3.7%	37	50	-24.6%
Monetary and Foreign Exchange Updates	19	11	78.7%	70	61	15.1%
Discount on Purchase of ICMS Credit	9	7	28.9%	34	16	106.1%
Sectoral Financial Assets Update	36	-	-	80	-	-
PIS and COFINS - over Other Financial Revenues	(12)	(11)	5.3%	(46)	(48)	-4.4%
PIS and COFINS over Interest on Own Capital	(39)	(26)	50.1%	(39)	(28)	41.6%
Others	39	41	-5.9%	113	87	29.0%
Total	184	171	7.1%	762	880	-13.4%

Expenses
Debt Charges	(326)	(340)	-4.1%	(1,329)	(1,661)	-20.0%
Monetary and Foreign Exchange Updates	(69)	(104)	-33.4%	(368)	(540)	-31.8%
(-) Capitalized Interest	8	8	-0.1%	29	51	-43.4%
Sectoral Financial Liabilities Update	-	(2)	-100.0%	-	(82)	-100.0%
Use of Public Asset	(4)	(3)	20.1%	(18)	(8)	120.7%
Others	(63)	(21)	198.6%	(179)	(127)	41.1%
Total	(454)	(461)	-1.5%	(1,865)	(2,368)	-21.2%

Financial Result	(271)	(290)	-6.7%	(1,103)	(1,488)	-25.9%

In 4Q18,net financial expense was of R$ 271 million, a reduction of 6.7% (R$ 19 million) compared to the net financial expense of R$ 290 million reported in 4Q17.

The items explaining these variations in Financial Result are as follows:

· Financial Revenues: increase of 7.1% (R$ 12 million), from R$ 171 million in 4Q17 to R$ 184 million in 4Q18, mainly due to the following factors:

(i) Sectoral financial assets update in 4Q18, in the amount of R$ 36 million;

(ii) Increase of 18.6% (R$ 11 million) inadditions and late payment fines;

(iii) Increase of 78.7% (R$ 9 million) in themonetary and foreign exchange updates, due to the increases: (a) of R$ 12 million in revenues from fines, interest and monetary adjustment relating to installment payments made by consumers, and (b) of R$ 4 million in other monetary and foreign exchange updates; partially offset by the reductions (c) of R$ 6 million in the update of the balance of tariff subsidies, as determined by ANEEL,and (d) of R$ 1 million in gains with the zero-cost collar derivative¹;

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(iv) Increase of 28.9% (R$ 2 million) indiscount on the acquisition of ICMS credit;

Partially offset by:

(v) Reduction of 35.9% (R$ 26 million) in theincome from financial investments, due to the reductions in the CDI interbank rate and in the average balance of investments;

(vi) Increase of 50.1% (R$ 13 million) inPIS and COFINS over Interest on Own Capital (revenue reducer);

(vii) Reduction of 53.0% (R$ 3 million) infiscal credits update;

(viii) Reduction of 5.9% (R$ 2 million) inother financial revenues;

(ix) Increase of 5.3% (R$ 1 million) inPIS and COFINS over Other Financial Revenue (revenue reducer).

· Financial Expenses: reduction of 1.5% (R$ 7 million), from R$ 461 million in 4Q17 to R$ 454 million in 4Q18, mainly due to the following factors:

(i) Reduction of 33.4% (R$ 35 million) in themonetary and foreign exchange updates, due to: (a) the mark-to-market positive effect for financial operations under Law 4,131 – non-cash effect (R$ 21 million), (b) the effect of Itaipu’s exchange variation (R$ 13 million), and (c) the reduction of debt charges in foreign currency, with swap to CDI interbank rate (R$ 1 million);

(ii) Reduction of 4.1% (R$ 14 million) ofdebt charges in local currency, due to the reduction in the CDI interbank rate;

(iii) Sectoral financial liabilities update in 4Q17, in the amount of R$ 2 million (expense reducer);

Partially offset by:

(iv) Increase of 198.6% (R$ 42 million) inother financial expenses;

(v) Increase of 20.1% (R$ 1 million) in thefinancial expenses with the Use of Public Asset (UBP).

In 2018,net financial expense was of R$ 1,103 million, a reduction of 25.9% (R$ 385 million) compared to the net financial expense of R$ 1,488 million reported in 2017.

The items explaining these variations in Financial Result are as follows:

· Financial Revenues: reduction of 13.4% (R$ 118 million), from R$ 880 million in 2017 to R$ 762 million in 2018, mainly due to the following factors:

(i) Reduction of 51.3% (R$ 234 million) in theincome from financial investments, due to the reductions in the CDI interbank rate and in the average balance of investments;

(ii) Reduction of 24.6% (R$ 12 million) injudicial deposits update;

(iii) Increase of 41.6% (R$ 12 million) inPIS and COFINS over Interest on Own Capital (revenue reducer);

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1In 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.

4Q18/2018 Results | March 28, 2019

(iv) Reduction of 24.5% (R$ 5 million) infiscal credits update;

Partially offset by:

(v) Sectoral financial assets update in 2018, in the amount of R$ 80 million;

(vi) Increase of 29.0% (R$ 25 million) inother financial revenues;

(vii) Increase of 106.1% (R$ 17 million) indiscount on the acquisition of ICMS credit;

(viii) Increase of 4.1% (R$ 11 million) inadditions and late payment fines;

(ix) Increase of 15.1% (R$ 9 million) in themonetary and foreign exchange updates, due to: (a) the increase of R$ 38 million in revenues from fines, interest and monetary adjustment relating to installment payments made by consumers; partially offset by the reductions (b) of R$ 20 million in the gains with the zero-cost collar derivative, (c) of R$ 5 million in other monetary and foreign exchange updates, and (d) of R$ 4 million in the update of the balance of tariff subsidies, as determined by ANEEL;;

(x) Reduction of 4.4% (R$ 2 million) inPIS and COFINS over Other Financial Revenue (revenue reducer).

· Financial Expenses: reduction of 21.2% (R$ 503 million), from R$ 2,368 million in 2017 to R$ 1,865 million in 2018, mainly due to the following factors:

(i) Reduction of 20.0% (R$ 332 million) ofdebt charges in local currency, due to the reduction in the CDI interbank rate;

(ii) Reduction of 31.8% (R$ 172 million) in themonetary and foreign exchange updates, due to: (a) the reduction of debt charges in foreign currency, with swap to CDI interbank rate (R$ 145 million), (b) the mark-to-market positive effect for financial operations under Law 4,131 – non-cash effect (R$ 19 million), and (c) the effect of Itaipu’s exchange variation (R$ 7 million);

(iii) Sectoral financial liabilities update in 2017, in the amount of R$ 82 million;

Partially offset by:

(iv) Increase of 41.1% (R$ 52 million) inother financial expenses;

(v) Reduction of 43.4% (R$ 22 million) incapitalized interest (expense reducer);

(vi) Increase of 120.7% (R$ 10 million) in thefinancial expenses with the Use of Public Asset (UBP).

4.8) Net Income

Net incomewas of R$ 670 million in 4Q18, registering an increase of 34.7% (R$ 173 million) if compared to the net income of R$ 498 million observed in 4Q17. In 2018,net income was of R$ 2,166 million, registering an increase of 74.2% (R$ 923 million) if compared to the net income of R$ 1,243 million observed in 2017.

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5) INDEBTEDNESS

5.1) Debt (IFRS)

Note includes the mark-to-market (MTM) effect and borrowing costs.

Indexation after Hedge – 4Q17 vs. 4Q18

4Q17

4Q18

Note: for debt linked to foreign currency (25.6% of total in 4Q18), swap operations are contracted, aiming the protection ofthe foreign exchange and the rate linked to the contract.

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Net Debt in IFRS

IFRS \| R$ Million	4Q18	4Q17	Var. %
Financial Debt (including hedge)	(19,752)	(19,615)	0.7%
(+) Available Funds	1,891	3,250	-41.8%
(=) Net Debt	(17,860)	(16,366)	9.1%

5.1.1) Debt Amortization Schedule in IFRS (Dec-18)

CPFL Energia has a large market access to liquidity sources through diversified funding alternatives, either through local market financing lines such as debenture issues, BNDES and other development banks, or through financing lines in the foreign market. This access to credit for the CPFL group is currently strengthened by the support of its shareholding structure, as State Grid gives greater robustness to CPFL group in financial market.

Notes:

1) Considers only the principal of the debt of R$ 19,706 million. In order to reach the value of debt in IFRS, of R$ 19,752 million, should be included charges and the mark-to-market (MTM) effect and cost with funding;

2) Short-term (January 2019 – December 2019) = R$ 2,896 million.

The cash position at the end of 4Q18 had a coverage ratio of0.65x the amortizations of the next 12 months, enough to honor all amortization commitments until the beginning of 2019. The average amortization term, calculated from this schedule, is of3.32 years.

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Gross Debt Cost¹ in IFRS criteria

Note: (1) as of 2Q17, CPFL Energia started to calculate its debt average cost considering the end of the period, to better reflect the variations on interest rates.

5.2) Debt in Financial Covenants Criteria

5.2.1) Indexation and Debt Cost in Financial Covenants Criteria

Indexation¹ After Hedge² in Financial Covenants Criteria – 4Q17 vs. 4Q18

4Q17

4Q18

1) Considering proportional consolidation of CPFL Renováveis, CERAN, ENERCAN, Foz do Chapecó and EPASA;

2) For debt linked to foreign currency (28.3% of total), swap operations are contracted, aiming the protection of the foreign exchange and the rate linked to the contract.

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5.2.2) Net Debt in Financial Covenants Criteria and Leverage

In 4Q18 Proforma Net Debt totaledR$ 16,274 million, an increase of12.3% compared to net debt position at the end of 4Q17, in the amount ofR$ 14,490 million.

*Covenant Criteria () - R$ Million**	4Q18	4Q17	Var.
Financial Debt (including hedge)1	(17,868)	(17,385)	2.8%
(+) Available Funds	1,593	2,895	-45.0%
(=) Net Debt	(16,274)	(14,490)	12.3%
EBITDA Proforma2	5,343	4,531	17.9%
Net Debt / EBITDA	3.05	3.20	-4.75%

1) Considering proportional consolidation of CPFL Renováveis, CERAN, ENERCAN, Foz do Chapecó and EPASA;

2) Proforma EBITDA in the financial covenants criteria: adjusted according to equivalent participation of CPFL Energia in each of its subsidiaries, with the inclusion of regulatory assets and liabilities and the historical EBITDA of newly acquired projects.

In line with the criteria for calculation of financial covenants of loan agreements with financial institutions, net debt is adjusted according to the equivalent stake of CPFL Energia in each of its subsidiaries. Also, include in the calculation of Proforma EBITDA the effects of historic EBITDA of newly acquired projects. Considering that the Proforma Net Debt totaledR$ 16,274 million and Proforma EBITDA in the last 12 months reachedR$ 5,343 million, the ratio Proforma Net Debt / EBITDA at the end of 4Q18 reached3.05x.

6) INVESTMENTS

6.1) Actual Investments

Investments (R$ Million)
Segment	4Q18	4Q17	Var.	2018	2017	Var.
Distribution	617	618	-0.2%	1,770	1,883	-6.0%
Generation - Conventional	6	6	-0.8%	12	9	28.4%
Generation - Renewable	51	55	-7.5%	225	621	-63.7%
Commercialization	1	1	-4.5%	3	3	0.0%
Services and Others¹	18	13	32.9%	53	55	-3.2%
Subtotal	693	694	-0.1%	2,062	2,570	-19.8%
Transmission	1	0	87.1%	3	46	-92.5%
Total	693	694	-0.1%	2,066	2,617	-21.0%

Note:

1) Others – basically refer to assets and transactions that are not related to the listed segments.

In 4Q18, investments were R$ 693 million, a reduction of 0.1% compared to 4Q17. In 2018, the investments were R$ 2,066 million, a reduction of 21.0%. Investments related to the transmission segment, according to IFRIC 15, are recorded as “Contractual Asset of Transmission Companies” (in other credits).

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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. Boa Vista II SHPP.

6.2) Investments Forecasts

On November 30, 2018, CPFL Energia’s Board of Directors approved Board of Executive Officers’ proposal for 2019 Annual Budget and 2020/2023 Multiannual Plan for the Company, which was previously discussed by the Budget and Corporate Finance Commission.

Investments Forecasts (R$ million)¹

Notes:

1) Constant currency;

2) Investment Plan released in 4Q18/2018 Earnings Release, from March 2019;

3) Disregard investments in Special Obligations (among other items financed by consumers);

4) Conventional + Renewable.

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7) ALLOCATION OF RESULTS

The Company’s Bylaws require the distribution of at least 25% of net income adjusted according to law, as dividends to its shareholders. The proposal for allocation of net income from the fiscal year is shown below:

Minimum Mandatory Dividend (25%)

The Board of Directors propose the payment of R$ 489 million in dividends to holders of common shares traded on B3 S.A. – Brasil, Bolsa, Balcão (B3). This proposed amount corresponds to R$ 0.480182232 per share, related to the fiscal year of 2018.

Statutory Reserve – Working Capital Reinforcement

For this fiscal year, considering the current macro scenario with an incipient economic recovery, and also considering the uncertainties regarding hydrology, the Company’s Management is proposing the allocation of R$ 2.235 million to the statutory reserve - working capital reinforcement.

8) STOCK MARKETS

8.1) Stock Performance

CPFL Energia is listed on both the B3 (Novo Mercado) and the New York Stock Exchange (NYSE) (ADR Level III), segments with the highest levels of corporate governance.

B3				NYSE
Date	CPFE3 (R$)	IEE	IBOV	Date	CPL (US$)	DJBr20	Dow Jones
12/31/2018	R$ 28.85	49,266	87,887	12/31/2018	$ 14.80	22,007	23,327
09/30/2018	R$ 23.87	39,351	79,342	09/30/2018	$ 11.82	19,406	26,458
12/31/2017	R$ 19.35	39,732	76,402	12/31/2017	$ 11.50	22,690	24,719
QoQ	20.9%	25.2%	10.8%	QoQ	25.2%	13.4%	-11.8%
YoY	49.1%	24.0%	15.0%	YoY	28.7%	-3.0%	-5.6%

On December 31, 2018, CPFL Energia’s shares closed at R$ 28.85 per share on the B3 and US$14.80 per ADR on the NYSE, an appreciation in the quarter of 20.9% and 25.2%, respectively. Considering the variation in the last 12 months, the shares and ADRs presented an appreciation of 49.1% on the B3 and of 28.7% on the NYSE.

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8.2) Daily Average Volume

The daily trading volume in 4Q18 averaged R$ 12.1 million, of which R$ 10.9 million on the B3 and R$ 1.2 million on the NYSE, representing a reduction of 77.5% in relation to 4Q17. The number of trades on the B3 decreased by 61.8%.

Note: Considers the sum of the average daily volume on the B3 and NYSE.

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9) CORPORATE GOVERNANCE

The corporate governance model adopted by CPFL Energia and its subsidiaries is based on the principles of transparency, equity, accountability and corporate responsibility.

In 2018, CPFL marked 14 years since being listed on the B3 and the New York Stock Exchange (“NYSE”). With more than 100 years of history in Brazil, the Company’s shares are listed on theNovo MercadoSpecial Listing Segment of the B3 with Level III ADRs, a special segment for companies that comply with corporate governance best practices. All CPFL shares are common shares, entitling all shareholders the right to vote with 100% Tag Along rights guaranteed in case of sale of shareholding control.

CPFL’s Management is composed of the Board of Directors (“Board”), its decision-making authority, and the Board of Executive Officers, its executive body. The Board is responsible for defining the strategic business direction of the holding company and subsidiaries, and is composed of 7 members (of which 2 independent members), with terms of one year, eligible for reelection.

The Bylaws of the Board establishes the procedures for evaluating the directors, under the leadership of the Chairman, their main duties and rights.

The Board set up three advisory committees (Management Processes, Risks and Sustainability, People Management and Related Parties), which support the Board in its decisions and monitor relevant and strategic themes, such as people and risk management, sustainability, the surveillance of internal audits and analysis of transactions with Parties Related to controlling shareholders and handling of incidents recorded through complaint hotlines and ethical conduct channels.

The Board of Executive Officers is made up of 1 Chief Executive Officer, 1 Deputy Chief of Executive Officer and 7 Vice Presidents, with terms of two years, eligible for reelection, responsible for executing the strategy of CPFL Energia and its subsidiaries as defined by the Board of Directors in line with corporate governance guidelines. To ensure alignment of governance practices, Executive Officers sit on the Boards of Directors of companies that make up the CPFL group and nominate their respective executive officers.

CPFL has a permanent Fiscal Council, made up of 3 members, that also exercises the duties of the Audit Committee, in line with Sarbanes-Oxley law (SOX) rulings applicable to foreign companies listed on U.S. stock exchanges.

The guidelines and documents on corporate governance are available at the Investor Relations website http://www.cpfl.com.br/ir.

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10) SHAREHOLDERS STRUCTURE

CPFL Energia is a holding company that owns stake in other companies. State Grid Corporation of China (SGCC) controls CPFL Energia through its subsidiaries State Grid International Development Co., Ltd, State Grid International Development Limited (SGID), International Grid Holdings Limited, State Grid Brazil Power Participações S.A. (SGBP) and ESC Energia S.A.:

Reference date: 12/31/2018

Notes:

(1) RGE Sul is held by CPFL Energia (89.0107%) and CPFL Brasil (10.9893%).

(2) CPFL Soluções = CPFL Brasil + CPFL Serviços + CPFL Eficiência;

(3) 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;

10.1) CPFL Renováveis’ Tender Offer

CPFL Renováveis’ Mandatory Tender Offer occurred on November 26, 2018. According to the Material Fact and the Announcement to the Market released on November 26 and 30, 2018, respectively, as a result of the auction, State Grid acquired 243,771,824 common shares issued by the company, representing 48.39% of the capital stock of the company. The common shares were acquired at the price of R$ 16.85, totaling the amount of R$ 4.1 billion. State Grid and CPFL Geração (indirectly controlled by State Grid) jointly held 503,520,623 common shares issued by the company, equivalent to 99.94% of the total share capital of the company.

10.2) Merger of RGE and RGE Sul distribution companies

In December 2018, CPFL promoted the merger of the distribution company Rio Grande Energia S.A. (“RGE” or “Merged Company”) into RGE Sul Distribuidora de Energia S.A. (“RGE Sul” or“Merging Company”). On December 04, 2018, by means of Authorizing Resolution No. 7,499, the grouping of the concessions of the two companies was approved by the National Electric Energy Regulatory Agency (ANEEL), through the incorporation of the assets held by the Merged Company by the Merging Company on December 31, 2018.

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As a result of the grouping, RGE Sul (“New RGE”) became responsible for the electric power supply of 381 municipalities, located in the State of Rio Grande do Sul, meeting the demand of 2.9 million clients.

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11) PERFORMANCE OF THE BUSINESS SEGMENTS

11.1) Distribution Segment

11.1.1) Economic-Financial Performance

Consolidated Income Statement - Distribution (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Gross Operating Revenue	8,613	9,197	-6.4%	36,310	33,768	7.5%
Net Operating Revenue	5,160	5,750	-10.2%	22,467	21,077	6.6%
Cost of Electric Power	(3,104)	(3,767)	-17.6%	(15,022)	(14,147)	6.2%
Operating Costs & Expenses	(1,526)	(1,494)	2.1%	(5,208)	(5,399)	-3.5%
EBIT	530	489	8.5%	2,237	1,531	46.2%
EBITDA⁽¹⁾	726	668	8.7%	3,004	2,234	34.5%
Financial Income (Expense)	(61)	(87)	-30.4%	(310)	(566)	-45.3%
Income Before Taxes	469	401	16.9%	1,928	964	99.9%
Net Income	511	337	51.8%	1,432	665	115.4%

Note:

(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12.

11.1.1.1) Sectoral Financial Assets and Liabilities

In 4Q18, totalsectoral financial liabilities accounted for R$ 735 million, a variation of R$ 1,586 million if compared to 4Q17, whensectoral financial assets amounted to R$ 852 million. In 2018, totalsectoral financial assets accounted for R$ 1,208 million, a reduction of 36.5% (R$ 693 million) if compared to 2017, whensectoral financial assets amounted to R$ 1,901 million.

On December 31, 2018, the balance of sectoral financial assets and liabilities was positive in R$ 1,508 million, compared to a positive balance of R$ 2,207 million on September 30, 2018 and a positive balance of R$ 517 million on December 31, 2017.

As established by the applicable regulation, any sectoral financial assets or liabilities shall be included in the tariffs of the distributors in their respective annual tariff events.

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11.1.1.2) Operating Revenue

Operating Revenue (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Gross Operating Revenue
Revenue with Energy Sales (Captive + TUSD)	8,245	7,020	17.4%	30,203	26,174	15.4%
Short-term Electric Energy	13	193	-93.3%	781	1,723	-54.7%
Revenue from Building the Infrastructure of the Concession	568	592	-4.0%	1,771	2,026	-12.6%
Sectoral Financial Assets and Liabilities	(735)	852	-	1,208	1,901	-36.5%
CDE Resources - Low-income and Other Tariff Subsidies	375	347	7.9%	1,536	1,419	8.3%
Adjustments to the Concession's Financial Asset	43	113	-62.3%	345	204	68.8%
Other Revenues and Income	104	79	31.1%	467	321	45.3%
Total	8,613	9,197	-6.4%	36,310	33,768	7.5%

Deductions from the Gross Operating Revenue
ICMS Tax	(1,647)	(1,405)	17.2%	(6,090)	(5,362)	13.6%
PIS and COFINS Taxes	(743)	(767)	-3.1%	(3,179)	(2,889)	10.0%
CDE Sector Charge	(1,187)	(787)	50.9%	(4,016)	(3,186)	26.1%
R&D and Energy Efficiency Program	(45)	(51)	-10.0%	(203)	(188)	8.1%
PROINFA	(40)	(39)	3.1%	(152)	(167)	-9.0%
Tariff Flags and Others	216	(395)	-	(179)	(878)	-79.7%
Others	(7)	(5)	26.6%	(24)	(21)	15.6%
Total	(3,452)	(3,447)	0.1%	(13,843)	(12,692)	9.1%

Net Operating Revenue	5,160	5,750	-10.2%	22,467	21,077	6.6%

In 4Q18, gross operating revenue amounted to R$ 8,613 million, a reduction of 6.4% (R$ 584 million), due to the following factors:

· Variation of R$ 1,586 million in the Sectoral Financial Assets/Liabilities, from a sectoral financial asset of R$ 852 million in 4Q17 to a sectoral financial liability of R$ 735 million in 4Q18;

· Reduction of 93.3% (R$ 181 million) in Short-term Electric Energy;

· Reduction of 62.3% (R$ 70 million) in the adjustments to the Concession´s Financial Asset;

· Reduction of 4.0% (R$ 24 million) in revenue from building the infrastructure of the concession;

Partially offset by:

· Increase of 17.4% (R$ 1,224 million) in the revenue with energy sales (captive + free clients), due to: (i) the positive average tariff adjustment in the distribution companies for the period between 4Q17 and 4Q18 (highlight for the average increases of 16.90% in CPFL Paulista and 22.47% in RGE Sul, in April 2018, of 20.58% in RGE, in June 2018, and of 19.25% in CPFL Piratininga, in October 2018); and (ii) the increase of 1.2% in the sales volume within the concession area;

· Increase of 7.9% (R$ 28 million) in tariff subsidies (CDE resources);

· Increase of 31.1% (R$ 25 million) in Other Revenues and Income.

Deductions from the gross operating revenue were R$ 3,452 million in 4Q18, representing an increase of 0.1% (R$ 5 million), due to the following factors:

· Increase of 50.9% (R$ 400 million) in the CDE sector charge;

· Increase of 17.2% (R$ 242 million) in ICMS tax;

· Increase of 3.1% (R$ 1 million) in the PROINFA;

· Increase of 26.6% (R$ 1 million) in other deductions from the gross operating revenue;

Partially offset by the following factor:

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· Variation of R$ 611 million in tariff flags approved by the CCEE, from an expense of R$ 395 million in 4Q17 to a revenue of R$ 216 million in 4Q18;

· Reduction of 3.1% (R$ 24 million) in PIS and COFINS taxes;

· Reduction of 10.0% (R$ 5 million) in the R&D and Energy Efficiency Program.

Net operating revenue reached R$ 5,160 million in 4Q18, representing a reduction of 10.2% (R$ 589 million).

In 2018, gross operating revenue amounted to R$ 36,310 million, an increase of 7.5% (R$ 2,542 million), due to the following factors:

· Increase of 15.4% (R$ 4,029 million) in the revenue with energy sales (captive + free clients), due to: (i) the positive average tariff adjustment in the distribution companies for the period between 2017 and 2018; and (ii) the increase of 2.5% in the sales volume within the concession area;

· Increase of 45.3% (R$ 146 million) in Other Revenues and Income;

· Increase of 68.8% (R$ 141 million) in the adjustments to the Concession´s Financial Asset;

· Increase of 8.3% (R$ 117 million) in tariff subsidies (CDE resources);

Partially offset by:

· Reduction of 54.7% (R$ 942 million) in Short-term Electric Energy;

· Reduction of 36.5% (R$ 693 million) in the Sectoral Financial Assets/Liabilities;

· Reduction of 12.6% (R$ 256 million) in revenue from building the infrastructure of the concession.

Deductions from the gross operating revenue were R$ 13,843 million in 2018, representing an increase of 9.1% (R$ 1,151 million), due to the following factors:

· Increase of 26.1% (R$ 831 million) in the CDE sector charge;

· Increase of 13.6% (R$ 728 million) in ICMS tax;

· Increase of 10.0% (R$ 289 million) in PIS and COFINS taxes;

· Increase of 8.1% (R$ 15 million) in the R&D and Energy Efficiency Program;

· Increase of 15.6% (R$ 3 million) in other deductions from the gross operating revenue;

Partially offset by the following factors:

· Reduction of 79.7% (R$ 700 million) in tariff flags approved by the CCEE;

· Reduction of 9.0% (R$ 15 million) in the PROINFA.

Net operating revenue reached R$ 22,467 million in 2018, representing an increase of 6.6% (R$ 1,391 million).

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11.1.1.3) Cost of Electric Energy

Cost of Electric Energy (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Cost of Electric Power Purchased for Resale
Energy from Itaipu Binacional	643	587	9.6%	2,668	2,351	13.5%
PROINFA	81	77	5.0%	331	293	12.8%
Energy Purchased through Auction in the Regulated Environment, Bilateral Contracts and Energy Purchased in the Spot Market	2,061	3,085	-33.2%	10,979	11,643	-5.7%
PIS and COFINS Tax Credit	(242)	(346)	-30.1%	(1,239)	(1,318)	-5.9%
Total	2,542	3,403	-25.3%	12,738	12,970	-1.8%

Charges for the Use of the Transmission and Distribution System
Basic Network Charges	465	534	-12.9%	2,039	1,462	39.4%
Itaipu Transmission Charges	68	63	7.5%	266	160	66.5%
Connection Charges	45	29	54.5%	155	106	46.2%
Charges for the Use of the Distribution System	9	5	67.1%	30	21	40.6%
System Service Usage Charges - ESS	32	(229)	-	(106)	(453)	-76.6%
Reserve Energy Charges - EER	-	-	-	135	-	-
PIS and COFINS Tax Credit	(57)	(39)	49.1%	(235)	(119)	96.4%
Total	562	364	54.2%	2,284	1,177	94.1%

Cost of Electric Energy	3,104	3,767	-17.6%	15,022	14,147	6.2%

In 4Q18, 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$ 3,104 million, representing a reduction of 17.6% (R$ 663 million):

· Thecost of electric power purchased for resale was R$ 2,542 million in 4Q18, representing a reduction of 25.3% (R$ 860 million), due to the following factors:

(i) Reduction of 33.2% (R$ 1,024 million) in thecost of energy purchased through auction in the regulated environment, bilateral contracts and energy purchased in the spot market, due to the reduction of 34.6% in the average purchase price (from R$ 303.67/MWh in 4Q17 to R$ 198.72/MWh in 4Q18), partially offset by the increase of 2.1% (212 GWh) in the volume of purchased energy;

Partially offset by:

(ii) Reduction of 30.1% (R$ 104 million) inPIS and Cofins tax credit (cost reducer), generated from the energy purchase;

(iii) Increase of 9.6% (R$ 56 million) in thecost of energy fromItaipu, due to theincrease of 16.1% in the average purchase price (from R$ 197.38/MWh in 4Q17 to R$ 229.13/MWh in 4Q18), partially offset by the reduction of 5.6% (167 GWh) in the volume of purchased energy;

(iv) Increase of 5.0% (R$ 4 million) in thecost of the Proinfa, due to theincrease of 6.0% in the average purchase price (from R$ 249.11/MWh in 4Q17 to R$ 264.09/MWh in 4Q18), partially offset by the reduction of 0.9% (3 GWh) in the volume of purchased energy.

· Charges for the use of the transmission and distribution system reached R$ 562 million in 4Q18, representing an increase of 54.2% (R$ 197 million), due to the following factors:

(i) Variation of R$ 261 million in theSystem Service Usage Charges – ESS, from a revenue of R$ 229 million in 4Q17 to an expense of R$ 32 million in 4Q18;

(ii) Increase of 54.5% (R$ 16 million) inconnection charges;

(iii) Increase of 7.5% (R$ 5 million) in theItaipu transmission charges;

(iv) Increase of 67.1% (R$ 3 million) in theusage of the distribution system charges;

Partially offset by:

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(v) Reduction of 12.9% (R$ 69 million) incharges for basic network;

(vi) Increase of 49.1% (R$ 19 million) inPIS and Cofins tax credit (cost reducer), generated from the charges.

In 2018, 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$ 15,022 million, representing an increase of 6.2% (R$ 876 million):

· Thecost of electric power purchased for resale was R$ 12,738 million in 2018, representing a reduction of 1.8% (R$ 232 million), due to the following factors:

(i) Reduction of 5.7% (R$ 665 million) in thecost of energy purchased through auction in the regulated environment, bilateral contracts and energy purchased in the spot market, due to the reduction of 6.6% (2,934 GWh) in the volume of purchased energy, partially offset by the increase of 0.9% in the average purchase price (from R$ 261.23/MWh in 2017 to R$ 263.67/MWh in 2018);

Partially offset by:

(ii) Increase of 13.5% (R$ 317 million) in thecost of energy from Itaipu, due to the increase of 20.3% in the average purchase price (from R$ 199.58/MWh in 2017 to R$ 240.03/MWh in 2018), partially offset by the reduction of 5.6% (662 GWh) in the volume of purchased energy;

(iii) Reduction of 5.9% (R$ 78 million) inPIS and Cofins tax credit (cost reducer), generated from the energy purchase;

(iv) Increase of 12.8% (R$ 37 million) in thecost of the Proinfa, due to the increase of 15.9% in the average purchase price (from R$ 256.70/MWh in 2017 to R$ 297.52/MWh in 2018), partially offset by the reduction of 2.7% (31 GWh) in the volume of purchased energy.

· Charges for the use of the transmission and distribution system reached R$ 2,284 million in 2018, representing an increase of 94.1% (R$ 1,107 million), due to the following factors:

(i) Increase of 39.4% (R$ 576 million) incharges for basic network;

(ii) Reduction of 76.6% (R$ 347 million) in theSystem Service Usage Charges – ESS (cost reducer), from a revenue of R$ 453 million in 2017 to a revenue of R$ 106 million in 2018;

(iii) Expense of R$ 135 million in 2018, related to theEnergy Reserve Charges – EER;

(iv) Increase of 66.5% (R$ 106 million) in theItaipu transmission charges;

(v) Increase of 46.2% (R$ 49 million) inconnection charges;

(vi) Increase of 40.6% (R$ 9 million) in theusage of the distribution system charges;

Partially offset by:

(vii) Increase of 96.4% (R$ 115 million) inPIS and Cofins tax credit (cost reducer), generated from the charges.

11.1.1.4) Operating Costs and Expenses

Operating costs and expenses reached R$ 1,526 million in 4Q18, compared to R$ 1,494 million in 4Q17, an increase of 2.1% (R$ 32 million). In 2018, operating costs and expenses reached R$ 5,208 million, compared to R$ 5,399 million in 2017, a reduction of 3.5% (R$ 192 million).

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The factors that explain these variations follow below:

PMSO

Reported PMSO (R$ million)
	4Q18	4Q17	Variation		2018	2017	Variação
	4Q18	4Q17	R$ MM	%	2018	2017	R$ MM	%
Reported PMSO
Personnel	(245)	(251)	6	-2.4%	(926)	(920)	(5)	0.6%
Material	(46)	(46)	(0)	0.6%	(170)	(170)	(1)	0.3%
Outsourced Services	(239)	(235)	(5)	2.1%	(866)	(853)	(14)	1.6%
Other Operating Costs/Expenses	(209)	(163)	(46)	28.0%	(620)	(615)	(5)	0.8%
Allowance for doubtful accounts	(50)	(36)	(14)	39.9%	(166)	(155)	(11)	6.9%
Legal and judicial expenses	(73)	(59)	(14)	24.2%	(180)	(179)	(0)	0.1%
Others	(85)	(68)	(17)	25.1%	(274)	(280)	6	-2.1%
Total Reported PMSO	(739)	(695)	(45)	6.4%	(2,582)	(2,557)	(24)	1.0%

In 4Q18,PMSO reached R$ 739 million, an increase of 6.4% (R$ 45 million), compared to R$ 695 million in 4Q17.

Personnel– reduction of 2.4% (R$ 6 million);

Material– increase of 0.6% (R$ 0.3 million);

Third party services – increase of 2.1% (R$ 5 million), mainly due to the increases in the following items: maintenance services in lines, network and substations (R$ 8 million), outsourced services (R$ 6 million), delinquency/collection recovery (R$ 2 million), hardware/software maintenance (R$ 2 million), meter reading and use (R$ 2 million), maintenance and conservation of buildings (R$ 2 million); partially offset by the reductions in other outsourced services (R$ 8 million), maintenance in machinery and equipment (R$ 4 million) and maintenance of the electric system – lines and network (R$ 3 million) and cleanliness and conservation (R$ 2 million);

Other operating costs/expenses – increase of 28.0% (R$ 46 million), due to the increases in the following items: (a) compensation for non-compliance with technical indicators (R$ 16 million), which as from January 2018 was classified under Other Revenues, (b) legal and judicial expenses (R$ 14 million), (c) allowance for doubtful accounts (R$ 14 million) and (d) other costs/expenses (R$ 1 million).

In 2018,PMSO reached R$ 2,582 million, an increase of 1.0% (R$ 24 million), compared to R$ 2,557 million in 2017.

Personnel– increase of 0.6% (R$ 5 million), mainly due to the collective bargaining agreement – wages and benefits;

Material– increase of 0.3% (R$ 1 million);

Third party services – increase of 1.6% (R$ 14 million), mainly due to the increases in the following items: maintenance services in lines, network and substations (R$ 21 million), outsourced services (R$ 15 million), meter reading and use (R$ 9 million), tree pruning (R$ 7 million), auditand consulting (R$ 5 million), hardware/software maintenance (R$ 4 million) and maintenance and conservation of buildings (R$ 3 million); partially offset by the reductions in other outsourced services (R$ 32 million), maintenance in machinery and equipment (R$ 13 million) and maintenance of the electric system – lines and network (R$ 4 million);

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Other operating costs/expenses – increase of 0.8% (R$ 5 million), due to the increases in the following items: (a) loss on disposal, retirement and other noncurrent assets (R$ 21 million), (b) other costs/expenses (R$ 16 million), (c) allowance for doubtful accounts (R$ 11 million) and (d) collection fees (R$ 7 million); partially offset by the reduction in compensation for non-compliance with technical indicators (R$ 50 million), which as from January 2018 was classified under Other Revenues.

Other operating costs and expenses

In 4Q18, other operating costs and expenses reached R$ 787 million, compared to R$ 800 million in 4Q17, registering a reduction of 1.6% (R$ 13 million), with the variations below:

(i)		Reduction of 4.0% (R$ 24 million) incost of building the concession´s infrastructure. This item, which reached R$ 568 million in 4Q18, does not affect results, since it has its counterpart in “operating revenue”;
(ii)		Reduction of 21.0% (R$ 6 million) inPrivate Pension Fund item, due to the registration of the impacts of the 2018 actuarial report;
		Partially offset by:
(iii)		Increase of 9.9% (R$ 16 million) inDepreciation and Amortization item;
(iv)		Increase of 4.7% (R$ 1 million) inAmortization of Intangible of Concession Asset item.

In 2018, other operating costs and expenses reached R$ 2,626 million, compared to R$ 2,842 million in 2017, registering a reduction of 7.6% (R$ 216 million), with the variations below:

(v)		Reduction of 12.6% (R$ 256 million) incost of building the concession´s infrastructure. This item, which reached R$ 1,771 million in 2018, does not affect results, since it has its counterpart in “operating revenue”;
(vi)		Reduction of 21.0% (R$ 23 million) inPrivate Pension Fund item, due to the registration of the impacts of the 2018 actuarial report;
(vii)		Reduction of 2.9% (R$ 2 million) inAmortization of Intangible of Concession Asset item;
		Partially offset by:
(viii)		Increase of 10.1% (R$ 65 million) inDepreciation and Amortization item.

11.1.1.5) EBITDA

EBITDAtotaled R$ 726 million in 4Q18, compared to R$ 668 million in 4Q17, an increase of 8.7% (R$ 58 million). In 2018,EBITDAtotaled R$ 3,004 million, compared to R$ 2,234 million in 2017, an increase of 34.5% (R$ 770 million).

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Conciliation of Net Income and EBITDA (R$ million)
	4Q18	4Q17	Var.	2018	2017	Var.
Net income	511	337	51.8%	1,432	665	115.4%
Depreciation and Amortization	196	179		767	704
Financial Results	61	87		310	566
Income Tax /Social Contribution	(42)	64		495	300
EBITDA	726	668	8.7%	3,004	2,234	34.5%

11.1.1.6) Financial Result

Financial Result (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Revenues
Income from Financial Investments	15	28	-46.1%	74	218	-66.0%
Additions and Late Payment Fines	73	61	18.8%	273	262	4.3%
Fiscal Credits Update	1	1	-7.4%	8	8	4.5%
Judicial Deposits Update	9	9	-5.0%	36	49	-26.6%
Monetary and Foreign Exchange Updates	19	14	38.7%	69	40	71.5%
Discount on Purchase of ICMS Credit	9	7	29.0%	34	16	106.1%
Sectoral Financial Assets Update	36	-	-	80	-	-
PIS and COFINS - over Other Financial Revenues	(9)	(9)	9.5%	(36)	(36)	0.0%
Others	9	13	-30.1%	38	41	-9.5%
Total	161	125	29.0%	575	597	-3.8%

Expenses
Debt Charges	(149)	(131)	13.8%	(582)	(623)	-6.6%
Monetary and Foreign Exchange Updates	(44)	(69)	-36.2%	(227)	(390)	-41.9%
(-) Capitalized Interest	6	6	-7.3%	18	21	-13.1%
Sectoral Financial Liabilities Update	-	(2)	-100.0%	-	(82)	-100.0%
Others	(35)	(18)	99.2%	(93)	(88)	5.6%
Total	(222)	(212)	4.5%	(885)	(1,164)	-24.0%

Financial Result	(61)	(87)	-30.4%	(310)	(566)	-45.3%

In 4Q18, the net financial result recorded a net financial expense of R$ 61 million, a reduction of 30.4% (R$ 27 million). The items explaining these changes are as follows:

· Financial Revenue: increase of 29.0% (R$ 36 million), from R$ 125 million in 4Q17 to R$ 161 million in 4Q18, mainly due to the following factors:

(i)		Sectoral financial assets update in 4Q18, in the amount of R$ 36 million;
(ii)		Increase of 18.8% (R$ 12 million) inlate payment interest and fines;
(iii)		Increase of 38.7% (R$ 5 million) inadjustments for inflation and exchange rate changes, due to (a) the increase of R$ 12 million in revenues from fines, interest and monetary adjustment relating to installment payments made by consumers; partially offset by the reductions (b) of R$ 6 million in the adjustment of the balance of tariff subsidies, as determined by Aneel, and (c) of R$ 1 million in other adjustments for inflation and exchange rate changes;
(iv)		Increase of 29.0% (R$ 2 million) in thediscount on purchase of ICMS credit;
		Partially offset by:
(v)		Reduction of 46.1% (R$ 13 million) in theincome from financial investments, due to the lower average balance of investments and the fall of CDI interbank rate;

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(vi)		Reduction of 30.1% (R$ 4 million) inother financial revenues;
(vii)		Increase of 9.5% (R$ 1 million) inPIS and Cofins on financial revenues (revenue reducer).

· Financial Expense: increase of 4.5% (R$ 10 million), from R$ 212 million in 4Q17 to R$ 222 million in 4Q18, mainly due to the following factors:

(i)		Increase of 13.8% (R$ 18 million) in interest on debt in local currency;
(ii)		Increase of 99.2% (R$ 17 million) inother financial expenses;
		Partially offset by:
(iii)		Reduction of 36.2% (R$ 25 million) inadjustments 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$ 14 million); and (b) the effect of Itaipu’s exchange variation (R$ 13 million); partially offset by (c) the increase of debt charges in foreign currency, with swap to CDI interbank rate (R$ 2 million);
(iv)		Sectoral financial liabilities update in 4Q17, in the amount of R$ 2 million (expense reducer).

In 2018, the net financial result recorded a net financial expense of R$ 310 million, a reduction of 45.3% (R$ 257 million). The items explaining these changes are as follows:

· Financial Revenue: reduction of 3.8% (R$ 23 million), from R$ 597 million in 2017 to R$ 575 million in 2018, mainly due to the following factors:

(i)		Reduction of 66.0% (R$ 144 million) in theincome from financial investments, due to the lower average balance of investments and the fall of CDI interbank rate;
(ii)		Reduction of 26.6% (R$ 13 million) inadjustments for inflation of escrow deposits;
(iii)		Reduction of 9.5% (R$ 4 million) inother financial revenues;
		Partially offset by:
(iv)		Sectoral financial assets update in 2018, in the amount of R$ 80 million;
(v)		Increase of 71.5% (R$ 29 million) inadjustments for inflation and exchange rate changes, due to: (a) the increase of R$ 38 million in revenues from fines, interest and monetary adjustment relating to installment payments made by consumers; partially offset by the reductions (b) of R$ 5 million in other adjustments for inflation and exchange rate changes, and (c) of R$ 4 million in the adjustment of the balance of tariff subsidies, as determined by Aneel;
(vi)		Increase of 106.1% (R$ 17 million) in thediscount on purchase of ICMS credit;
(vii)		Increase of 4.3% (R$ 11 million) inlate payment interest and fines.

· Financial Expense: reduction of 24.0% (R$ 279 million), from R$ 1,164 million in 2017 to R$ 885 million in 2018, mainly due to the following factors:

(i)		Reduction of 41.9% (R$ 163 million) inadjustments for inflation and exchange rate changes, due to: (a) the reduction of debt charges in foreign currency, with swap to CDI interbank rate (R$ 103 million); (b) the mark-to-market positive effect for financial operations under Law 4,131 – non-cash effect (R$ 53 million); and (c) the effect of exchange variation in Itaipu invoices (R$ 7 million);
(ii)		Sectoral financial liabilities update in 2017, in the amount of R$ 82 million (expensereducer);

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(iii) Reduction of 6.6% (R$ 41 million) ininterest on debt in local currency;

Partially offset by:

(iv) Increase of 5.6% (R$ 5 million) inother financial expenses;

(v) Reduction of 13.1% (R$ 3 million) incapitalized interest (expense reducer).

11.1.1.7) Net Income

Net Incometotaled R$ 511 million in 4Q18, compared to R$ 337 million in 4Q17, an increase of 51.8% (R$ 174 million). In 2018,Net Incometotaled R$ 1,432 million, compared to R$ 665 million in 2017, an increase of 115.4% (R$ 768 million).

11.1.2) Tariff Events

Reference dates

Tariff Process Dates
Distributor	Date
CPFL Santa Cruz	March 22^nd
CPFL Paulista	April 8^th
New RGE	June 19^th
CPFL Piratininga	October 23^rd

Tariff Revision
Distributor	Periodicity	Next Revision	Cycle
CPFL Piratininga	Every 4 years	October 2019	5^thPTRC
CPFL Santa Cruz	Every 5 years	March 2021	5^th PTRC
CPFL Paulista	Every 5 years	April 2023	5^th PTRC
New RGE	Every 5 years	June 2023	5^th PTRC

Annual tariff adjustments occurred in October 2018 and March 2019

	CPFL Piratininga	CPFL Santa Cruz
Ratifying Resolution	2,472	2,522
Adjustment	20.01%	13.31%
Parcel A	7.07%	1.12%
Parcel B	1.76%	0.90%
Financial Components	11.18%	11.29%
Effect on consumer billings	19.25%	13.31%
Date of entry into force	10/23/2018	03/22/2019

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Periodic tariff reviews occurred in 2018

	CPFL Paulista	RGE Sul	RGE
Ratifying Resolution	2,381	2,385	2,401
Adjustment	12.68%	18.44%	21.27%
Parcel A	5.53%	6.79%	6.11%
Parcel B	3.14%	4.77%	9.45%
Financial Components	4.01%	6.88%	5.71%
Effect on consumer billings	16.90%	22.47%	20.58%
Date of entry into force	04/08/2018	04/19/2018	06/19/2018

4^th Periodic Tariff Review Cycle	CPFL Paulista	RGE Sul	RGE
Date	Apr-18	Apr-18	Jun-18
Gross Regulatory Asset Base (A)	9,457	3,605	4,374
Depreciation Rate (B)	3.72%	3.87%	3.74%
Depreciation Quota (C = A x B)	352	140	164
Net Regulatory Asset Base (D)	5,193	2,389	3,032
Pre-tax WACC (E)	12.26%	12.26%	12.26%
Cost of Capital (F = D x E)	637	290	372
Special Obligations (G)	45	5	8
Regulatory EBITDA (H = C + F + G)	1,033	435	543
OPEX = CAOM + CAIMI (I)	1,245	438	523
Parcel B (J = H + I)	2,278	872	1,066
Productivity Index Parcel B ( K )	0.96%	0.98%	1.07%
Quality Incentive Mechanism ( L)	-0.17%	-0.71%	0.05%
Parcel B with adjusts (M = J * (K - L)	2,260	870	1,054
Other Revenues (N)	88	19	28
Adjusted Parcel B (O = M - N)	2,172	851	1,026
Parcel A (P)	7,785	2,653	2,816
Required Revenue (Q = O + P)	9,957	3,504	3,842

CPFL Paulista

On April 3, 2018, ANEEL approved the result of the fourth Periodic Tariff Review of distributor CPFL Paulista. The average effect to be perceived by the consumers is 16.90% and details can be found in the table above.

RGE Sul

On April 17, 2018, ANEEL approved the result of the fourth Periodic Tariff Review of distributor RGE Sul. The average effect to be perceived by the consumers was 22.47% and details can be found in the table above.

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RGE

On June 19, 2018, ANEEL approved the result of the fourth Periodic Tariff Review of distributor RGE Sul. The average effect to be perceived by the consumers was 20.58% and details can be found in the table above.

11.1.3) Operating Performance of Distribution

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 Indicators
Distributor	SAIDI (hours)									SAIFI (interruptions)
Distributor	2014	2015	2016	2017	1Q18	2Q18	3Q18	4Q18	ANEEL¹	2014	2015	2016	2017	1Q18	2Q18	3Q18	4Q18	ANEEL¹
CPFL Paulista	6.92	7.76	7.62	7.14	6.90	6.50	6.25	6.17	7.38	4.87	4.89	5.00	4.94	4.76	4.46	4.13	4.01	6.33
CPFL Piratininga	6.98	7.24	8.44²	6.97	6.37	5.93	6.01	5.92	6.74	4.19	4.31	3.97²	4.45	4.13	3.61	3.71	3.88	5.82
RGE	18.77	15.98	14.44	14.17	13.74	13.46	13.15	13.43	11.48	9.14	8.33	7.56	7.74	7.09	6.71	6.28	6.30	8.50
RGE Sul	17.75	19.11	19.45	15.58	15.30	15.54	15.98	15.56	10.79	8.87	8.42	9.41	7.62	7.05	6.51	6.34	5.89	8.30
CPFL Santa Cruz				6.20	5.80	5.61	5.61	6.01	8.75				5.12	5.26	4.98	4.89	5.09	7.88

Notes:

1) 2018 Regulatory Agency (ANEEL);

2) In the previous disclosures, we reported a SAIDI of 6.97 and a SAIFI of 3.80 for CPFL Piratininga in 2016. This number excluded the effect of a CTEEP transmission failure during a storm. However, a decision by ANEEL determined that this effect was included in the SAIDI and SAIFI statistics, so that we corrected the values, as shown in the table.

The year of 2018 presented positive historical results, mainly for the distributors of São Paulo and RGE. CPFL Santa Cruz and RGE presented the best historical result of SAIDI. CPFL Paulista and CPFL Piratininga presented the best result of SAIDI since 2010 and 2012, respectively. For the consolidated SAIFI of 2018, it was the best result for all companies in the CPFL group: CPFL Paulista, CPFL Piratininga, CPFL Santa Cruz, RGE e RGE Sul.

As regards RGE Sul specifically, the recovery plan for technical indicators remains Rural, Troncal and Urban pruning, treatment of major primary, secondary and damage recidivism, programming of services for testing and maintenance in substations and transmission lines, carry out termovision and ultrasound inspections in distribution networks, substations and transmission lines. In addition, part of the maintenance plan, improvements and extensions of the existing structure, with the forecast of exchanges of posts, capacity adjustment, modernization of substations, and installation of remote control and control equipment. This plan is part of a continuous improvement that is already under development. In addition to the significant investments being made, the significant reduction of these investments has already been observed.

Since 2019, the RGE and RGE Sul concessions have been unified, becoming a single distributor for the purpose of calculating technical indicators.

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Losses

Find below the performance of CPFL distribution companies throughout the last quarters:

12M Accumulated Losses¹	Total Losses
12M Accumulated Losses¹	4Q17	1Q18	2Q18	3Q18	4Q18	ANEEL
CPFL Energia	8.91%	8.82%	9.02%	8.86%	8.97%	8.30%
CPFL Paulista	8.94%	8.93%	9.10%	8.87%	9.09%	8.33%
CPFL Piratininga	7.70%	7.72%	7.87%	7.79%	7.90%	6.92%
RGE	9.01%	8.79%	9.05%	8.98%	8.95%	9.28%
RGE Sul	10.63%	10.24%	10.55%	10.58%	10.38%	8.90%
CPFL Santa Cruz	8.59%	8.65%	8.84%	8.09%	8.50%	7.59%

Notes:

1) The figures above were adequate to a better comparison with the regulatory losses trajectory defined by the Regulatory Agency (ANEEL). In CPFL Piratininga, RGE and RGE Sul, high-voltage customers were disregarded;

The consolidated losses index of CPFL Energia was of 8.97% in 4Q18, compared to 8.86% in 3Q18, an increase of 0.11 p.p. Compared to 4Q17 (8.91%), there was an increase of 0.06 p.p.

��

11.2) Commercialization and Services Segments

11.2.1) Commercialization Segment

Consolidated Income Statement - Commercialization (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Net Operating Revenue	963	1,044	-7.8%	3,496	3,414	2.4%
EBITDA(1)	14	53	-73.0%	96	171	-43.5%
Net Loss	10	29	-65.5%	53	90	-41.2%

Note:

(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization.

Operating Revenue

In 4Q18, net operating revenue reached R$ 963 million, representing a reduction of 7.8% (R$ 81 million).

In 2018, net operating revenue reached R$ 3,496 million, representing an increase of 2.4% (R$ 82 million).

EBITDA

In 4Q18, EBITDA totaled R$ 14 million, compared to R$ 53 million in 4Q17, a reduction of 73.0% (R$ 39 million).

In 2018, EBITDA totaled R$ 96 million, compared to R$ 171 million in 2017, a reduction of 43.5% (R$ 74 million).

Net Income

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In 4Q18, net income was R$ 10 million, compared to net income of R$ 29 million in 4Q17, a reduction of 65.5% (R$ 19 million).

In 2018, net income was R$ 53 million, compared to net income of R$ 90 million in 2017, a reduction of 41.2% (R$ 37 million).

11.2.2) Services Segment

Consolidated Income Statement - Services (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Net Operating Revenue	153	140	9.7%	533	486	9.7%
EBITDA(1)	16	27	-40.0%	95	87	8.9%
Net Income	(3)	17	-	43	55	-21.7%

Note:

(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization.

Operating Revenue

In 4Q18, net operating revenue reached R$ 153 million, representing an increase of 9.7% (R$ 14 million).

In 2018, net operating revenue reached R$ 533 million, representing an increase of 9.7% (R$ 47 million).

EBITDA

In 4Q18, EBITDA totaled R$ 16 million, compared to R$ 27 million in 4Q17, a reduction of 40.0% (R$ 11 million).

In 2018, EBITDA totaled R$ 95 million, compared to R$ 87 million in 2017, an increase of 8.9% (R$ 8 million).

Net Income

In 4Q18, net loss was R$ 3 million, compared to a net income of R$ 17 million in 4Q17.

In 2018, net income was R$ 43 million, compared to R$ 55 million in 2017, a reduction of 21.7% (R$ 12 million).

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4Q18/2018 Results | March 28, 2019

11.3) Conventional Generation Segment

11.3.1) Economic-Financial Performance

Consolidated Income Statement - Conventional Generation (R$ million)
	4Q18	4Q17	Var.	2018	2017	Var.
Gross Operating Revenue	316	324	-2.5%	1,276	1,303	-2.1%
Net Operating Revenue	285	295	-3.4%	1,144	1,190	-3.9%
Cost of Electric Power	(35)	(49)	-28.6%	(102)	(147)	-30.5%
Operating Costs & Expenses	(60)	(61)	-1.3%	(221)	(277)	-20.2%
EBIT	190	185	2.5%	821	766	7.2%
EBITDA	312	275	13.4%	1,272	1,200	6.1%
Financial Income (Expense)	(43)	(63)	-31.7%	(248)	(329)	-24.4%
Income Before Taxes	240	181	32.2%	907	750	21.0%
Net Income	234	185	26.4%	770	654	17.7%

Nota:

(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization.

11.3.1.1) Operating Revenue

In the analysis presented in this report we consider the migration of the transmission companies CPFL Piracicaba and CPFL Morro Agudo from “Others” to “Conventional Generation” segment.

In 4Q18,Gross Operating Revenuereached R$ 316 million, a reduction of 2.5% (R$ 8 million).Net Operating Revenue was of R$ 285 million,registering a reduction of 3.4% (R$ 10 million).

The main factors that affected the net operating revenue are:

Reduction of R$ 11 million in other operating revenues;
Reduction of 2.1% (R$ 4 million) in the revenue with the power supply to CPFL Paulista and CPFL Piratininga;

Partially offset by:

Increase of 6.5% (R$ 6 million) in the revenue from the plants of Rio das Antas Complex (CERAN);
Increase of R$ 2 million in the revenue with the power supply from Jaguari Geração.

In 2018, Gross Operating Revenue reached R$ 1,276 million, a reduction of 2.1% (R$ 27 million).Net Operating Revenue was of R$ 1,144 million, registering a reduction of 3.9% (R$ 46 million).

The main factors that affected the net operating revenue are:

The effect of the consolidation of the transmission companies, with the reduction of R$ 45 million in the Revenue from Construction of Concession Infrastructure;
Reduction of R$ 16 million in other operating revenues;
Reduction of 2.0% (R$ 15 million) in the revenue with the power supply to CPFL Paulista and CPFL Piratininga;

Partially offset by:

Increase of R$ 34 million in the revenue from the plants of Rio das Antas Complex (CERAN);

· Increase of R$ 15 million in the revenue with the power supply from Jaguari Geração.

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4Q18/2018 Results | March 28, 2019

11.3.1.2) Cost of Electric Power

In the analysis presented in this report we consider the migration of the transmission companies CPFL Piracicaba and CPFL Morro Agudo from “Others” to “Conventional Generation” segment.

In 4Q18, the cost of electric power reached R$ 35 million, a reduction of 28.6% (R$ 14 million), mainly due to the following factors:

Reduction of 29.2% (R$ 12 million) in the cost with Electric Energy Purchased for Resale, mainly due to the reduction in the average purchase price of the energy from BAESA, combined with the gain with reimbursement of the GSF agreement.
Reduction of 25.0% (R$ 2 million) in the cost with Charges for the Use of the Transmission and Distribution System.

In 2018, the cost of electric power reached R$ 102 million, a reduction of 30.5% (R$ 45 million), mainly due to the following factors:

· Reduction of 36.2% (R$ 44 million) in the cost with Electric Energy Purchased for Resale, mainly due to the following factors:

(i) In CPFL Geração, reduction in the cost with the purchase of energy (R$ 50 million), mainly due to the reduction in the average purchase price of the energy from BAESA, combined with the gain with reimbursement of the GSF agreement;

(ii) Reduction of R$ 9 million in the cost of energy of Rio das Antas Complex (CERAN);

(iii) Reduction of R$ 2 million in the cost with energy from CPFL Centrais Geradoras;

Partially offset by:

(iv) Increase of R$ 17 million in the cost with energy from Paulista Lajeado.

· Reduction of 5.0% (R$ 1 million) in the cost with Charges for the Use of the Transmission and Distribution System.

11.3.1.3)Operating Costs and Expenses

In the analysis presented in this report we consider the migration of the transmission companies CPFL Piracicaba and CPFL Morro Agudo from “Others” to “Conventional Generation” segment.

Operating costs and expenses reached R$ 60 million in 4Q18, compared to R$ 61 million in 4Q17, a reduction of 1.3% (R$ 1 million). In 2018, operating costs and expenses reached R$ 221 million, compared to R$ 277 million in 2017, a reduction of 20.2% (R$ 56 million).

The factors that explain these variations follow below:

PMSO

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4Q18/2018 Results | March 28, 2019

PMSO (R$ million)
	4Q18	4Q17	Variation	2018	2017	Variation
	4Q18	4Q17	%	2018	2017	%
PMSO
Personnel	9	11	-13.3%	35	39	-10.5%
Material	1	1	23.5%	3	4	-31.8%
Outsourced Services	8	7	22.0%	23	26	-14.0%
Other Operating Costs/Expenses	12	12	5.2%	41	39	4.9%
GSF Risk Premium	(5)	2	-400.0%	4	4	-
Others	18	10	80.0%	37	35	5.4%
Total PMSO	31	30	2.7%	101	109	-6.7%

PMSO item reached R$ 31 million in 4Q18, registering an increase of 2.7%, due to the following factors:

(i) Increase of 22.0% (R$ 1 million) in expenses with Outsourced Services;

(ii) Increase of 5.2% (R$ 1 million) in Other Operating Costs/Expenses;

(iii) Increase of 23.5% (R$ 0.2 million) in expenses with Material;

Partially offset by:

(iv) Reduction of 13.3% (R$ 1 million) in expenses with Personnel.

In 2018, PMSO item reached R$ 101 million, compared to R$ 109 million in 2017, registering a reduction of 6.7% (R$ 7 million), due to the following factors:

(i) Reduction of 10.5% (R$ 4 million) in expenses with Personnel;

(ii) Reduction of 14.0% (R$ 4 million) in Outsourced Services;

(iii) Reduction of 31.8% (R$ 1 million) in expenses with Material;

Partially offset by:

(iv) Increase of 4.9% (R$ 2 million) in expenses with Other Operating Costs/Expenses.

Other operating costs and expenses

Other operating costs and expenses reached R$ 29 million in 4Q18, compared to R$ 31 million in 4Q17, registering a reduction of 5.2% (R$ 2 million), explained by the variations below:

(i) Reduction of 5.0% (R$ 1 million) in Depreciation and Amortization item.

(ii) Reduction of 28.3% (R$ 0.1 million) in Costs from Construction of Concession Infrastructure (CPFL Piracicaba and CPFL Morro Agudo);

(iii) Reduction of 24.9% (R$ 0.1 million) in Private Pension Fund.

In 2018, other operating costs and expenses reached R$ 120 million, compared to R$ 168 million in 2017, registering a reduction of 28.9% (R$ 49 million), explained by the variations below:

(i) Reduction of 96.5% (R$ 44 million) in Costs from Construction of Concession Infrastructure (CPFL Piracicaba and CPFL Morro Agudo);

(ii) Reduction of 3.8% (R$ 4 million) in Depreciation and Amortization;

(iii) Reduction of 24.9% (R$ 0.5 million) in Private Pension Fund.

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4Q18/2018 Results | March 28, 2019

11.3.1.4) Equity Income

Equity Income (R$ Million)
	4Q18	4Q17	Var. R$	Var. %	2018	2017	Var. R$	Var. %
Projects
Barra Grande HPP	5	(0)	5	-	1	12	(11)	-93.3%
Campos Novos HPP	31	(3)	34	-	101	86	16	18.2%
Foz do Chapecó HPP	32	26	6	21.5%	127	121	7	5.5%
Epasa TPP	26	37	(11)	-29.6%	105	95	11	11.3%
Total	93	60	34	56.1%	335	313	22	7.0%

In 4Q18, Equity Income result reached R$ 93 million, compared to R$ 60 million in 4Q17, an increase of 56.1% (R$ 34 million).

In 2018, Equity Income result reached R$ 335 million, compared to R$ 313 million in 2017, an increase of 7.0% (R$ 22 million).

Equity Income (R$ Million)
EPASA	4Q18	4Q17	Var. R$	Var. %	2018	2017	Var. R$	Var. %

Net Revenue	121	138	(17)	-12.4%	448	421	27	6.4%
Operating Costs / Expenses	(83)	(85)	2	-2.9%	(300)	(276)	(23)	8.4%
Deprec. / Amortization	(4)	(6)	2	-26.9%	(18)	(19)	1	-3.1%
Net Financial Result	(2)	(6)	4	-71.8%	(7)	(11)	4	-38.4%
Income Tax	(5)	(8)	3	-32.6%	(13)	(14)	1	-9.1%
Net Income	26	37	(11)	-29.6%	105	95	11	11.3%

Equity Income (R$ Million)
FOZ DO CHAPECO	4Q18	4Q17	Var. R$	Var. %	2018	2017	Var. R$	Var. %

Net Revenue	110	110	1	0.5%	441	423	18	4.1%
Operating Costs / Expenses	(25)	(33)	8	-23.0%	(98)	(95)	(3)	2.7%
Deprec. / Amortization	(13)	(16)	4	-21.8%	(60)	(65)	5	-7.1%
Net Financial Result	(21)	(47)	26	-54.8%	(90)	(81)	(9)	11.0%
Income Tax	(17)	(12)	(5)	43.8%	(45)	(44)	(1)	1.2%
Net Income	32	26	6	21.5%	127	121	7	5.5%

Equity Income (R$ Million)
BAESA	4Q18	4Q17	Var. R$	Var. %	2018	2017	Var. R$	Var. %

Net Revenue	24	43	(18)	-43.0%	80	103	(23)	-22.1%
Operating Costs / Expenses	(13)	(38)	25	-66.2%	(54)	(67)	13	-19.4%
Deprec. / Amortization	(3)	(3)	(0)	0.0%	(13)	(13)	0	0.0%
Net Financial Result	(4)	(4)	0	-11.1%	(12)	(6)	(7)	115.6%
Income Tax	(0)	0	(1)	-	4	(3)	7	-
Net Income	5	(0)	5	-	1	12	(11)	-

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4Q18/2018 Results | March 28, 2019

Equity Income (R$ Million)
ENERCAN	4Q18	4Q17	Var. R$	Var. %	2018	2017	Var. R$	Var. %

Net Revenue	78	71	7	9.8%	288	283	6	2.0%
Operating Costs / Expenses	(23)	(68)	45	-66.1%	(92)	(133)	41	-30.9%
Deprec. / Amortization	(6)	(6)	0	-5.8%	(24)	(26)	1	-5.2%
Net Financial Result	(5)	(7)	2	-33.5%	(20)	1	(21)	-
Income Tax	(14)	3	(16)	-	(32)	(22)	(10)	44.2%
Net Income	31	(3)	34	-	101	86	16	18.2%

11.3.1.5) EBITDA

In 4Q18,EBITDAwas of R$ 312 million, compared to R$ 275 million in 4Q17, an increase of 13.4% (R$ 37 million).

In 2018,EBITDAwas of R$ 1,272 million, compared to R$ 1,200 million in 2017, an increase of 6.1% (R$ 73 million).

Conciliation of Net Income and EBITDA (R$ million)
	4Q18	4Q17	Var.	2,018	2,017	Var.
Net Income	234	185	26.4%	770	654	17.7%
Depreciation and Amortization	29	30		117	121
Financial Result	43	63		248	329
Income Tax /Social Contribution	5	(4)		137	96
EBITDA	312	275	13.4%	1,272	1,200	6.1%

11.3.1.6) Financial Result

Financial Result (R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Revenues
Income from Financial Investments	6	12	-51.6%	40	80	-50.1%
Adjustment for inflation of tax credits	0	0	248.5%	2	1	185.6%
Adjustment for inflation and exchange rate changes	0	(5)	-	1	19	-93.0%
Interest on loan agreements	7	0	-	18	0	-
PIS and COFINS on other finance income	(1)	(1)	16.8%	(3)	(4)	-11.7%
Others	9	9	-5.7%	18	12	45.6%
Total	21	16	28.4%	76	109	-30.1%

Expenses
Interest on debts	(59)	(65)	-9.2%	(249)	(354)	-29.5%
Adjustment for inflation and exchange rate changes	(0)	(11)	-95.7%	(52)	(71)	-26.8%
Use of Public Asset	(4)	(3)	20.1%	(18)	(8)	120.7%
Others	(1)	(0)	140.2%	(5)	(4)	20.5%
Total	(64)	(80)	-19.4%	(324)	(437)	-25.8%

Financial Result	(43)	(63)	-31.7%	(248)	(328)	-24.4%

In 4Q18, the financial result was a net expense of R$ 43 million, representing a reduction of 31.7% (R$ 20 million), compared to net financial expenses of R$ 63 million registered in 4Q17.

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4Q18/2018 Results | March 28, 2019

· Financial Revenues moved from R$ 16 million in 4Q17 to R$ 21 million in 4Q18, an increase of 28.4% (R$ 5 million), due to:

ü Revenue of R$ 7 million in 4Q18, related tointerest on loan agreements;

ü Variation of R$ 5 million inmonetary and foreign exchange updates (zero-cost collar derivative² effect of R$ 1 million in the period);

Partially offset by:

ü Reduction of 51.6% (R$ 6 million) related toincome from financial investments.

· Financial Expenses moved from R$ 80 million in 4Q17 to R$ 64 million in 4Q18, a reduction of 19.4% (R$ 15 million), due to:

ü Reduction of 95.7% (R$ 11 million) inmonetary and foreign exchange updates;

ü Reduction of 9.2% (R$ 6 million) indebt charges, mainly due to the reduction in the CDI interbank rate;

Partially offset by:

ü Increase of 20.1% (R$ 1 million) in thefinancial expenses with the Use of Public Asset (UBP);

ü Increase of 140.2% (R$ 1 million) inother financial expenses.

In 2018, the financial result was a net expense of R$ 248 million, representing a reduction of 24.4% (R$ 80 million), compared to net financial expenses of R$ 328 million registered in 2017.

· Financial Revenues moved from R$ 109 million in 2017 to R$ 76 million in 2018, a reduction of 30.1% (R$ 33 million), due to:

ü Reduction of 50.1% (R$ 40 million) inincome from financial investments;

ü Reduction of 93.0% (R$ 18 million) inmonetary and foreign exchange updates, mainly due to the effect of the zero-cost collar derivative (R$ 20 million);

Partially offset by:

ü Revenue of R$ 18 million in 2018 related toInterest on loan agreements;

ü Increase of 45.6% (R$ 6 million) inother financial income;

ü Increaseof 185.6% (R$ 1 million) related toFiscal Credit update.

· Financial Expenses moved from R$ 437 million in 2017 to R$ 324 million in 2018, a reduction of 25.8% (R$ 113 million), due to:

ü Reduction of 29.5% (R$ 104 million) indebt charges, mainly due to the reduction in the CDI interbank rate;

ü Reduction of 26.8% (R$ 19 million) inmonetary and foreign exchange updates;

Partially offset by:

ü Increase of 120.7% (R$ 10 million) in thefinancial expenses with the Use of Public Asset (UBP).

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2In 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.

4Q18/2018 Results | March 28, 2019

11.3.1.7) Net Income

In 4Q18,net incomewas of R$ 234 million, compared to a net income of R$ 185 million in 4Q17, an increase of 26.4% (R$ 49 million).

In 2018,net incomewas of R$ 770 million, compared to a net income of R$ 654 million in 2017, an increase of 17.7% (R$ 116 million).

11.4) CPFL Renováveis

11.4.1) Economic-Financial Performance

Income Statement - CPFL Renováveis ( R$ Million)
	4Q18	4Q17	Var. %	2018	2017	Var. %
Gross Operating Revenue	545	625	-12.8%	2,044	2,067	-1.1%
Net Operating Revenue	516	591	-12.7%	1,936	1,959	-1.2%
Cost of Electric Power	(59)	(124)	-52.8%	(320)	(348)	-8.0%
Operating Costs & Expenses	(314)	(268)	17.2%	(1,030)	(1,006)	2.4%
EBIT	143	199	-28.0%	586	605	-3.1%
EBITDA⁽¹⁾	298	354	-15.8%	1,209	1,222	-1.1%
Financial Income (Expense)	(129)	(124)	4.7%	(504)	(511)	-1.3%
Income Before Taxes	14	75	-81.6%	82	94	-13.1%
Net Income	107	51	108.4%	119	20	504.5%

Note:

(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization.

11.4.1.1) Operating Revenue

In 4Q18,Gross Operating Revenue reached R$ 545 million, representing a reduction of 12.8% (R$ 80 million).Net Operating Revenue reached R$ 516 million, representing a reduction of 12.7% (R$ 75 million). These variations are mainly explained by the following factors:

Wind Source:

· Reduction of R$ 34 million in revenue from wind farms mainly due to the following factors: (i) write-off of R$11 million in PROINFA agreements due to the recognition of the tax benefit, which did not materialize; (ii) positive effect of the annual and quadrennial adjustment of agreements at some wind plants in 4Q17, which did not recur in 4Q18 (R$ 8 million); (iii) reimbursement for the lower generation of plants under PROINFA (R$ 8 million); and (iv) lower generation of wind complexes in Rio Grande do Norte (R$ 7 million). These items were partially offset by the price adjustment in energy sale agreements during the period.

SHPPs Source and Holding Company:

· Reduction of R$ 56 million in revenue of SHPPs and the Holding Company, mainly due to the hedge and swap operations of intercompany of the Pedra Cheirosa wind complex in 4Q17, which increased revenues and had a counterpart in the purchase of energy and which did not recur in 4Q18. This effect was partially offset by the lower GSF in the SHPPs of Proinfa and the price adjustment in energy sale agreements.

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4Q18/2018 Results | March 28, 2019

Biomass Source:

· Increase of R$ 15 million in revenue from biomass due to the settlement of surplus generation of some plants settled at the spot market price, the strategy of seasonal adjustment of agreements and the price adjustment in energy sale agreements.

In 2018,Gross Operating Revenue reached R$ 2,044 million, representing a reduction of 1.1% (R$ 23 million).Net Operating Revenue was of R$ 1,936 million, representing a reduction of 1.2% (R$ 23 million). These variations are mainly explained by the following factors:

Wind Source:

· Increase of R$ 29 million in revenue from wind farms mainly due to the following factors: (i) the positive effect of R$ 46 million of the new energy auction through Surplus and Deficit Offset Mechanism (MCSD), since the contract price in the free market was higher than the contract price in the regulated market for the eight wind farms that participated in the auction; (ii) the commercial startup of the Pedra Cheirosa wind complex in June 2017 (R$ 29 million); and (iii) inflation adjustment in sales agreement. These effects were partially offset by the following items: (iv) lower generation at the wind complexes in Rio Grande do Norte (R$ 38 million); (v) write-off of R$11 million in PROINFA agreements due to the recognition of the tax benefit, which did not materialize; (vi) the positive effect of the annual and quadrennial adjustment of agreements at some wind plants in 2017, which did not recur in 2018 (R$ 9 million); and (vii) reimbursement for lower generation of plants under PROINFA.

SHPPs Source and Holding Company:

· Reduction of R$ 80 million in revenue from SHPPs and the Holding Company, mainly due to the swap operations of intercompany of the Pedra Cheirosa wind complex in the 4Q17 settled at the spot market price at the Holding Company, with counterpart in the purchase of energy, which was not repeated in 2018. This effect was partially offset by the lower GSF in the SHPPs of Proinfa and price adjustment in energy sale agreements.

Biomass Source:

· Increase of R$ 28 million in revenue from biomass due to the settlement at the spot market price of the surplus generation at some plants and the price adjustment of energy sale agreements.

11.4.1.2) Cost of Electric Power

In 4Q18, cost of electric power totaled R$ 59 million, representing a reduction of 52.8% (R$ 66 million). Energy purchase cost totaled R$ 34 million in 4Q18, down 65.9% compared to 4Q17 (R$ 65 million), influenced by energy purchases to meet the exposure in the spot market, hedge and to rebuild guarantees in 2017 and lower energy purchase to attend GSF. For 2018, the purchases served mostly to cover exposures of wind plants in the free market.Cost of system use fees totaled R$ 25 million in 4Q18, reduction of 1.7% in relation to 4Q17 (R$ 0.4 million).

In 2018, cost of electric power totaled R$ 320 million, representing a reduction of 8.0% (R$ 28 million). Energy purchase cost represented a reduction of 7.0% compared to 2017 (R$ 17 million), also influenced by energy purchases to meet the exposure in the spot market, hedge and to rebuild guarantees in 2017 and lower energy purchase to attend GSF. For 2018, purchases were mostly to cover the exposure of the wind farms in the free market. In 2018, cost of system use feestotaled R$ 89 million, reduction of 10.4% compared to 2017 (R$ 10 million), chiefly due to the positive effect of retroactive recovery of PIS and Cofins credits in 2Q18, partially offset by the price adjustments in connection charges and the distribution and transmission system use and connection tariffs.

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4Q18/2018 Results | March 28, 2019

11.4.1.3) Operating Costs and Expenses

Operating Costs and Expenses reached R$ 314 million in 4Q18, compared to R$ 268 million in 4Q17, representing an increase of 17.2% (R$ 46 million). In 2018,Operating Costs and Expenses reached R$ 1,030 million, compared to R$ 1,006 million in 2017, an increase of 2.4% (R$ 24 million).

The factors that explain these variations follow:

PMSO

PMSO (R$ million)
	4Q18	4Q17	Variation		2018	2017	Variation
	4Q18	4Q17	R$ MM	%	2018	2017	R$ MM	%
Reported PMSO
Personnel	(26)	(27)	0	-0.7%	(102)	(98)	(4)	3.9%
Material	(6)	(8)	2	-28.6%	(26)	(25)	(2)	6.9%
Outsourced Services	(48)	(44)	(5)	10.4%	(169)	(170)	1	-0.5%
Other Operating Costs/Expenses	(79)	(35)	(44)	128.3%	(109)	(96)	(13)	13.5%
GSF Risk Premium	(1)	(1)	1	-50.0%	(1)	(2)	1	-50.0%
Others	(78)	(33)	(45)	134.7%	(108)	(94)	(14)	15.1%
Total PMSO	(159)	(113)	(46)	41.2%	(407)	(389)	(18)	4.6%

The PMSO item reached R$ 159 million in 4Q18, compared to R$ 113 million in 4Q17, an increase of 41.2% (R$ 46 million), due to the following factors: (i) increase with the higher maintenance costs resulting from O&M services at the wind farms in Ceará, since the maintenance work was conducted by own employees in the second half of 2017; partially offset by the reduction in the purchase of bagasse and wood chips for biomass generation and the use of PIS and Cofins credits in 4Q18; (ii) increase in provisions for losses and write-off of assets in 4Q18 in relation to 4Q17; the write-off and provision for loss of project assets is due to the uncertainty of investments; additionally, balances of accounts receivable were written off due to the petition for voluntary bankruptcy filed by a supplier (Suzlon) and provisions for loss of assets in 2017.

In 2018, the PMSO item totaled R$ 407 million, compared to R$ 389 million in 2017, an increase of 4.6% (R$ 18 million), mainly due to the increase in provisions for losses and write-off of assets in 2018 in relation to 2017; the write-off and provision for loss of project assets is due to the uncertainty of investments; additionally, balances of accounts receivable were written off due to the petition for voluntary bankruptcy filed by a supplier (Suzlon) and provisions for loss of assets in 2017; partially offset by the reduction in third-party services due to lower consulting expenses.

Other operating costs and expenses

Other operating costs and expenses, represented by Depreciation and Amortization accounts, reached R$ 155 million in 4Q18, stable in relation to 4Q17. In 2018, other operating costs and expenses reached R$ 623 million, compared to R$ 617 million in 2017, registering an increase of 1.0% (R$ 6 million), due to the start-up of the Pedra Cheirosa wind farm in June 2017 and the Boa Vista II SHP in November 2018.

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4Q18/2018 Results | March 28, 2019

11.4.1.4) EBITDA

In 4Q18, EBITDA was of R$ 298 million, compared to R$ 354 million in 4Q17, a reduction of 15.8% (R$ 56 million). This result is mainly due to: (i) lower net revenue from wind farms and hedge operations; (ii) higher volume of provisions and asset write-offs in 4Q18. These items were partially offset by lower costs with energy purchases.

In 2018, EBITDA was of R$ 1,209 million, compared to R$ 1,222 million in 2017, a reduction of 1.1% (R$ 13 million). This result is chiefly due to:(i) the decrease in net revenue; (ii) higher volume of provisions and asset write-offs. These items were partially offset by lower costs with the purchase of energy.

Conciliation of Net Income and EBITDA (R$ million)
	4Q18	4Q17	Var.	2018	2017	Var.
Net income	107	51	108.4%	119	20	504.5%
Amortization	(155)	(155)		(623)	(617)
Financial Results	(129)	(124)		(504)	(511)
Income Tax /Social Contribution	93	(24)		37	(74)
EBITDA	298	354	-15.8%	1,209	1,222	-1.1%

11.4.1.5) Financial Result

Financial Result (Adjusted - R$ Million)
	4Q18	4Q17	Var.	2018	2017	Var.
Revenues
Income from Financial Investments	22	26	-16.3%	93	126	-26.2%
Late payment interest and fines	0	0	13.6%	0	1	-88.7%
Judicial Deposits Update	0	0	99.1%	1	1	140.4%
Monetary and Foreign Exchange Updates	0	2	-97.2%	0	2	-85.6%
PIS and COFINS - over Other Financial Revenues	(1)	(1)	-42.7%	(3)	(5)	-34.3%
Others	15	4	320.4%	40	13	204.8%
Total	37	31	20.4%	132	138	-4.4%

Expenses
Debt Charges	(108)	(127)	-14.6%	(451)	(559)	-19.4%
Monetary and Foreign Exchange Updates	(21)	(19)	11.5%	(70)	(72)	-1.8%
(-) Capitalized Interest	3	2	21.9%	11	30	-64.5%
Others	(40)	(11)	266.3%	(125)	(47)	163.7%
Total	(166)	(154)	-7.8%	(636)	(649)	-2.0%
	-	-
Financial Result	(129)	(124)	-4.7%	(504)	(511)	-1.3%

Net financial result registered a net financial expense of R$ 129 million in 4Q18, a reduction 4.7% (R$ 6 million). In 2018, net financial result registered a net financial expense of R$ 504 million, a reduction of 1.3% (R$ 7 million).

Financial revenues totaled R$ 37 million in 4Q18, an increase of 20.4% (R$ 6 million) due to higher revenue from inflation adjustment on amounts receivable from settlements in the CCEE (R$ 10.9million), partially offset by the lower average CDI rate in the periods (6.40% in 4Q18 vs. 7.47% in 4Q17). In 2018, financial revenues totaled R$ 132 million, a reduction of 4.4% (R$ 6 million) due tothe reduction in the average CDI rate (6.47% in 2018 vs. 10.07% in 2017), partially offset by higher income from inflation adjustment on receivables at CCEE (R$ 26 million).

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Financial expenses totaled R$ 166 million in 4Q18, an increase of 7.8% (R$ 12 million). In 2018, financial expenses totaled R$ 636 million, a reduction of 2.0% (R$ 13 million). These variations are mainly due to the reduction in the average CDI rate and the TJLP rate, partially offset by the increase in expenses with debts related projects, which, after operational startup, cease to be capitalized and affect profit or loss, and inflation adjustment on the provision for GSF.

11.4.1.6) Net Income

In 4Q18, net income was of R$ 107 million, compared to the net income of R$ 51 million in 4Q17, an increase of 108.4% (R$ 56 million). In 2018, the net income was of R$ 119 million, compared to the net income of R$ 20 million in 2017, an increase of 504.5%. This performance mainly reflects the recognition of taxable credits that had a positive impact on income tax and social contribution and the improvement in financial result, partially offset by the reduction in EBITDA.

11.4.2) Status of Generation Projects – 100% Participation

On the date of this report, the portfolio of projects of CPFL Renováveis (100% participation) totaled 2,133 MW of operating installed capacity and 97 MW of capacity under construction. The operational power plants comprises 40 Small Hydroelectric Power Plants – SHPPs (453 MW), 45 wind farms (1,309 MW), 8 biomass thermoelectric power plants (370 MW) and 1 solar power plant (1 MW). Still under construction there are 1 SHPP (28 MW) and 4 wind farms (69 MW).

Additionally, CPFL Renováveis owns wind, solar and SHPP projects under development totaling 2,418 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	453	370	1,309	1	2,133
Under construction	28	-	69	-	97
Under development	167	-	1,911	340	2,418
Total	648	370	3,289	341	4,648

Boa Vista II SHPP – Operating

The Boa Vista II SHPP, project located in the State of Minas Gerais, had its start-up in November 2018, with more than 1 year of anticipation. The installed capacity is of 29.9 MW and the physical guarantee is of 15.2 average-MW. Energy was sold through a long-term contract in the 2015 A-5 new energy auction. (price: R$ 240.47/MWh – December 2018).

Lucia Cherobim SHPP

The PCH Lucia Cherobim, project located in the State of Paraná, is scheduled to have its start-up in 2024. The installed capacity is of 28.0 MW and the physical guarantee is of 16.6 average-MW. Energy was sold through a long-term contract in the 2018 A-6 new energy auction (price: R$ 189.95/MWh – December 2018).

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Wind Farmsof the Gameleira Complex

The wind farms of the Gameleira Complex (Costa das Dunas, Figueira Branca, Farol de Touros e Gameleira), located in the State of Rio Grande do Norte, is scheduled to have its start-up in 2024. The installed capacity is of 69.3 MW and the phusical guarantee is of 39.4 average-MW. Part of the energy (12.0 average-MW) was sold through a long-term contract it the 2018 A-6 new energy auction (price: R$ 89.89/MWh – December 2018).

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12) ATTACHMENTS

12.1) Statement of Assets – CPFL Energia

(R$ thousands)

	Consolidated
ASSETS	12/31/2018	12/31/2017

CURRENT
Cash and Cash Equivalents	1,891,457	3,249,642
Consumers, Concessionaries and Licensees	4,547,951	4,301,283
Dividend and Interest on Equity	100,182	56,145
Recoverable Taxes	411,256	395,045
Derivatives	309,484	444,029
Sectoral Financial Assets	1,330,981	210,834
Concession Financial Assets	-	23,736
Other Credits	811,005	900,498
TOTAL CURRENT	9,402,316	9,581,212

NON-CURRENT
Consumers, Concessionaries and Licensees	752,795	236,539
Affiliates, Subsidiaries and Parent Company	-	8,612
Judicial Deposits	854,374	839,990
Recoverable Taxes	253,691	233,444
Sectoral Financial Assets	223,880	355,003
Derivatives	347,507	203,901
Deferred Taxes	956,380	943,199
Concession Financial Assets	7,430,149	6,545,668
Investments at Cost	116,654	116,654
Other Credits	927,440	840,192
Investments	980,362	1,001,550
Property, Plant and Equipment	9,456,614	9,787,125
Intangible	10,509,368	10,589,824
TOTAL NON-CURRENT	32,809,214	31,701,701

TOTAL ASSETS	42,211,530	41,282,912

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12.2) Statement of Liabilities – CPFL Energia

(R$ thousands)

	Consolidated
LIABILITIES AND SHAREHOLDERS' EQUITY	12/31/2018	12/31/2017

CURRENT
Suppliers	2,398,085	3,296,870
Loans and Financing	2,446,113	3,589,607
Debentures	917,352	1,703,073
Employee Pension Plans	86,623	60,801
Regulatory Charges	150,656	581,600
Taxes, Fees and Contributions	765,438	710,303
Dividend and Interest on Equity	532,608	297,744
Accrued Liabilities	119,252	116,080
Derivatives	8,139	10,230
Sectoral Financial Liabilities	-	40,111
Public Utilities	11,570	10,965
Other Accounts Payable	979,296	961,306
TOTAL CURRENT	8,415,132	11,378,688

NON-CURRENT
Suppliers	333,036	128,438
Loans and Financing	8,989,846	7,402,450
Debentures	8,023,493	7,473,454
Employee Pension Plans	1,156,639	880,360
Taxes, Fees and Contributions	9,691	18,839
Deferred Taxes	1,136,227	1,249,591
Reserve for Tax, Civil and Labor Risks	979,360	961,134
Derivatives	23,659	84,576
Sectoral Financial Liabilities	46,703	8,385
Public Utilities	89,965	83,766
Other Accounts Payable	475,396	426,889
TOTAL NON-CURRENT	21,264,015	18,717,881

SHAREHOLDERS' EQUITY
Capital	5,741,284	5,741,284
Capital Reserve	469,257	468,014
Legal Reserve	798,090	798,090
Statutory Reserve - Concession Financial Assets	-	826,600
Statutory Reserve - Strengthening of Working Capital	3,630,413	1,292,046
Other Comprehensive Income	(376,294)	(164,506)
Retained Earnings	-	-
	10,262,749	8,961,528
Non-Controlling Shareholders' Interest	2,269,634	2,224,816
TOTAL SHAREHOLDERS' EQUITY	12,532,383	11,186,344

TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	42,211,530	41,282,912

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12.3) Income Statement – CPFL Energia

(R$ thousands)

Note:

(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization, according to CVM Instruction no. 527/12.

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12.4) Cash Flow – CPFL Energia

(R$ thousands)

Consolidated

	4Q18	2018

Beginning Balance	3,578,838	3,249,642

Net Income Before Taxes	680,670	2,939,977

Depreciation and Amortization	402,411	1,594,064
Interest on Debts and Monetary and Foreign Exchange Restatements	225,980	1,117,742
Consumers, Concessionaries and Licensees	57,066	(1,006,291)
Sectoral Financial Assets	811,189	(846,216)
Accounts Receivable - Resources Provided by the CDE/CCEE	9,220	59,196
Suppliers	(1,404,098)	(848,880)
Sectoral Financial Liabilities	(55,789)	(64,361)
Accounts Payable - CDE	35,240	71,779
Interest on Debts and Debentures Paid	(288,293)	(1,353,339)
Income Tax and Social Contribution Paid	(313,835)	(816,402)
Others	(262,692)	9,419
	(783,601)	(2,083,289)

Total Operating Activities	(102,931)	856,688

Investment Activities
Acquisition of Property, Plant and Equipment, and Intangibles	(692,579)	(2,062,423)
Others	101,734	211,735
Total Investment Activities	(590,845)	(1,850,688)

Financing Activities
Loans and Debentures	1,328,256	9,610,814
Principal Amortization of Loans and Debentures, Net of Derivatives	(2,320,994)	(9,660,830)
Dividend and Interest on Equity Paid	(8,831)	(322,163)
Others	7,964	7,994
Total Financing Activities	(993,605)	(364,185)


Cash Flow Generation	(1,687,381)	(1,358,185)

Ending Balance - 12/31/2018	1,891,457	1,891,457

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12.5) Income Statement – Conventional Generation Segment

(R$ thousands)

Note:

(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12.

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12.6) Income Statement – CPFL Renováveis

(R$ thousands)

Consolidated - 100% Participation
	4Q18	4Q17	Var.	Var. %	2018	2017	Var.	Var. %
OPERATING REVENUES
Eletricity Sales to Final Consumers	5,175	6,111	(936)	-15.3%	21,417	41,469	(20,052)	-48.4%
Eletricity Sales to Distributors	536,725	614,448	(77,723)	-12.6%	2,015,036	2,016,565	(1,529)	-0.1%
Other Operating Revenues	3,159	4,847	(1,688)	-34.8%	7,949	9,238	(1,289)	-14.0%
	545,058	625,406	(80,348)	-12.8%	2,044,403	2,067,273	(22,870)	-1.1%

DEDUCTIONS FROM OPERATING REVENUES	(28,975)	(34,241)	5,266	-15.4%	(108,084)	(108,189)	104	-0.1%
NET OPERATING REVENUES	516,084	591,165	(75,082)	-12.7%	1,936,319	1,959,084	(22,765)	-1.2%

COST OF ELETRIC ENERGY SERVICES
Eletricity Purchased for Resale	(33,642)	(98,771)	65,129	-65.9%	(230,979)	(248,339)	17,361	-7.0%
Eletricity Network Usage Charges	(25,022)	(25,460)	438	-1.7%	(89,368)	(99,690)	10,322	-10.4%
	(58,664)	(124,231)	65,567	-52.8%	(320,346)	(348,029)	27,682	-8.0%
OPERATING COSTS AND EXPENSES
Personnel	(26,341)	(26,525)	184	-0.7%	(102,269)	(98,388)	(3,881)	3.9%
Material	(5,579)	(7,809)	2,230	-28.6%	(26,215)	(24,524)	(1,691)	6.9%
Outsourced Services	(48,300)	(43,737)	(4,563)	10.4%	(169,295)	(170,095)	800	-0.5%
Other Operating Costs/Expenses	(78,775)	(34,509)	(44,266)	128.3%	(109,432)	(96,442)	(12,990)	13.5%
Depreciation and Amortization	(114,803)	(116,471)	1,668	-1.4%	(465,459)	(461,694)	(3,765)	0.8%
Amortization of Concession's Intangible	(40,433)	(39,017)	(1,416)	3.6%	(157,647)	(155,323)	(2,324)	1.5%
	(314,231)	(268,068)	(46,163)	17.2%	(1,030,317)	(1,006,467)	(23,851)	2.4%

EBITDA¹	298,425	354,353	(55,929)	-15.8%	1,208,761	1,221,606	(12,844)	-1.1%

EBIT	143,189	198,866	(55,677)	-28.0%	585,655	604,589	(18,934)	-3.1%

FINANCIAL INCOME (EXPENSE)
Financial Income	37,084	30,808	6,277	20.4%	131,694	137,765	(6,070)	-4.4%
Financial Expenses	(166,410)	(154,332)	(12,078)	7.8%	(635,820)	(648,571)	12,751	-2.0%
	(129,326)	(123,524)	(5,802)	4.7%	(504,125)	(510,806)	6,681	-1.3%

INCOME BEFORE TAXES ON INCOME	13,863	75,342	(61,479)	-81.6%	81,530	93,782	(12,253)	-13.1%

Social Contribution	21,694	(10,665)	32,359	-	1,647	(29,055)	30,702	-
Income Tax	71,263	(13,421)	84,684	-	35,629	(45,075)	80,704	-

NET INCOME	106,820	51,257	55,563	108.4%	118,805	19,653	99,153	504.5%

Note:

(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12.

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12.7) Income Statement – Distribution Segment

(R$ thousands)

Consolidated
	4Q18	4Q17	Variation	2018	2017	Variation
OPERATING REVENUE
Electricity Sales to Final Customers	7,375,245	6,381,135	15.6%	27,076,283	23,755,821	14.0%
Electricity Sales to Distributors	161,915	274,833	-41.1%	1,250,487	2,018,813	-38.1%
Revenue from building the infrastructure	568,451	592,281	-4.0%	1,770,587	2,026,224	-12.6%
Adjustments to the concession´s financial asset	42,517	112,730	-62.3%	345,015	204,443	68.8%
Sectoral financial assets and liabilities	(734,837)	851,553	-	1,207,917	1,900,837	-36.5%
Other Operating Revenues	1,199,249	984,413	21.8%	4,660,027	3,862,214	20.7%
	8,612,541	9,196,944	-6.4%	36,310,317	33,768,351	7.5%

DEDUCTIONS FROM OPERATING REVENUE	(3,452,128)	(3,447,205)	0.1%	(13,842,999)	(12,691,734)	9.1%
NET OPERATING REVENUE	5,160,413	5,749,740	-10.2%	22,467,318	21,076,618	6.6%

COST OF ELECTRIC ENERGY SERVICES
Electricity Purchased for Resale	(2,542,474)	(3,402,543)	-25.3%	(12,738,247)	(12,969,727)	-1.8%
Electricity Network Usage Charges	(561,922)	(364,499)	54.2%	(2,284,056)	(1,176,976)	94.1%
	(3,104,396)	(3,767,042)	-17.6%	(15,022,304)	(14,146,703)	6.2%
OPERATING COSTS AND EXPENSES
Personnel	(245,253)	(251,375)	-2.4%	(925,513)	(920,343)	0.6%
Material	(45,985)	(45,690)	0.6%	(170,223)	(169,670)	0.3%
Outsourced Services	(239,364)	(234,545)	2.1%	(866,273)	(852,732)	1.6%
Other Operating Costs/Expenses	(208,546)	(162,914)	28.0%	(619,831)	(614,693)	0.8%
Allowance for Doubtful Accounts	(50,152)	(35,857)	39.9%	(165,942)	(155,250)	6.9%
Legal and Judicial Expenses	(73,284)	(59,017)	24.2%	(179,611)	(179,413)	0.1%
Others	(85,109)	(68,040)	25.1%	(274,278)	(280,030)	-2.1%
Cost of building the infrastructure	(568,451)	(592,280)	-4.0%	(1,770,587)	(2,026,223)	-12.6%
Employee Pension Plans	(22,089)	(27,944)	-21.0%	(88,356)	(111,820)	-21.0%
Depreciation and Amortization	(182,302)	(165,876)	9.9%	(710,265)	(645,389)	10.1%
Amortization of Concession's Intangible	(14,133)	(13,502)	4.7%	(56,531)	(58,212)	-2.9%
	(1,526,123)	(1,494,127)	2.1%	(5,207,579)	(5,399,082)	-3.5%

EBITDA¹	726,329	667,948	8.7%	3,004,231	2,234,434	34.5%

EBIT	529,894	488,570	8.5%	2,237,434	1,530,833	46.2%

FINANCIAL INCOME (EXPENSE)
Financial Income	161,151	124,905	29.0%	574,685	597,222	-3.8%
Financial Expenses	(222,015)	(212,402)	4.5%	(884,583)	(1,163,689)	-24.0%
Interest on Equity
	(60,865)	(87,496)	-30.4%	(309,898)	(566,467)	-45.3%

INCOME BEFORE TAXES ON INCOME	469,030	401,074	16.9%	1,927,537	964,366	99.9%

Social Contribution	11,181	(17,158)	-	(132,166)	(79,876)	65.5%
Income Tax	31,080	(47,012)	-	(362,954)	(219,634)	65.3%

NET INCOME	511,291	336,903	51.8%	1,432,416	664,856	115.4%

Note:

(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12.

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12.8) Economic-Financial Performance by Distributor

(R$ thousands)

Summary of Income Statement by Distribution Company (R$ Thousands)

CPFL PAULISTA
	4Q18	4Q17	Var.	2018	2017	Var.
Gross Operating Revenue	3,766,229	4,120,153	-8.6%	15,817,680	14,886,770	6.3%
Net Operating Revenue	2,279,888	2,580,722	-11.7%	9,892,570	9,326,596	6.1%
Cost of Electric Power	(1,424,800)	(1,751,526)	-18.7%	(6,769,557)	(6,453,927)	4.9%
Operating Costs & Expenses	(587,291)	(595,440)	-1.4%	(2,094,084)	(2,248,144)	-6.9%
EBIT	267,797	233,756	14.6%	1,028,929	624,525	64.8%
EBITDA⁽¹⁾	329,913	295,368	11.7%	1,287,003	860,323	49.6%
Financial Income (Expense)	(12,986)	(35,758)	-63.7%	(76,911)	(220,475)	-65.1%
Income Before Taxes	254,810	197,998	28.7%	952,019	404,050	135.6%
Net Income	205,770	162,097	26.9%	649,516	280,354	131.7%

CPFL PIRATININGA
	4Q18	4Q17	Var.	2018	2017	Var.
Gross Operating Revenue	1,516,438	1,764,173	-14.0%	6,446,884	6,402,060	0.7%
Net Operating Revenue	870,372	1,097,527	-20.7%	3,879,542	3,997,322	-2.9%
Cost of Electric Power	(550,150)	(741,957)	-25.9%	(2,725,556)	(2,828,403)	-3.6%
Operating Costs & Expenses	(249,635)	(261,778)	-4.6%	(831,908)	(843,472)	-1.4%
EBIT	70,587	93,792	-24.7%	322,078	325,447	-1.0%
EBITDA⁽¹⁾	96,237	118,106	-18.5%	422,308	421,784	0.1%
Financial Income (Expense)	(8,469)	(10,650)	-20.5%	(48,548)	(100,626)	-51.8%
Income Before Taxes	62,118	83,142	-25.3%	273,530	224,821	21.7%
Net Income	50,551	64,172	-21.2%	182,654	152,080	20.1%

RGE
	4Q18	4Q17	Var.	2018	2017	Var.
Gross Operating Revenue	2,931,138	2,886,641	1.5%	12,364,980	10,905,664	13.4%
Net Operating Revenue	1,750,031	1,794,366	-2.5%	7,590,040	6,723,754	12.9%
Cost of Electric Power	(979,140)	(1,112,562)	-12.0%	(4,852,886)	(4,272,839)	13.6%
Operating Costs & Expenses	(607,024)	(541,132)	12.2%	(1,979,630)	(1,984,159)	-0.2%
EBIT	163,868	140,672	16.5%	757,524	466,757	62.3%
EBITDA⁽¹⁾	260,783	223,155	16.9%	1,120,578	794,092	41.1%
Financial Income (Expense)	(37,948)	(35,405)	7.2%	(170,424)	(219,644)	-22.4%
Income Before Taxes	125,920	105,267	19.6%	587,100	247,112	137.6%
Net Income	231,437	99,144	133.4%	519,055	170,123	205.1%

CPFL SANTA CRUZ
	4Q18	4Q17	Var.	2018	2017	Var.
Gross Operating Revenue	398,737	425,977	-6.4%	1,680,773	1,573,857	6.8%
Net Operating Revenue	260,122	277,125	-6.1%	1,105,165	1,028,945	7.4%
Cost of Electric Power	(150,306)	(160,997)	-6.6%	(674,305)	(591,534)	14.0%
Operating Costs & Expenses	(82,173)	(95,778)	-14.2%	(301,957)	(323,307)	-6.6%
EBIT	27,642	20,350	35.8%	128,904	114,105	13.0%
EBITDA⁽¹⁾	39,395	31,320	25.8%	174,341	158,235	10.2%
Financial Income (Expense)	(1,461)	(5,683)	-74.3%	(14,015)	(25,722)	-45.5%
Income Before Taxes	26,181	14,668	78.5%	114,888	88,382	30.0%
Net Income	23,533	11,490	104.8%	81,191	62,299	30.3%

Note:(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization.

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4Q18/2018 Results | March 28, 2019

12.9) Sales within the Concession Area by Distributor (In GWh)

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12.10) Sales to the Captive Market by Distributor (in GWh)

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12.11) Reconciliation of Net Debt/EBITDA Pro Forma ratio of CPFL Energia for purposes of financial covenants calculation

(R$ million)

Note: in accordance with financial covenants calculation in cases of assets acquired by the Company.

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SIGNATURES

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

Date: March 28, 2019

CPFL ENERGIA S.A.

	By:	/S/ YueHui Pan
	Name: Title:	YueHui Pan Chief Financial Officer and Head of Investor Relations

FORWARD-LOOKING STATEMENTS

This press release may contain forward-looking statements. These statements are statements that are not historical facts, and are based on management's current view and estimates 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.

CPFL Energy (CPL) 6-KCPLPR4Q18_6K

1) MESSAGE FROM THE CEO

2) ENERGY SALES

2.1) Sales within the Distributors’ Concession Area

2.1.1) Sales by Segment – Concession Area

2.1.2) Sales to the Captive Market

2.1.3) Free Clients

3) INFORMATION ON INTEREST IN COMPANIES AND CRITERIA OF FINANCIAL STATEMENTS CONSOLIDATION

4) ECONOMIC-FINANCIAL PERFORMANCE

4.1) Opening of economic-financial performance by business segment

4.2) Sectoral Financial Assets and Liabilities

4.3) Operating Revenue

4.4) Cost of Electric Energy

4.5) Operating Costs and Expenses

4.6) EBITDA

4.7) Financial Result

4.8) Net Income

5) INDEBTEDNESS

5.1) Debt (IFRS)

5.1.1) Debt Amortization Schedule in IFRS (Dec-18)

5.2) Debt in Financial Covenants Criteria

5.2.1) Indexation and Debt Cost in Financial Covenants Criteria

5.2.2) Net Debt in Financial Covenants Criteria and Leverage

6) INVESTMENTS

6.1) Actual Investments

6.2) Investments Forecasts

7) ALLOCATION OF RESULTS

8) STOCK MARKETS

8.2) Daily Average Volume

9) CORPORATE GOVERNANCE

10) SHAREHOLDERS STRUCTURE

10.1) CPFL Renováveis’ Tender Offer

11) PERFORMANCE OF THE BUSINESS SEGMENTS

11.1) Distribution Segment

11.1.1) Economic-Financial Performance

11.1.1.1) Sectoral Financial Assets and Liabilities

11.1.1.2) Operating Revenue

11.1.1.3) Cost of Electric Energy

11.1.1.4) Operating Costs and Expenses

11.1.1.5) EBITDA

11.1.1.6) Financial Result

11.1.1.7) Net Income

11.1.2) Tariff Events

11.1.3) Operating Performance of Distribution

11.2) Commercialization and Services Segments

11.2.1) Commercialization Segment

11.2.2) Services Segment

11.3) Conventional Generation Segment

11.3.1) Economic-Financial Performance

11.3.1.1) Operating Revenue

11.3.1.2) Cost of Electric Power

11.3.1.3)Operating Costs and Expenses

11.3.1.4) Equity Income

11.3.1.5) EBITDA

11.3.1.6) Financial Result

11.3.1.7) Net Income

11.4) CPFL Renováveis

11.4.1) Economic-Financial Performance

11.4.1.1) Operating Revenue

11.4.1.2) Cost of Electric Power

11.4.1.3) Operating Costs and Expenses

11.4.1.4) EBITDA

11.4.1.5) Financial Result

11.4.1.6) Net Income

11.4.2) Status of Generation Projects – 100% Participation

12) ATTACHMENTS

12.1) Statement of Assets – CPFL Energia

12.2) Statement of Liabilities – CPFL Energia

12.3) Income Statement – CPFL Energia

12.4) Cash Flow – CPFL Energia

12.5) Income Statement – Conventional Generation Segment

12.6) Income Statement – CPFL Renováveis

12.7) Income Statement – Distribution Segment

12.8) Economic-Financial Performance by Distributor

12.9) Sales within the Concession Area by Distributor (In GWh)

12.10) Sales to the Captive Market by Distributor (in GWh)

12.11) Reconciliation of Net Debt/EBITDA Pro Forma ratio of CPFL Energia for purposes of financial covenants calculation