Companhia Paranaense de Energia - COPEL (ELP) 6-K/A Current report (foreign) (amended)

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 6-K/A

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

Securities Exchange Act of 1934

For the month of July, 2018

Commission File Number 1-14668

COMPANHIA PARANAENSE DE ENERGIA

(Exact name of registrant as specified in its charter)

Energy Company of Paraná

(Translation of Registrant's name into English)

Rua Coronel Dulcídio, 800
80420-170 Curitiba, Paraná
Federative Republic of Brazil
(5541) 3222-2027

(Address of principal executive offices)

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

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

Yes _______ No ___X____

 

                     

Companhia Paranaense de Energia

Corporate Taxpayer's ID (CNPJ/MF) 76.483.817/0001-20

State registration 10146326-50

Publicly-Held Company - CVM 1431-1

www.copel.com       copel@copel.com

Rua Coronel Dulcídio, 800, Batel - Curitiba - PR

CEP 80420-170

QUARTERLY INFORMATION

ITR

September / 2017

 

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CONTENTS
FINANCIAL STATEMENTS			3
Statements of Financial Position		3
Statements of Income		5
Statements of Income – Changes in the Third Quarter		6
Statements of Comprehensive Income		7
Statements of Comprehensive Income – Changes in the Third Quarter		8
Statements of Changes in Equity		9
Statements of Cash Flows		10
Statements of Added Value		12
NOTES TO THE FINANCIAL INFORMATION			14
1	Operations	14
2	Concessions and Authorizations	16
3	Basis of Preparation	18
4	Significant Accounting Policies	19
5	Cash and Cash Equivalents	21
6	Bonds and Securities	22
7	Trade Accounts Receivable	23
8	CRC Transferred to the State Government of Paraná	25
9	Net Sectorial Financial Assets and Liabilities	26
10	Accounts Receivable Related to the Concession	28
11	Accounts Receivable Related to Concession Compensation	30
12	Other Receivables	31
13	Taxes	31
14	Prepaid Expenses	36
15	Receivables from Related Parties	37
16	Other Temporary Investments	40
17	Judicial Deposits	40
18	Investments	41
19	Property, Plant and Equipment	44
20	Intangible Assets	49
21	Payroll, Social Charges and Accruals	51
22	Suppliers	51
23	Loans and Financing	53
24	Debentures	57
25	Post-employment Benefits	59
26	Customer Charges Due	61
27	Research and Development and Energy Efficiency	61
28	Accounts Payable Related to Concession	62
29	Other Accounts Payable	62
30	Provisions for Legal Claims	63
31	Equity	69
32	Net Operating Revenue	71
33	Operating Costs and Expenses	77
34	Financial Results	83
35	Operating Segments	84
36	Financial Instruments	87
37	Related Party Transactions	101
38	Insurance	104
39	Additional Information to the Statement of Cash Flows	104
40	Subsequent Events	105
COMMENTS ON PERFORMANCE			107
COMPOSITION OF GROUPS RESPONSIBLE FOR GOVERNANCE			116
REVIEW REPORT ON QUARTERLY INFORMATION			118
S T A T E M E N T			117

 

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FINANCIAL STATEMENTS

Statements of Financial Position

as of September 30, 2017 and December 31, 2016

All amounts expressed in thousands of Brazilian reais

3

 

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Statements of Financial Position

as of September 30, 2017 and December 31, 2016 (continued)

All amounts expressed in thousands of Brazilian reais

4

 

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Statements of Income

for the nine-month periods ended September 30, 2017 and 2016

All amounts expressed in thousands of Brazilian reais, unless otherwise stated

5

 

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Statements of Income – Changes in the Third Quarter

for the three-month periods ended September 30, 2017 and 2016

All amounts expressed in thousands of Brazilian reais

6

 

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Statements of Comprehensive Income

    for the nine-month periods ended September 30, 2017 and 2016

All amounts expressed in thousands of Brazilian reais

7

 

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Statements of Comprehensive Income – Changes in the Third Quarter

for the three-month periods ended September 30, 2017 and 2016

All amounts expressed in thousands of Brazilian reais

8

 

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Statements of Changes in Equity

for the nine-month periods ended September 30, 2017 and 2016

All amounts expressed in thousands of Brazilian reais

9

 

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Statements of Cash Flows

for the nine-month periods ended September 30, 2017 and 2016

All amounts expressed in thousands of Brazilian reais

10

 

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Statements of Cash Flows

for the nine-month periods ended September 30, 2017 and 2016 (continued)

All amounts expressed in thousands of Brazilian reais

11

 

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Statements of Added Value

for the nine-month periods ended September 30, 2017 and 2016

All amounts expressed in thousands of Brazilian reais, unless otherwise stated

12

 

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Statements of Added Value

for the nine-month periods ended September 30, 2017 and 2016 (continued)

All amounts expressed in thousands of Brazilian reais, unless otherwise stated

13

 

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NOTES TO THE FINANCIAL INFORMATION

for the nine-month period ended September 30, 2017

All amounts expressed in thousands of Brazilian reais, unless otherwise stated

1Operations

Companhia Paranaense de Energia (Copel, Company or Parent Company), with its headquarters at Rua Coronel Dulcídio, 800, Curitiba - State of Paraná, is a publicly-held mixed capital company controlled by the State of Paraná and its shares are traded on Corporate Governance Level 1 of the Special Segments Listing of B3 S.A. - Brasil, Bolsa Balcão and also on the New York Stock Exchange (NYSE) and on the Madrid Stock Exchange in the Latin American segment (Latibex).

The core activities of Copel and its subsidiaries, regulated by the Brazilian Electricity Regulatory Agency (Aneel), linked to the Ministry of Mines and Energy (MME), is to research, study, plan, build and explore the production, transformation, distribution and trading of energy in any of its forms, primarily electricity. Furthermore, Copel participates in consortiums and in private sector and mixed-capital companies for the purpose of engaging in activities, primarily in the fields of energy, telecommunications, and natural gas.

1.1 Copel’s equity interests

Copel has direct and indirect interests in subsidiaries (1.1.1), joint ventures (1.1.2), associates (1.1.3) and joint operations (1.1.4).

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1.1.1Subsidiaries
	Headquarters	Main activity	Interest
Subsidiaries			%	Investor
Copel Geração e Transmissão S.A. (Copel GeT)	Curitiba/PR	Production and transmission of electricity	100.0	Copel
Copel Distribuição S.A. (Copel DIS)	Curitiba/PR	Distribution and marketing of electricity	100.0	Copel
Copel Telecomunicações S.A. (Copel TEL)	Curitiba/PR	Telecommunication and communication	100.0	Copel
Copel Renováveis S.A. (Copel REN)	Curitiba/PR	Control and management of interests	100.0	Copel
Copel Comercialização S.A. (Copel Energia)	Curitiba/PR	Commercialization of electricity	100.0	Copel
Companhia Paranaense de Gás - Compagás	Curitiba/PR	Distribution of pipeline gas	51.0	Copel
Elejor - Centrais Elétricas do Rio Jordão S.A.	Curitiba/PR	Production of electricity	70.0	Copel
UEG Araucária Ltda.	Curitiba/PR	Production of electricity from natural gas	20.0	Copel
			60.0	Copel GeT
São Bento Energia, Investimentos e Participações S.A. (São Bento)	Curitiba/PR	Control and management of interests	100.0	Copel GeT
Nova Asa Branca I Energias Renováveis S.A.	S. Miguel do Gostoso/RN	Production of electricity from w ind sources	100.0	Copel GeT
Nova Asa Branca II Energias Renováveis S.A.	Parazinho/RN	Production of electricity from w ind sources	100.0	Copel GeT
Nova Asa Branca III Energias Renováveis S.A.	Parazinho/RN	Production of electricity from w ind sources	100.0	Copel GeT
Nova Eurus IV Energias Renováveis S.A.	Touros/RN	Production of electricity from w ind sources	100.0	Copel GeT
Santa Maria Energias Renováveis S.A.	Maracanaú/CE	Production of electricity from w ind sources	100.0	Copel GeT
Santa Helena Energias Renováveis S.A.	Maracanaú/CE	Production of electricity from w ind sources	100.0	Copel GeT
Ventos de Santo Uriel S.A.	João Câmara/RN	Production of electricity from w ind sources	100.0	Copel GeT
Cutia Empreendimentos Eólicos S.A. (Cutia)	Curitiba/PR	Control and management of interests	100.0	Copel GeT
Copel Brisa Potiguar S.A. (a)	Curitiba/PR	Control and management of interests	100.0	Copel REN
GE Olho D’Água S.A.	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	São Bento
GE Boa Vista S.A.	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	São Bento
GE Farol S.A.	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	São Bento
GE São Bento do Norte S.A.	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	São Bento
Central Geradora Eólica São Bento do Norte I S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Central Geradora Eólica São Bento do Norte II S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Central Geradora Eólica São Bento do Norte III S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Central Geradora Eólica São Miguel I S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Central Geradora Eólica São Miguel II S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Central Geradora Eólica São Miguel III S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Usina de Energia Eólica Guajiru S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Usina de Energia Eólica Jangada S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Usina de Energia Eólica Potiguar S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Usina de Energia Eólica Cutia S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Usina de Energia Eólica Maria Helena S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Usina de Energia Eólica Esperança do Nordeste S.A.(a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia
Usina de Energia Eólica Paraíso dos Ventos do Nordeste S.A. (a)	São Bento do Norte/RN	Production of electricity from w ind sources	100.0	Cutia

(a) Pre-operating stage.

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1.1.3Associates

1.1.4Joint operations (consortiums)

Joint operations	Interest (%) Copel GeT	Other consortium members
Hydroelectric Pow er Plant Gov. Jayme Canet Júnior (Mauá)	51.0	Eletrosul Centrais Elétricas S.A. (49%)
Hydroelectric Pow er Plant Baixo Iguaçu (Note 19.5.1) (a)	30.0	Geração Céu Azul S.A (subsidiarie of Neoenergia S.A.) (70%)
(a) Pre-operating stage.

2Concessions and Authorizations

2.1 Concessions contracts or authorizations obtained by Copel

Copel		Interest	% Maturity
Concession agreement / authorization of the equity
Copel DIS	Contract 046/1999, extended by 5th addendum to the contratct	100	07.07.2045
Copel TEL	Authorization Term 54/2003 - Anatel/SVP/PVST	100	Indeterminate
	Authorization Term 305/2012 - Anatel/SVP/PVST	100	Indeterminate
Elejor	Contract 125/2001 - HPP Fundão and Santa Clara	70	05.28.2037
	Authorization - SHP Fundão I and SHP Santa Clara I - 753/2002 and 757/2002	70	12.18.2032
Dona Francisca Energética	Contract 188/1998 - HPP Dona Francisca	23	08.27.2033
Foz do Chopim	Authorization 114/2000 - SHP Arturo Andreoli	36	04.23.2030
UEG Araucária	Authorization 351/1999 - TPP Araucária (60% Copel GET)	20	12.22.2029
Compagás	Concession gas distribution contract	51	07.06.2024
Dois Saltos (a)	Authorization 5,204/2015	30	04.22.2045
Paraná Gás (b)	PART-T-300_R12 4861-.0000.99/2014-00 - ANP	30	05.15.2045
Usina de Energia Eólica São João S.A. (c)	MME Ordinance 173 /2012 - WPP São João	49	03.25.2047
Usina de Energia Eólica Carnaúba S.A. (c)	MME Ordinance 204 /2012 - WPP Carnaúbas	49	04.08.2047
Usina de Energia Eólica Reduto S.A. (c)	MME Ordinance 230 /2012 - WPP Reduto	49	04.15.2047
Usina de Energia Eólica Santo Cristo S.A. (c)	MME Ordinance 233/2012 - WPP Santo Cristo	49	04.17.2047
(a) Building under construction.
(b) Entity w ith its activities paralyzed due to a Public Civil Action.
(c) Subsidiaries of Voltalia São Miguel do Gostoso I Participações S.A.
Hydroelectric Pow er Plant - HPP
Small Hydroelectric Plant - SHP
Thermal Pow er Plant - TPP
Wind Pow er Plant - WPP

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2.2  Concession contracts or authorizations obtained by Copel GeT and is investees

Copel GeT		Interest %	Maturity
ONEROUS CONCESSION BY THE USE OF PUBLIC PROPERTY - UBP
Generation Concession 001/2007- HPP Gov. Jayme Canet Júnior (Mauá)		51	07.02.2042
Generation concession 001/2011- HPP Colíder	(a)	100	01.16.2046
Ordinance 133/2011- SHP Cavernoso II		100	02.27.2046
Generation Concession 002/2012- HPP Baixo Iguaçu (a)		30	09.14.2049
Generation Concession 007/2013
HPP Apucaraninha		100	10.12.2025
HPP Chaminé		100	08.16.2026
HPP Derivação do Rio Jordão		100	11.15.2029
HPP Cavernoso		100	01.07.2031
PUBLIC SERVICE CONCESSIONS
Generation concession 045/1999
TPP Figueira		100	03.26.2019
HPP Gov. Bento Munhoz da Rocha Neto (Foz do Areia)		100	09.17.2023
HPP São Jorge		100	12.03.2024
HPP Guaricana		100	08.16.2026
HPP Gov. Ney Aminthas de Barros Braga (Segredo)		100	11.15.2029
HPP Gov. José Richa (Salto Caxias)		100	05.04.2030
Authorization 278/1999- WPP Palmas		100	09.28.2029
Dispatch 182/2002 - Hydroeletric Generating Plant - HGP Melissa, HGP Pitangui and HGP Salto do Vau (only register with ANEEL)		100	-
Generation concession 002/2016 -HPP Gov. Pedro Viriato Parigot de Souza (GPS)		100	01.05.2046
In progress for homologation from ANEEL- HPP Marumbi		100	-
Authorization Aneel 5,373/2015- HGP Chopim I (only register w ith ANEEL)		100	-
Concession agreement / authorization of the equity
UEG Araucária	Authorization 351/1999 - TPP Araucária (20% - Copel)	60	12.22.2029
Nova Asa Branca I	MME Ordinance 267/2011 - WPP Asa Branca I	100	04.24.2046
Nova Asa Branca II	MME Ordinance 333/2011 - WPP Asa Branca II	100	05.30.2046
Nova Asa Branca III	MME Ordinance 334/2011 - WPP Asa Branca III	100	05.30.2046
Nova Eurus IV	MME Ordinance 273/2011 -WPP Eurus IV	100	04.26.2046
Santa Maria	MME Ordinance 274/2012 - WPP SM	100	05.07.2047
Santa Helena	MME Ordinance 207/2012 - WPP Santa Helena	100	04.08.2047
Ventos de Santo Uriel	MME Ordinance 201/2012 - WPP Santo Uriel	100	04.08.2047
GE Boa Vista	MME Ordinance 276 /2011 - WPP Dreen Boa Vista	100	04.27.2046
GE Farol	MME Ordinance 263 /2011 - WPP Farol	100	04.19.2046
GE Olho D’Água	MME Ordinance 343 /2011 - WPP Dreen Olho D'Água	100	05.31.2046
GE São Bento do Norte	MME Ordinance 310 /2011 - WPP Dreen São Bento do Norte	100	05.18.2046
Esperança do Nordeste	MME Ordinance 183/2015 - WPP Esperança do Nordeste (a)	100	05.10.2050
Paraíso dos Ventos do Nordeste	MME Ordinance 182/2015 - WPP Paraíso dos Ventos do Nordeste (a)	100	05.10.2050
Usina de Energia Eólica Jangada	Resolution 3,257/2011 - WPP GE Jangada (a)	100	01.04.2042
Maria Helena	Resolution 3,259/2011 - WPP GE Maria Helena (a)	100	01.04.2042
Usina de Energia Eólica Potiguar	MME Ordinance 179/2015 - WPP Potiguar (a)	100	05.10.2050
Usina de Energia Eólica Guajiru	Resolution 3,256/2011 - WPP Dreen Guajiru (a)	100	01.04.2042
Usina de Energia Eólica Cutia	Resolution 3,258/2011 - WPP Dreen Cutia (a)	100	01.04.2042
São Bento do Norte I	Ordinance 349/2015 - WPP São Bento do Norte I (a)	100	08.03.2050
São Bento do Norte II	Ordinance 348/2015 - WPP São Bento do Norte II (a)	100	08.03.2050
São Bento do Norte III	Ordinance 347/2015 - WPP São Bento do Norte III (a)	100	08.03.2050
São Miguel I	Ordinance 352/2015 - WPP São Miguel I (a)	100	08.03.2050
São MigueI lI	Ordinance 351/2015 - WPP São Miguel II (a)	100	08.03.2050
São Miguel III	Ordinance 350/2015 - WPP São Miguel III (a)	100	08.03.2050
(a) Building under construction.

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Copel GeT		Interest %	Maturity
Transmission lines and substations concession agreements
Contract 060/2001 (extended by 3rd addendum to the contratct) - Transmission facilities – several joint ventures		100	12.31.2042
Contract 075/2001 - Transmission line Bateias - Jaguariaíva		100	08.16.2031
Contract 006/2008 - Transmission line Bateias - Pilarzinho		100	03.16.2038
Contract 027/2009 - Transmission line Foz do Iguaçu - Cascavel Oeste		100	11.18.2039
Contract 010/2010 - Transmission line Araraquara 2 - Taubaté (a)		100	10.05.2040
Contract 015/2010 - Substation Cerquilho III		100	10.05.2040
Contract 022/2012 - Transmission line - Foz do Chopim - Salto Osório C2; Transmission line 230 kV Londrina - Figueira		100	08.26.2042
Contract 002/2013 - Transmission line - Assis - Paraguaçu Paulista II; Substation 230/88 kV Paraguaçu Paulista II		100	02.24.2043
Contract 005/2014 - Transmission line - Bateias - Curitiba Norte; Substation 230/138 kV Curitiba Norte		100	01.28.2044
Contract 021/2014 - Transmission line Foz do Chopim - Realeza; Substation Realeza 230/138 kV - Pátio novo 230 kV		100	09.04.2044
Contract 022/2014 - Transmission line Assis - Londrina		100	09.04.2044
Contract 006/2016 - Transmission line 525kV Curitiba Leste - Blumenau C1 (a)		100	04.06.2046
Contract 006/2016 - Transmission line 230 kV Uberaba - Curitiba Centro C1 e C2 (Underground) (a)
Substation 230/138 kV Curitiba Centro (SF6) - 230/138 kV - 2 x ATF 150 MVA (a)
Substation 230/138 kV Medianeira (Pátio novo 230 kV) - 2 x 150 MVA (a)
Transmission line 230 kV Baixo Iguaçu - Realeza (a)
Substation 230/138 kV Andirá Leste - 2 x ATR 150 MVA (a)
Concession agreement / authorization of the equity
Costa Oeste Transmissora	Contract 001/2012 - Transmission line Cascavel Oeste - Umuarama; Substation Umuarama 230/20138 kV	51	01.11.2042
Transmissora Sul Brasileira Contract 004/2012 - Transmission line Nova Santa Rita - Camaquã 3;		20	05.09.2042
	Transmission line 230 kV Camaquã 3 - Quinta; Transmission line 525 kV Salto Santiago - Itá;
	Transmission line 525 kV Itá - Nova Santa Rita; Substation Camaquã 3 230/69/2013,8 kV
Caiuá Transmissora	Contract 007/2012 - Transmission line Umuarama - Guaíra; Transmission line 230 kV Cascavel Oeste - Cascavel Norte;	49	05.09.2042
	Substation Santa Quitéria 230/69-13,8 kV; Substation Cascavel Norte 230/20138-13,8 kV
Marumbi Transmissora	Contract 008/2012 - Transmission line Curitiba - Curitiba Leste; Substation Curitiba Leste 525/230 kV	80	05.09.2042
Integração Maranhense	Contract 011/2012 - Transmission line Açailândia - Miranda II	49	05.09.2042
Matrinchã Transmissora	Contract 012/2012 - Transmission line Paranaíta - Ribeirãozinho; Transmission line 500 kV Paranaíta - Cláudia;	49	05.09.2042
	Substation Cláudia 500 kV; Transmission line 500 kV Cláudia - Paranatinga; Substation Paranatinga 500 kV;
	Transmission line 500 kV Paranatinga - Ribeirãozinho
Guaraciaba Transmissora	Contract 013/2012 - Transmission line Ribeirãozinho - Marimbondo II;	49	05.09.2042
	Transmission line 500 kV Ribeirãozinho - Rio Verde Norte; Transmission line 500 Rio Verde Norte - Marimbondo II;
	Sectioning of Transmission lines 500 kV Marimbondo - Araraquara, at Substation Marimbondo II;
	Substation Marimbondo II 500 kV
Paranaíba Transmissora	Contract 007/2013 - Transmission line - T 500 kV Barreiras II - Rio das Éguas;	24.5	05.01.2043
	Transmission line 500 kV Rio das Éguas - Luziânia; Transmission line 500 kV Luziânia - Pirapora 2
Mata de Santa Genebra	Contract 001/2014 - Transmission line - Itatiba - Bateias (a); Transmission line 500 kV Itatiba - Bateias (a);	50.1	05.13.2044
	Transmission line 500 kV Araraquara 2 - Itatiba (a); Transmission line 500 kV Araraquara 2 - Fernão Dias (a);
	Substation Santa Bárbara D'Oeste 440 kV (a); Substation Itatiba 500 kV (a);
	Substation 500/440 kV Fernão Dias (a)
Cantareira Transmissora	Contract 019/2014 - Transmission line - Estreito - Fernão Dias (a)	49	09.04.2044
(a) Buildings under construction.

3Basis of Preparation

3.1 Statement of compliance

The quarterly information is being presented considering the provisions of CPC 21 (R1) and IAS 34 – Interim Financial Reporting. Consequently, certain information contained in the notes to the financial statements for the year ended December 31, 2016, and which was not subject to modifications in the first nine months of 2017, is not being presented. Therefore, this quarterly information should be read together with the financial statements as at December 31, 2016, available on the websites of the CVM and Copel.

Company's management believes that all the relevant information used in its management is evidenced in the individual and consolidated quarterly information.

This quarterly information is being restated, as described in Note 4.1 which includes information mainly on the investment held by the indirect subsidiary UEG Araucária, a matter that also resulted in the restatement of the Financial Statements for the year ended December 31, 2017 on May 14, 2018, together with the comparative restatement of the information related to December 31, 2016 and January 1, 2016.

We highlight that the information presented in Note 4.1 to this Quarterly Information is consistent with the information in Note 4.1 to the Financial Statements for the year ended December 31, 2017 and with the prior disclosures.

The issue of this quarterly information was approved by Management on June 13, 2018.

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3.2  Functional and presentation currency

The individual and consolidated quarterly information is presented in Brazilian Reais, which is the functional currency of the Company. The financial information has been rounded to the nearest thousand, unless otherwise indicated.

3.3  Basis of measurement

The quarterly information was prepared based on the historical cost, except for certain financial instruments measured at fair value and investments.

3.4  Use of estimates and judgments

In the preparation of this quarterly information, Management used judgments, estimates and assumptions that affect the application of accounting policies and the reported amounts of assets, liabilities, income and expenses of the Company and its subsidiaries. Actual results may differ from those estimates.

Estimates and assumptions are reviewed on a continuous basis. Reviews of estimates are recognized in the period in which it is revised (prospective basis).

The information on the use of estimates and judgments involving the application of the accounting policies adopted that has effects on the amounts recognized in the quarterly information is the same as that disclosed in Note 3.4 to the financial statements as of December 31, 2016.

4Significant Accounting Policies

The Company’s Management made the following adjustments to the Quarterly Information as at September 30, 2017 with the respective comparative balances as at December 31, 2016 and September 30, 2016:

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4.1  Fair value of the indemnifiable concession asset

After reviewing its accounting practices at December 31, 2016, the Company and its electricity distribution subsidiary, aiming at the best presentation of its operational and financial performance, concluded that the changes in the expected cash flows of the indemnifiable financial asset of Copel DIS, which was originally presented in the Financial Income, in Financial Results, would be better classified in the group of Operating Revenue, together with other revenues related to its activity. This allocation better reflects the electricity distribution business model and provides a better presentation on its performance. This conclusion is supported by the fact that:

i) Investing in infrastructure is the indispensable activity of the electricity distribution business, whose management model is supported in building, maintaining and operating this infrastructure;

ii) The return on infrastructure investment in the distribution business is determined by the fair value of that infrastructure, either the amortizable portion over the contract horizon (intangible asset), or the portion indemnifiable by the Granting Authority to its final (financial asset), plus regulatory Weighted Average Cost of Capital – WACC; and

iii) Tariff revenues represent both the return on the intangible asset and a portion of the return on the financial asset, both of which are part of the regulatory remuneration base. Tariff revenues are fully recorded as part of the "Net Operating Revenue".

Beginning on December 31, 2016, according to CPC 23/IAS 8 - Accounting Policies, Changes in Accounting Estimates and Errors, the Company and its subsidiary changed their accounting policy previously adopted to an accounting policy that best reflects the performance of their business (for the above-mentioned arguments) and therefore made retrospective reclassifications in its financial statements, reclassifying the amount of R$129,311 from finance income to net operating revenue.

4.1.2 Investments

During the preparation of our unaudited consolidated interim financial information as of September 30, 2017, the Company's Management identified an investment by its indirect subsidiary UEG Araucária Ltda. in a Multimarket Investment Fund, which held shares of other investment funds that in turn invested in a private company, whose main asset was a real estate development. As of September 30, 2017, such investment corresponded to R$157,079 and was recognized under “Bonds and Securities”, in current assets, because, according to information delivered by the management of UEG Araucária to the Company’s Management, that investment was made in a wholly-owned fund, whose benchmark was 103.5% of the CDI (Interbank Deposit Certificate) rate and that was composed of shares issued by other investment funds and government bonds, with immediate liquidity and that were available for sale. This investment amounted to R$165,749 as of December 31, 2016, also recognized under “Bonds and Securities”.

In order to determine the value of such investment and its accounting classification, as well as the extent of any possible impact, the Company's Management relied on independent experts in accordance with best governance practices, including an internal investigation into the circumstances of the investment. The valuation has already been concluded and the investigations are in their final stage. These investigations found that the investment occurred strictly in the UEG Araucária and violated Copel’s investment policy, which authorizes investments in wholly-owned investment funds only to the extent such funds invest exclusively in bonds issued by the Brazilian federal government or by financial institutions controlled by the Brazilian federal government.

Based on the information available during the preparation of the financial statements for 2017, we concluded that it is necessary to recognize a provision for the impairment of the investment in light of its specific characteristics, such as the status of its underlying real estate development and the outlook for its future cash flow generation. It was also evaluated that this provision should have been recorded in prior years if the information known during the preparation of these financial statements, which were already available at the time, had been considered when preparing the financial statements for 2016 and 2015.

In the course of preparing the financial statements, were analyzed all legal and corporate documents of the investment fund and it was concluded that from July 2015, UEG Araucária started to have significant influence in the private company, even though indirectly. Thus, from July 2015, the remaining balance of the investment, until then classified as a financial instrument measured by its fair value, became measured and disclosed as an associate, and the effects of the change in the asset classification were recorded in the company's profit or loss of that year.

Supported by a report prepared in March 2018 by an independent appraisers engaged by Copel, the Company’s Management determined the fair value of the financial instrument as of July 2015, and the remaining balance, already considered as an investment in associate, was reduced by a provision for impairment, so the Company’s equity was decreased by R$124,950 and the non-controlling interests by R$31,237. The balance of this investment as at December 31, 2016 is R$9,562.

Until September 30, 2016, the provision for impairment is R$48,314, of which R$47,085 recorded as equity in earnings of investees, R$3,277 in financial expenses and R$2,048 in financial income, with an effect of R$38,651 in the line item equity in earnings of investees in the individual financial statements of the Parent Company. As of September 30, 2017, the provision for impairment is R$5,830 of which R$5,712 recorded as equity in earnings of investees and R$11,542 in financial income, with an effect of R$4,664 in the line item equity in earnings of investees in the individual financial statements of the Parent Company.

The balance of this investment as at December 31, 2016 is R$6,722.

4.1.3 Provisions for legal claims - CVA tax regime

In 2017 Copel DIS recognized prior period adjustments to the account of provisions related to tax litigation due to the taxation of the Offsetting and Variation of Tranche A account - CVA, currently classified as Sectorial financial assets and liabilities. The impact of these adjustments represents as at December 31, 2016 an increase by R$31,995 (R$40,005 as at September 30, 2016) in the Provision for legal claims, in noncurrent liabilities, and an increase by R$10,878 (R$13,602 as at September 30, 2016) in Deferred taxes in noncurrent assets, versus Financial expenses and Deferred income tax and social contribution at Statements of income.

The effect in the line item equity in earnings of investees in the individual financial statements of the Parent Company is R$21,117 as at December 31, 2016 (R$26,403 as at September 30, 2016) and, consequently, a decrease in the Company’s equity in the same amounts.

Upon joining Special Tax Regularization Program - Pert in August 2017, as described in Note 13.3.1, the liability of R$31,995 and the asset of R$10,878 were reversed from Provision for legal claims and from Deferred taxes against Financial expenses and Deferred income tax and social contribution accounts, in the Statements of income of September 30, 2017, with a positive effect of R$21,117 in the line item equity in earnings of investees in the individual financial statements of the Parent Company.

4.1.4 Effects of restatement of comparative balances

Based on the guidelines of CPC 23 - Accounting Policies, Changes in Accounting Estimates and Correction of Errors, the Financial Statements are being restated for comparability purposes, with the following adjustments:

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5Cash and Cash Equivalents

	Parent Company		Consolidated
	09.30.2017	12.31.2016	09.30.2017	12.31.2016
Cash and bank accounts	845	2,452	147,154	173,020
Financial investments w ith immediate liquidity	403,946	43,644	1,158,246	809,053
	404,791	46,096	1,305,400	982,073

These comprise cash on hand, deposits with banks and short-term highly liquid investments, which can be redeemed in cash within 90 days from the investment date.

Financial investments refer to Bank Deposit Certificates - CDBs and Repurchase Agreements, which are the sale of a security with the commitment of the seller (Bank) to repurchase it, and of the purchaser to resell it in the future. Investments are remunerated between 60% and 100% of the rate of change of the Interbank Deposit Certificate (Certificado de Depósito Interbancário - CDI).

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6Bonds and Securities

Copel and its subsidiaries have securities that yield variable interest rates. The term of these securities ranges from 1 to 60 months from the end of the reporting period. None of these assets is overdue or impaired at period-end.

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7Trade Accounts Receivable

Consolidated	Balances	Overdue	Overdue for	Total	Total
	falling due	up to 90 days	more than 90 days	09.30.2017	12.31.2016
Customers
Residential	294,560	175,415	36,334	506,309	447,345
Industrial	282,057	31,168	67,718	380,943	313,963
Commercial	245,441	44,383	33,229	323,053	267,647
Rural	50,346	15,743	7,741	73,830	68,611
Public Entities	37,337	7,770	11,680	56,787	64,581
Public lighting	34,891	52	239	35,182	28,991
Public service	36,388	583	1,899	38,870	34,391
Unbilled	455,580	-	-	455,580	377,498
Energy installments plan (7.1)	129,091	15,582	43,817	188,490	193,426
Low income subsidy - Eletrobras	13,390	-	-	13,390	12,128
Other receivables	52,649	16,700	66,134	135,483	159,051
	1,631,730	307,396	268,791	2,207,917	1,967,632
Concessionaires and Permission holder
Energy supplies
Energy purchase agreements in the
regulated market - CCEAR	69,854	961	6,334	77,149	116,516
Bilateral contracts	186,022	3,761	4,663	194,446	102,570
CCEE (7.2)	304,533	-	181,560	486,093	354,662
Unbilled	33,249	-	-	33,249	28,873
Quota system and Reimbursement to generators	10,313	150	2,392	12,855	17,415
	603,971	4,872	194,949	803,792	620,036
Charges from using transmission grid	125,760	3,613	7,302	136,675	104,831
Telecommunications	29,358	14,596	36,862	80,816	81,374
Gas distribution	49,422	3,482	9,426	62,330	69,934
Allow ance for doubtful accounts (7.3)	(1,782)	(2,134)	(363,296)	(367,212)	(355,666)
	2,438,459	331,825	154,034	2,924,318	2,488,141
Current				2,653,868	2,217,355
Noncurrent				270,450	270,786

7.1 Energy installments plan

The trade accounts receivable renegotiated are discounted to present value, taking into consideration the future value, the maturity dates, the dates of settlement and the discount rate ranging from 0.19% to 3.81% p.m.

7.2 CCEE

Of the balance presented, the most significant amounts are R$201,151 receivable by Copel GeT and R$251,807 receivable by Copel DIS.

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Of the balance of Copel GeT, the amounts of R$2,744 and R$2,798 were received on October 10, 2017 and November 10, 2017 and the amount of R$14,049 is expected to be received on December 10,  2017, and the remaining balance of R$181,560 derives from sale of energy to be reprocessed by CCEE for the period from January to May 2015 as a result of the request for exemption from responsibility for complying with trading contracts of Colíder Hydroelectric Power Plant for delivery of energy (Note 19.4). Of the contested portion there is a register of estimated losses for doubtful accounts of R$119,665. On March 14, 2010, ANEEL denied the Company's request for reconsideration of ANEEL Order No. 1,580/2016, which had maintained unaltered the implementation schedules and the energy supply schedules related to the plant. Considering that the plant's start-up schedule was impacted by acts of public authorities and unforeseeable or force majeure events occurred during the implementation of the project, the Company will refer the matter to the court with the conviction that the decision of the Agency will be reversed.

Of the balance of Copel DIS, the amounts received were R$26,528 on October 3, 2017, R$118,630 on October 10.2017, R$26,000 on November 6, 2017 and R$80,649 on November 8, 2017.

7.3 Allowance for doubtful accounts

Consolidated	Balance as of	Additions /	Reversal	Balance as of
	January 1º, 2017	(reversals)	of write offs	September 30, 2017
Customers
Residential	66,502	25,318	(41,238)	50,582
Industrial	66,563	19,524	(4,751)	81,336
Commercial	67,075	17,148	(13,081)	71,142
Rural	3,130	2,404	(36)	5,498
Public Entities	12,981	(1,298)	(418)	11,265
Public lighting	104	91	-	195
Public service	1,111	280	-	1,391
	217,466	63,467	(59,524)	221,409
Concessionaries and permission holder
CCEE (7.3.1)	119,665	-	-	119,665
Concessionaries and permission holder	13,077	1,582	(9)	14,650
	132,742	1,582	(9)	134,315
Telecommunications	534	4,838	-	5,372
Gas distribution	4,924	1,267	(75)	6,116
	355,666	71,154	(59,608)	367,212

7.3.1CCEE

An allowance for doubtful accounts was recognized in 2015 in the amount of R$119,665 in respect of differences between the sales price of the energy traded under the Contracts for Purchasing and Selling Electricity in the Regulated Market (CCEARs) of the Colíder Hydroelectric Power Plant and the difference settlement price (PLD). The Company will await the decision on the request for a revision of the power plant’s operations start date to reverse those estimated losses.

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8CRC Transferred to the State Government of Paraná

By means of a fourth amendment dated January 21, 2005, the Company renegotiated with the State of Paraná the outstanding CRC (Account for Compensation of Income and Losses) balance as of December 31, 2004, in the amount of R$1,197,404, to be paid in 244 installments under the Price amortization system, adjusted according to the IGP-DI inflation index plus interest of 6.65% p.y., which are received monthly, with the first installment due on January 30, 2005 and the others due in subsequent and consecutive months.

As per the request of the Paraná State Government, approved by the Company’s Board of Directors on June 16, 2016, contingent upon the approval of the Ministry of Finance, the Novation of the Term of Adjustment of CRC is under way, comprising: (i) between April and December 2016, total grace period for payments of interest and principal; and (ii) between January and December 2017, a grace period only for the principal amount, with interest payable monthly. The other clauses will be maintained, including the maintenance of monetary restatement and interest currently effective, thus not affecting the global net present value of such agreement.

As from January 2017, the State of Paraná has complied with the agreed terms and has been paying monthly the amount referring to the interest of the installment.

The Company’s management and the State of Paraná formalized on October 31, 2017 the fifth amendment.

8.1 Changes in CRC

Parent Company and Consolidated	Current	Noncurrent	Total
Balance as of January 1, 2017	-	1,522,735	1,522,735
Interest	72,928	-	72,928
Monetary variations	(877)	(30,085)	(30,962)
Transfers	123,179	(123,179)	-
Amortizations	(72,928)	-	(72,928)
Balance as of September 30, 2017	122,302	1,369,471	1,491,773

8.2 Maturity of noncurrent installments

Parent Company and Consolidated	09.30.2017
2018	42,097
2019	175,333
2020	186,993
2021	199,429
2022	212,692
After 2022	552,927
	1,369,471

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9Net Sectorial Financial Assets and Liabilities

9.1 Composition of the net sectorial financial assets and liabilities balances per tariff cycle

Consolidated		09.30.2017		12.31.2016
	Current Noncurrent		Current Noncurrent
Sectorial financial assets - Electricity rate adjustment recoverable 2018
Portion A
Charges for using the transmission system - basic grid	4,402	13,208	-	-
Electricity purchased for resale - Itaipu	84,276	252,830	-	-
System Service Charges - ESS	(75,607)	(226,822)	-	-
Energy Development Account - CDE	(13,284)	(39,853)	-	-
Proinfa	(20)	(61)	-	-
Electricity purchased for resale - CVA Energ	132,270	396,810	-	-
Transport of energy purchased from Itaipu	1,198	3,594	-	-
Other financial components
Overcontracting	(49,419)	(148,256)	-	-
Neutrality	11,542	34,625	-	-
Angra III Adjustment	(551)	(1,653)	-	-
Tariff refunds	(5,701)	(17,102)	-	-
Hydrological risk	(24,198)	(72,595)	-	-
	64,908	194,725	-	-

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Consolidated	09.30.2017		12.31.2016
	Current	Noncurrent	Current	Noncurrent
Sectorial financial liabilities - Electricity rate adjustment recoverable 2016
Portion A
Charges for using the transmission system - basic grid	-	-	(67)	-
Electricity purchased for resale - Itaipu	-	-	354,651	-
ESS	-	-	(65,712)	-
CDE	-	-	146,005	-
Proinfa	-	-	15,179	-
Electricity purchased for resale - CVA Energ	-	-	(318,905)	-
Transport of energy purchased from Itaipu	-	-	3,759	-
Other financial components		-
Overcontracting	-	-	(4,794)	-
Extraordinary Tariff Review	-	-	(257,353)	-
Neutrality	-	-	40,564	-
Financial exposure	-	-	(16,250)	-
Other	-	-	149	-
	-	-	(102,774)	-
Sectorial financial liabilities - Electricity rate adjustment recoverable 2017
Portion A
Charges for using the transmission system - basic grid	16,916	-	4,239	4,239
Electricity purchased for resale - Itaipu	54,731	-	34,717	34,717
ESS	(255,305)	-	(103,853)	(103,853)
CDE	(128,144)	-	(37,697)	(37,697)
Proinfa	(7,787)	-	1,057	1,057
Electricity purchased for resale - CVA Energ	(256,826)	-	(108,610)	(108,610)
Transport of energy purchased from Itaipu	4,252	-	1,972	1,972
Other financial components
Overcontracting	133,703	-	80,482	80,482
Neutrality	83,019	-	75,206	75,206
Tariff refunds	(18,957)	-	-	-
Angra III Adjustment	76,673	-	-	-
Other	4,595	-	-	-
	(293,130)	-	(52,487)	(52,487)
Sectorial financial liabilities - Tariff Review 2021
Financial components
Tariff refunds	-	(89,131)	-	(71,244)
	-	(89,131)	-	(71,244)
	(293,130)	(89,131)	(155,261)	(123,731)

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9.2 Changes in net sectorial financial assets and liabilities

	Balance as of	Operating revenues		Financialresults		Balance as of
	January 1, 2017	Constitution	Amortization	Updating	Rate flags	September 30, 2017
Portion A
Charges for using the transmission system - basic grid	8,411	32,248	(6,196)	63	-	34,526
Electricity purchased for resale - Itaipu	424,085	336,619	(400,395)	31,528	-	391,837
ESS	(273,418)	(413,607)	171,163	(41,872)	-	(557,734)
CDE	70,611	(154,991)	(105,952)	9,051	-	(181,281)
Proinfa	17,293	(14,693)	(13,221)	2,753	-	(7,868)
Electricity purchased for resale - CVA Energ	(536,125)	599,912	425,385	(5,508)	(211,410)	272,254
Transport of energy purchased f rom Itaipu	7,703	5,820	(5,640)	1,161	-	9,044
Other financial components
Overcontracting	156,170	(180,724)	(44,519)	5,101	-	(63,972)
Extraordinary Tariff Review	(257,353)	-	257,353	-	-	-
Neutrality	190,976	8,918	(71,183)	475	-	129,186
Financial exposure	(16,250)	-	16,250	-	-	-
Angra III Adjustment	-	97,426	(28,279)	5,322	-	74,469
Tariff refunds	(71,244)	(58,855)	6,992	(7,784)	-	(130,891)
Hydrological risk	-	(95,302)	-	(1,491)	-	(96,793)
Others	149	5,569	(1,844)	721	-	4,595
	(278,992)	168,340	199,914	(480)	(211,410)	(122,628)
Current	(155,261)					(228,222)
Noncurrent	(123,731)					105,594

10Accounts Receivable Related to the Concession

Consolidated		09.30.2017	12.31.2016
Distribution concession agreement (10.1)		651,955	614,806
Bonus from the grant of concession agreements under the quota system (10.2)		601,686	586,706
Transmission concession agreements (10.3)		1,425,056	1,342,055
Remeasurement of RBSE financial assets (10.4)		1,437,151	1,186,985
Concession agreement - gas distribution (10.5)		97,221	83,378
		4,213,069	3,813,930
	Current	152,228	65,595
	Noncurrent	4,060,841	3,748,335

10.1 Distribution concession agreement

	Noncurrent
Balance as of January 1, 2017	614,806
Donations and grants received	76
Transfers from intangible assets (Note 20.1)	30,784
Transfers to other receivables (assets held for disposal)	(3,711)
Fair value recognition	10,020
Loss on disposal	(20)
Balance as of September 30, 2017	651,955

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10.2 Bonus from the grant of concession agreements under the quota system

	Current	Noncurrent	Total
Balance as of January 1, 2017	1,269	585,437	586,706
Transfers from current to noncurrent	48,415	(48,415)	-
Transfers to electricity grid use charges - customers	(46,052)	-	(46,052)
Interest (Note 32.2)	-	61,032	61,032
Balance as of September 30, 2017	3,632	598,054	601,686

10.3 Transmission concession agreement

		Noncurrent
			Special
	Current	Assets	liabilities	Total
Balance as of January 1, 2017	11,278	1,407,792	(77,015)	1,342,055
Transfers from current to noncurrent	60,350	(60,350)	-	-
Transfers to electricity grid use charges - customers	(56,469)	-	-	(56,469)
Transfers to property, plant and equipment	-	(28,847)	-	(28,847)
Remuneration	-	88,821	-	88,821
Construction income	-	79,785	(289)	79,496
Balance as of September 30, 2017	15,159	1,487,201	(77,304)	1,425,056

10.4 Remeasurement of RBSE financial assets

	Current	Noncurrent	Total
Balance as of January 1, 2017	53,048	1,133,937	1,186,985
Gain on the cash flow from the RBSE assets	-	132,036	132,036
Increase in the estimated amount due to the approval of the report on RBSE assets	-	183,015	183,015
Transfers from current to noncurrent	145,274	(145,274)	-
Transfers to electricity grid use charges - customers	(64,885)	-	(64,885)
Balance as of September 30, 2017	133,437	1,303,714	1,437,151

Copel GeT extended the concession agreement 060/2001, pursuant to Law No. 12,783/2013, and recognized receivables related to the electricity transmission assets of the Existing Basic Network System (RBSE) and the connecting facilities and Other Transmission Facilities (RPC) existing in May 2000 and not yet depreciated or amortized.

On April 20, 2016, MME Ordinance No. 120 was published, determining that the amounts of assets not yet depreciated and/or amortized, shall comprise the Regulatory Remuneration Base (BRR) for electricity transmission concessionaires as of the 2017 tariff review process, in order to define the Annual Permitted Revenue (APR). The Ordinance addressed issues related to updating, remunerating and period for receiving the amounts, which are regulated by Aneel Normative Resolution No. 762/2017, by means of Public Hearing 068/2016.

On April 12, 2017, Aneel issued Technical Note No. 61/2017 - SFF, which concluded the audit of the appraisal report and recognized the amount of R$667,637 as the net value of the assets at December 31, 2012. ANEEL’s board approved the inspection results on May 9, 2017.

Copel GeT is considering the amount approved by ANEEL and the change derived from the remeasurement of the asset was recognized as a balancing item to the statement of income, R$315,051 was recognized in operating revenue until September 30, 2017 and R$207,934 in income after taxes.

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The appraisal report was submitted to Aneel on March 31, 2015 and had a base amount of R$882,300, R$214,663 greater than that approved by the Agency, and the disallowance is related to the assets of Substation SF6 of Salto Caxias.

Moreover, on June 27, 2017 ANEEL published Resolution No. 2,258 establishing the Annual Permitted Revenue (RAP), for the 2017/2018 tariff cycle, considering the court decision on the injunction of April 11, 2017 related to a lawsuit filed by three business associations, which determines the deduction of the “compensation”, provided for in article 15, paragraph 2 of Law 12,783/2013.

The compensation related to the cost of equity calculated for the RBSE assets from January 2013 to June 2017 temporarily reduced the referred RAP from R$132,993 to R$121,267, and the amount deducted from the RAP by ANEEL in the eight tariff cycles is R$201,795.

Based on the opinion of its legal counsel, Copel GeT understands that this is a provisional decision and is not against Copel GeT’s right to receive the amounts related to RSBE assets, which are guaranteed by Law. Therefore, the receivables related to the compensation by the cost of equity considered in the receipt flow of this asset are recorded in non-current assets.

10.5 Concession agreement – gas distribution

	Noncurrent
Balance as of January 1, 2017	83,378
Capitalization of intangible assets in progress	15,438
Fair value recognition	(1,595)
Balance as of September 30, 2017	97,221

10.6 Commitments regarding transmission

Commitments with suppliers of equipment and services are related to the following projects:

Contracts	Transmission Lines and Substations	Balance
Contract 010/2010	TL 500kV Araraquara 2 - Taubaté and SEs 500kV Araraquara and Taubaté	73,454
Contract 022/2014	TL 500kV Londrina - Assis and SEs 500kV Londrina and Assis	3,850
Contract 006/2016	TL 500kV Blumenau - Curitiba Leste and SEs 500kV Blumenau and Curitiba Leste	27,981
	TL 230kV SE B. Iguaçu - Realeza Sul and SE 230kV Medianeira Norte	61,943
	TL 230kV Curitiba Centro - Uberaba and SE 230kV Curitiba Centro	159,750
	Sectional LT 230kV Assis - Salto Grande and SE 230kV Andirá Leste	30,463
		357,441

11Accounts Receivable Related to Concession Compensation

11.1 Changes in accounts receivable related to concession compensation

Consolidated
	Noncurrent
Balance as of January 1, 2017	67,401
Gain on remeasurement of the cash flow	182
Reversal of impairment	599
Balance as of September 30, 2017	68,182

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12Other Receivables

.		Parent Company		Consolidated
		09.30.2017	12.31.2016	09.30.2017	12.31.2016
Services in progress (a)		7,444	7,893	132,527	136,085
CDE Transfer		-	-	121,485	45,929
Advance payments to suppliers (b) (12.1)		-	-	64,935	44,806
Advance payments to employees		859	652	36,360	25,916
Decommissioning in progress		-	-	34,067	43,602
Advance for severance estate		-	-	6,183	11,050
Other receivables		186	191	74,007	73,096
		8,489	8,736	469,564	380,484
	Current	8,489	8,736	366,729	306,933
	Noncurrent	-	-	102,835	73,551

(a) This item refers to services currently in progress w ithin the Company, most of w hich are related to the Research and Development and Energy Efficiency programs, w hich upon conclusion are offset against the respective liability recorded for this purpose.

(b) Advances to suppliers provided on contractual clauses.

12.1 Advances to suppliers

This balance includes the advance to suppliers of Compagás relating to the gas purchase agreement with Petrobras, purchase of volumes and transmission capacities contracted and assured, higher than those actually withdrawn and used, and contains future compensation clause. Compagás has the right to withdraw the gas in subsequent months, and can compensate the volume contracted and not consumed within a prescription period of up to ten years. This balance is monthly adjusted for inflation, updating the recovery amount. According to the contractual provisions and consumption perspectives, derived from the review of the projects and scenarios for the next years, Compagás made an adjustment to the recoverable amount of the credit from take or pay and ship or pay to be offset. The effects on the income for the year, in the amount of R$4,586, was recorded as operating costs - estimates losses, provisions and reversals.

13Taxes

13.1 Income tax and social contribution

.	Parent Company			Consolidated
	09.30.2017	12.31.2016	09.30.2017	12.31.2016
Current assets
IR and CSLL paid in advance	60,800	116,441	977,396	765,150
IR and CSLL to be offset against liability	(1,033)	(74,542)	(214,638)	(576,198)
	59,767	41,899	762,758	188,952
Noncurrent assets
IR and CSLL paid in advance	145,341	153,216	162,844	169,967
	145,341	153,216	162,844	169,967
Current liabilities
IR and CSLL due	-	4,882	458,739	547,992
IR and CSLL to be offset against asset	-	(4,882)	(213,605)	(506,538)
	-	-	245,134	41,454

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13.2 Deferred income tax and social contribution

13.2.1Changes in deferred income tax and social contribution

Parent Company	Balance as of January 1º, 2017	Recognized in income	Recognized in other comprehensive income	Balance as of September 30, 2017
Noncurrent assets
Tax losses and negative tax basis	4,755	50,227	-	54,982
Provisions for legal claims	52,000	(4,200)	-	47,800
Amortization - concession	19,299	286	-	19,585
Provision for financing	3,457	-	-	3,457
Private pension and health plans	2,114	87	-	2,201
Others	17,939	(1,965)	-	15,974
	99,564	44,435	-	143,999
(-) Noncurrent liabilities
Escrow deposits monetary variation	24,699	2,426	-	27,125
Result from the change in the investment valuation method	17,717	-	-	17,717
CPC 38/IAS 39 effects - financial instruments	7,079	(3,963)	1,210	4,326
CPC 08 effects - transaction costs	1,715	3,132	-	4,847
CPC 33/IAS 19 effects - employee benefits	892	-	-	892
	52,102	1,595	1,210	54,907
Net	47,462	42,840	(1,210)	89,092

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13.2.2Realization of deferred tax credits

The tax credit derived from the pension and healthcare plans was calculated considering the actuarial provision determined based on a valuation prepared annually by an independent actuary. The deferred taxes on all other provisions for litigations will be realized according to the court rulings.

The projected realization of the deferred tax credits is shown below:

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13.3 Other taxes recoverable and other tax obligations

.	Parent Company			Consolidated
	09.30.2017	12.31.2016	09.30.2017	12.31.2016
Current assets
Recoverable ICMS (VAT)	7	-	74,153	62,934
Recoverable PIS/Pasep and Cofins taxes	266	197	241,365	52,240
PIS/Pasep and Cofins to be offset against liabilities	-	-	(111,709)	(47,810)
Other recoverable taxes	-	-	571	567
	273	197	204,380	67,931
Noncurrent assets
Recoverable ICMS (VAT)	-	-	26,344	35,659
PIS/Pasep and Cofins taxes	-	-	57,336	62,113
Other recoverable taxes	15	15	33,338	33,336
	15	15	117,018	131,108
Current liabilities
ICMS (VAT) payable	-	5	150,665	113,793
PIS/Pasep and Cofins payable	1,033	39,819	121,293	136,437
PIS/Pasep and Cofins to be offset against assets	(1,033)	(39,819)	(112,742)	(87,629)
IRRF on JSCP	-	29,841	-	90,147
IRRF on JSCP to be offset against IR and CSLL assets	-	(29,841)	-	(29,841)
Special Tax Regularization Program - Pert (13.3.1)	-	-	145,846	-
Ordinary financing of taxes w ith the federal tax authorities	-	-	60,105	59,558
Other taxes	699	407	10,736	12,529
	699	412	375,903	294,994
Noncurrent liabilities
Social security contributions - injunction on judicial deposit	2,313	2,075	176,141	161,336
Pert (13.3.1)	-	-	487,955	-
Ordinary financing of taxes w ith the federal tax authorities	-	-	103,506	138,969
TCFRH (a)	-	-	40,280	-
Other taxes	-	-	3,210	2,841
	2,313	2,075	811,092	303,146
(a) Fee for Control, Monitoring and Inspection of Activities of Exploitation and Use of Water Resources

13.3.1Special Tax Regularization Program - Pert

In June 2016, the Brazilian Federal Revenue Office - RFB issued an understanding through Private Letter Ruling Cosit No. 101/2016, providing guidance that the Account of Compensation of Variation in Amounts of “Parcel A” - CVA, currently classified as Sectorial Financial Assets and Liabilities, should be realized when it was recorded (accrual basis) and not through transfer to tariffs (cash basis). According to the RFB, this understanding is based on the signing of the amendment to the concession agreement in December 2014, which currently assures that any residual balance of Sectorial Financial Assets and Liabilities will be indemnified at the end of the concession.

In this context, due to the RFB’s position, which produces effects since December 2014, the Company, which taxed the CVA operations on a cash basis, assessed the benefits offered by the Special Tax Regularization Program - Pert, established by Provisional Measure  – MP No., 783/2017 and regulated by Normative Instruction – IN No. 1711/2017, as well as the effect on its financial results and cash flow, decided to join the program in August 2017, thus changing the taxation regime from CVA to accrual basis.

Based on this decision, Copel DIS rectified all accessory obligations from December 2014 to July 2017.

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The underpayments made in the period from December 2014 to March 2017 were included in the Pert, with a declaration to the RFB of a debit of R$557,365  (principal amount), relating to PIS, Cofins, IRPJ and CSLL. Considering the benefits of reduction of fine and interest of the Pert, total amount adjusted for inflation through August 2017, program joining date, is R$694,822.

Tax	Principal	Fine	Interest	Consolidated debt before joining Pert (1)	Reduction of fine and interest - Pert (2)	Debt balance (1) - (2)
PIS	29,432	5,886	8,612	43,930	7,395	36,535
Cofins	135,614	27,123	39,678	202,415	34,073	168,342
IRPJ	286,528	57,306	89,814	433,648	75,819	357,829
CSLL	105,791	21,158	33,159	160,108	27,992	132,116
	557,365	111,473	171,263	840,101	145,279	694,822

The payment of the taxes included in the Pert is made as follows:

·Cash payment of 20% of the debit (without the reductions provided for in the Pert), in 5 installments of R$33,604, payable from August 2017. From September 2017, this amount will be adjusted for inflation at the Selic rate.

·Beginning in January 2018, the payment of the debt balance starts, in 145 installments of R$3,633. The amount of the instalment will be adjusted for inflation at the Selic rate.

The debt balance relating to the Pert at September 30, 2017 is R$633,801.

Regarding overpayments made in the period from December 2014 to July 2017, considering the change of the taxation regime from CVA to the accrual basis, pursuant to Private Letter Ruling Cosit No.  101/2016, Copel DIS declared to RFB credits relating to PIS, Cofins, IRPJ and CSLL, as shown in the table below:

Tax	Principal	Interest	Total
PIS	40,379	6,716	47,095
Cofins	185,134	30,803	215,937
IRPJ	369,900	50,219	420,119
CSLL	164,996	23,310	188,306
	760,409	111,048	871,457

The amounts of these credits will be used for future offsets of federal taxes and their balance will be adjusted for inflation monthly by the Selic rate.

Thus, the benefits earned by the Company for joining the program totalled R$145,279 relating to reduction of fine and interest.

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13.4 Reconciliation of provision for income tax (IRPJ) and social contribution (CSLL)

14Prepaid Expenses

Consolidated
		09.30.2017	12.31.2016
Risk premium - GSF renegotiation (14.1)		31,897	40,909
Others		18,867	23,770
		50,764	64,679
	Current	34,194	39,096
	Noncurrent	16,570	25,583

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14.1 GSF (Generation Scaling Factor) renegotiation

A breakdown of these items as at 09.30.2017 is presented below:

Consolidated	Balance as of			Balance as of
	January 1º, 2017	Amortization	Transfers	September 30, 2017
Risk premium - current asset	15,459	(9,012)	9,012	15,459
Risk premium - noncurrent asset	25,450	-	(9,012)	16,438
Intangible	53,186	(5,681)	-	47,505
	94,095	(14,693)	-	79,402
Risk premium to be amortized - prepaid expenses	40,909			31,897
Grant extension period - intangible	53,186			47,505

15Receivables from Related Parties

.	Controladora		Consolidado
	30.09.2017	31.12.2016	30.09.2017	31.12.2016
Controlador
Estado do Paraná (15.1)	130,156	130,156	142,648	155,141
Controladas
Copel DIS (15.2)	86,590	90,505	-	-
Copel TEL (15.3)	-	85,421	-	-
Usina de Energia Eólica Guajiru S.A. (15.4)	30,825	-	-	-
Usina de Energia Eólica Potiguar S.A. (15.5)	45,773	-	-	-
Usina de Energia Eólica Cutia S.A. (15.6)	19,292	-	-	-
Usina de Energia Eólica Maria Helena S.A. (15.7)	34,080	-	-	-
Usina de Energia Eólica Paraíso dos Ventos do Nordeste S.A. (15.8)	1,795	-	-	-
Copel REN - compartilhamento de estrutura	955	955	-	-
Copel Energia - compartilhamento de estrutura	541	541	-	-
Copel DIS - reembolso	-	135	-	-
Empreendimento controlado em conjunto
Voltalia São Miguel do Gostoso (15.9)	37,268	28,968	37,268	28,968
	387,275	336,681	179,916	184,109
Circulante	170,529	116,020	37,268	28,968
Não circulante	216,746	220,661	142,648	155,141

15.1 State of Paraná

15.1.1Credit related to Luz Fraterna Program, R$115,890 (R$115,890 as of 12.31.2016)

The transfer of the receivables from the Luz Fraterna account (Note 37.a) of Copel DIS to Copel was suspended from the second half of 2015, considering Decree No. 2,789/2015, which created the possibility of using presumed ICMS (VAT tax) credits for the settlement of invoices referring to this program. In addition, State Law No. 18,875, dated 09.27.2016 authorized the State of Paraná to pay in installments the debts due and unpaid to Copel relating to services rendered up to the date of publication of said Law.

The settlement of the remaining balances is in the final stage of negotiation.

15.1.2Credit referring to 2014 World Cup construction work, R$14,266 (R$14,266 as of 12.31.2016)

Copel’s executive board, through the 2,119th Meeting, of July 28, 2014, approved the transfer of credit rights on costs related to mobility projects for FIFA 2014 World Soccer Cup made by Copel DIS and under the responsibility of the Paraná State government.

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ANEEL agreed to the transaction through order No. 3,483/2015 and a Credit Assignment Agreement that transfers Copel DIS rights to Copel was executed.

In addition, State Law No. 18,875, dated September 27, 2016, authorized the State of Paraná to pay debts due and unpaid to Copel relating to services rendered up to the date of publication of said Law. Considering this legal provision, Management is in the negotiation phase to define the terms of the settlement of this balance.

15.1.3Credit referring to Programa Morar Bem, R$12,492 (R$24,985 as of 12.31.2016)

Programa Morar Bem Paraná, established by Decree No. 2845/2011, is an agreement between Paraná State, Companhia de Habitação do Paraná (Cohapar) and Copel DIS, and is managed by Cohapar. Copel main attributions in this agreement are comprised of the construction of electric power distribution networks and housing project consumer unit service connections.

State Law No. 18,875, dated September 27, 2016, authorized the State of Paraná to pay in installments the debts overdue and not paid to Copel DIS relating to services rendered up to the date of publication of said Law. Considering this legal provision, Management is under negotiation with the State of Paraná to define the terms of the settlement of this balance.

15.2 Copel DIS - Financing transferred - STN

The Company transferred loans and financing to its wholly-owned subsidiaries at the time of constitution in 2001. However, since the contracts for the transfers to the respective subsidiaries were not formalized with the financial institutions, they remain recognized in the Parent Company.

The balance with Copel DIS refers to STN financing transferred with the same levy of charges borne by the Company and shown as obligations for loans and financing at Copel DIS (Note 23).

15.3 Copel TEL - Loan

A loan agreement was signed on June 12, 2015 between Copel (lender) and Copel TEL (borrower), within the limit of R$20,000, changed to R$60,000 and R$120,000 pursuant to the first and second amendments to the agreements signed on October 14, 2016 and December 15, 2016, effective until December 29, 2017 and remuneration at 111.5% of the CDI rate, for the purpose of raising funds to comply with the borrower’s investment program. The loan was settled on 08.09.2017 and was recorded as financial income in the amount of R$6,667, in 2017 (R$55 in the third quarter of 2016).

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15.4 Usina de Energia Eólica Guajiru S.A. - Loan

On August 21, 2017, a loan agreement was signed between Copel (lender) and Usina de Energia Eólica Guajiru S.A. (borrower), within the limit of R$30,500 plus IOF (tax on financial transactions), effective until January 31, 2018 and remuneration at 117% of the CDI rate, aiming at providing working capital for financing the borrower's activities and business. Of the limit approved, the borrower used all the limit approved. This quarter a financial income of R$179 was recorded.

15.5 Usina de Energia Eólica Potiguar S.A. - Loan

On August 21, 2017, a loan agreement was signed between Copel (lender) and Usina de Energia Eólica Potiguar S.A. (borrower), within the limit of R$71,500 plus IOF, effective until January 31, 2018 and remuneration at 117% of the CDI rate, aiming at providing working capital for financing the borrower's activities and business. Of the limit approved, the borrower used R$45,327. This quarter a financial income of R$233 was recorded.

15.6 Usina de Energia Eólica Cutia S.A. - Loan

On August 21, 2017, a loan agreement was signed between Copel (lender) and Usina de Energia Eólica Cutia S.A. (borrower), within the limit of R$19,500 plus IOF, effective until January 31, 2018 and remuneration at 117% of the CDI rate, aiming at providing working capital for financing the borrower's activities and business. Of the limit approved, the borrower used R$19,088. This quarter a financial income of R$112 was recorded.

15.7 Usina de Energia Eólica Maria Helena S.A. - Loan

On August 21, 2017, a loan agreement was signed between Copel (lender) and Usina de Energia Eólica Maria Helena S.A. (borrower), within the limit of R$83,500 plus IOF, effective until January 31, 2018 and remuneration at 117% of the CDI rate, aiming at providing working capital for financing the borrower's activities and business. Of the limit approved, the borrower used R$33,729. This quarter a financial income of R$190 was recorded.

15.8 Usina de Energia Eólica Paraíso dos Ventos do Nordeste S.A. - Loan

On August 21, 2017, a loan agreement was signed between Copel (lender) and Usina de Energia Eólica Paraíso dos Ventos do Nordeste S.A. (borrower), within the limit of R$2,500 plus IOF, effective until January 31, 2018 and remuneration at 117% of the CDI rate, aiming at providing working capital for financing the borrower's activities and business. Of the limit approved, the borrower used R$1,776. This quarter a financial income of R$10 was recorded.

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15.9 Voltalia São Miguel do Gostoso Participações S.A. - Loan

On May 14, 2015, a loan agreement was signed between Copel (lender) and Voltalia São Miguel do Gostoso Participações S.A. (borrower), with retroactive effects as from February 6, 2015, within the limit of R$29,400, plus IOF, effective until February 6, 2018, according to the first amendment signed on February 6, 2017, and a remuneration at 111.5% of the Interbank Deposit Certificate (CDI), aiming at providing working capital for financing the borrower’s activities and business. Of the limit approved, the borrower used R$27,950. In the first nine months of 2017, a financial income of R$2,778.was recorded (R$2,606, in the same period of 2016).

16Other Temporary Investments

Investiment	Investor	Shares (quantity)	Type	Stock exchange quotation per share (R$) 09.30.2017	Stock exchange quotation per share (R$)	12.31.2016
Companhia de Saneamento do Paraná - Sanepar	Copel	36,343,267	Preferred	10.90 393,234	10.75	390,690
Sanepar (Note 18.4)	Copel Energia	7,956,306	Common	77,478		-
Other investments	Copel			18,622		17,607
				489,334		408,297

17Judicial Deposits

.		Parent Company		Consolidated
	09.30.2017	12.31.2016	09.30.2017	12.31.2016
Taxes claims	141,927	153,719	357,121	433,880
Labor claims	119	213	135,210	149,968
Civil
Suppliers	-	-	-	7,680
Civil	-	-	61,623	51,482
Easements	-	-	12,930	6,679
Customers	-	-	2,617	3,197
	-	-	77,170	69,038
Others	-	-	4,952	4,717
	142,046	153,932	574,453	657,603

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18Investments

18.1 Changes in investments

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18.2 Subsidiaries with non-controlling interest

18.2.1Summarized financial information

18.2.2Changes in equity attributable to non-controlling shareholders

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18.3 Total balances of the groups of assets, liabilities, net income and share in commitments and contingent liabilities of the main joint ventures

09.30.2017	Dominó	Voltalia	Costa Oeste	Marumbi	Transmis- sora  Sul Brasileira	Caiuá	Integração Maranhense	Matrinchã	Guaraciaba	Paranaíba	Mata de Santa Genebra	Canta- reira
ASSETS	5,830	157,891	97,726	161,026	694,511	232,126	468,378	2,730,832	1,375,803	1,626,922	1,526,685	900,984
Current assets	5,616	2,174	6,931	9,993	54,350	25,363	49,613	262,782	111,974	171,023	27,435	25,276
Cash and cash equivalents	1,887	28	1,930	1,706	24,295	1,730	4,008	125,727	6,167	33,204	15,121	24,540
Other current assets	3,729	2,146	5,001	8,287	30,055	23,633	45,605	137,055	105,807	137,819	12,314	736
Noncurrent assets	214	155,717	90,795	151,033	640,161	206,763	418,765	2,468,050	1,263,829	1,455,899	1,499,250	875,708
.
LIABILITIES	5,830	157,891	97,726	161,026	694,511	232,126	468,378	2,730,832	1,375,803	1,626,922	1,526,685	900,984
Current liabilities	820	2,226	3,753	9,958	36,990	25,387	74,075	131,048	60,678	72,261	607,171	15,335
Financial liabilities	-	-	3,120	5,208	28,327	7,404	13,209	48,575	29,625	51,288	544,447	-
Other current liabilities	820	2,226	633	4,750	8,663	17,983	60,866	82,473	31,053	20,973	62,724	15,335
Noncurrent liabilities	-	-	29,211	47,103	301,808	94,063	164,343	921,041	462,891	896,488	73,036	510,384
Financial liabilities	-	-	25,424	39,789	292,384	65,745	106,784	730,560	360,443	642,453	-	424,695
Other noncurrent liabilities	-	-	3,787	7,314	9,424	28,318	57,559	190,481	102,448	254,035	73,036	85,689
Equity	5,010	155,665	64,762	103,965	355,713	112,676	229,960	1,678,743	852,234	658,173	846,478	375,265
.
STATEMENT OF INCOME
Net operating income	-	-	8,626	14,653	40,988	(5,916)	(19,785)	305,264	168,944	213,935	483,869	325,574
Operating costs and expenses	(646)	(90)	(14,378)	(27,942)	(6,888)	(4,157)	(3,096)	(166,421)	(84,838)	(92,092)	(373,688)	(293,929)
Financial results	(508)	5	(1,345)	(2,327)	(20,265)	(4,663)	(6,933)	(44,115)	(26,959)	(43,693)	(64,893)	(34,708)
Equity in income of subsidiaries	-	1,540	-	-	-	-	-	-	-	-	-	-
Income tax and social contribution	(1)	-	854	984	(4,967)	4,846	10,278	(32,453)	(19,139)	(29,349)	(15,362)	1,164
Net income (loss)	(1,155)	1,455	(6,243)	(14,632)	8,868	(9,890)	(19,536)	62,275	38,008	48,801	29,926	(1,899)
Other comprehensive income	-	-	-	-	-	-	-	-	-	-	-	-
Total comprehensive income	(1,155)	1,455	(6,243)	(14,632)	8,868	(9,890)	(19,536)	62,275	38,008	48,801	29,926	(1,899)
Investment interest - %	49.0	49.0	51.0	80.0	20.0	49.0	49.0	49.0	49.0	24.5	50.1	49.0
Investment book value	2,455	76,276	33,028	83,172	71,143	55,210	112,680	822,583	417,594	161,251	424,086	183,880

Copel's interest in the commitments assumed from its joint ventures is equivalent to R$149,032 and in contingent liabilities is equivalent to R$3,487.

18.4 Dominó Holdings S.A.

At the Extraordinary General Meeting held on March 13, 2017, the shareholders approved the capital reduction of Dominó Holding, without cancelation of shares, through the delivery of all common shares issued by Sanepar, owned by Dominó Holdings, in the proportion of its interests. As a consequence, Copel Energia became the direct holder of 7,956,306 common shares of Sanepar, measured at their fair value at R$73,361, determined based on the discounted cash flow method.

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18.5 Total balances of the groups of assets, liabilities, net income and share in contingent liabilities of the main associates

09.30.2017	Dona Francisca	Foz do Chopim
ASSETS	139,783	51,810
Current assets	10,981	13,844
Noncurrent assets	128,802	37,966
LIABILITIES	139,783	51,810
Current liabilities	4,449	2,083
Noncurrent liabilities	4,315	14,205
Equity	131,019	35,522
STATEMENT OF INCOME
Net operating income	52,900	30,165
Operating costs and expenses	(23,564)	(12,102)
Financial income (expense)	747	576
Income tax and social contribution	(2,016)	(1,117)
Net income	28,067	17,522
Other comprehensive income	-	-
Total comprehensive income	28,067	17,522
Investment interest - %	23.0303	35.7700
Investment book value	30,174	12,707

Copel's interest in the contingent liabilities of its associates is equivalent to R$55,638.

19Property, Plant and Equipment

19.1 Property, plant and equipment by asset class

Consolidated	Cost	Accumulated depreciation	09.30.2017	Cost	Accumulated depreciation	12.31.2016
In service
Reservoirs, dams and aqueducts	6,641,555	(4,036,615)	2,604,940	6,595,895	(3,912,383)	2,683,512
Machinery and equipment	5,404,286	(2,778,432)	2,625,854	5,309,674	(2,645,702)	2,663,972
Buildings	1,500,496	(980,308)	520,188	1,498,841	(954,470)	544,371
Land	277,667	(14,553)	263,114	277,112	(12,351)	264,761
Vehicles and aircraft	58,948	(47,393)	11,555	60,914	(45,243)	15,671
Furniture and tools	16,926	(11,308)	5,618	16,771	(10,989)	5,782
(-) Provision for impairment	(1,160)	-	(1,160)	(77,318)	-	(77,318)
(-) Special Obligations	(56)	16	(40)	(56)	10	(46)
	13,898,662	(7,868,593)	6,030,069	13,681,833	(7,581,128)	6,100,705
In progress
Cost	4,742,936	-	4,742,936	3,969,703	-	3,969,703
(-) Provision for impairment	(1,111,207)	-	(1,111,207)	(1,136,105)	-	(1,136,105)
	3,631,729	-	3,631,729	2,833,598	-	2,833,598
	17,530,391	(7,868,593)	9,661,798	16,515,431	(7,581,128)	8,934,303

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19.2 Changes in property, plant and equipment

Consolidated		Additions /
	Balance as of	Reversal of		Loss on		Balance as of
	January 1, 2017	impairment	Depreciation	disposal	Transfers	September 30, 2017
In service
Reservoirs, dams and aqueducts	2,683,512	-	(108,249)	(13)	29,690	2,604,940
Machinery and equipment	2,663,971	-	(141,689)	(2,998)	106,570	2,625,854
Buildings	544,372	-	(27,255)	(390)	3,461	520,188
Land	264,761	-	(2,201)	(2)	556	263,114
Vehicles and aircraft	15,671	-	(4,128)	(6)	18	11,555
Furniture and tools	5,782	-	(603)	(4)	443	5,618
(-) Provision for impairment (19.7)	(77,318)	76,158	-	-	-	(1,160)
(-) Special Obligations	(46)	-	6	-	-	(40)
	6,100,705	76,158	(284,119)	(3,413)	140,738	6,030,069
In progress
Cost	3,969,703	888,487	-	(3,569)	(111,685)	4,742,936
(-) Provision for impairment (19.7)	(1,136,105)	24,898	-	-	-	(1,111,207)
	2,833,598	913,385	-	(3,569)	(111,685)	3,631,729
	8,934,303	989,543	(284,119)	(6,982)	29,053	9,661,798

19.3 Costs of loans, financing and debentures capitalized

The costs of loans, financing and debentures capitalized during the first nine months of 2017 amounted to R$1,519, at an average rate of 0.05% p.y. (R$5,499, at an average rate of 0.21% p.y., in the same period of 2016).

19.4 HPP Colíder

On July 30, 2010, at the ANEEL Auction of Power from New Projects 003/10, Copel GeT won the rights to the concession of the Colíder Hydroelectric Power Plant, valid for 35 years from the date of signature of Concession Agreement No. 001/11-MME-HPP Colíder, which took place on January 17, 2011.

This project is included in the Federal Government’s Growth Acceleration Program (PAC) and will comprise a main powerhouse of 300 MW, which is enough to supply approximately one million people. The facility will take advantage of the hydroelectric potential discovered on the Teles Pires River, between the towns of Nova Canaã do Norte and Itaúba, in the northern region of the State of Mato Grosso.

The National Bank for Economic and Social Development (BNDES) approved the classification of the HPP Colíder project for financial support feasibility analysis and the signed financing agreement amounted to R$1,041,155 (Note 23). Until September 30, 2017, the financing amount of R$975,108 was released.

Due to unforeseeable events or force majeure and acts of public authorities, such as fire at the construction site, difficulties related to environmental licensing, supplier delays in meeting the equipment delivery schedule, electromechanical assembly services and the construction of the transmission line associated to the plant, the project suffered impacts on its schedule, and the commercial operation forecast was revised, with the first generating unit scheduled for May 2018, while the third and final generating unit is scheduled to come on line in November 2018. As a result of these events, a balance of estimated losses on impairment of assets of R$638,837 is recorded as of September 30, 2017 (R$595,489 as of December 31, 2016).

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The Colíder Hydroelectric Power Plant’s power output was sold at an ANEEL auction at a final price of R$103.40/MWh, as of July 1, 2010, adjusted according to the variation of IPCA inflation index to R$161.56 as of 9/30/2017. 125 averages MW were sold, for supply starting on January 2015, for 30 years. Copel GeT submitted an application to ANEEL to exclude its responsibility, so that the obligation to supply energy could be postponed. In a first judgment, the request was not accepted, Copel GeT filed an application for reconsideration of the decision, which was also denied on March 14, 2017. Not agreeing with the decision, Copel GeT filed again an application for reconsideration, which was definitely denied on July 4, 2017 The Company will refer the matter to the court with the conviction that the Agency's decision will be reversed.

The Company has complied with its commitments of energy supply as follows:

·From January 2015 to June 2016: with energy surpluses not contracted in its other plants;

·From June 2016 to December 2017: with partial reduction in June 2016 through a Bilateral Agreement and in the period from July 2016 to December 2017, reduction of all supply contracts of the CCEARs – Energy Trading Agreement in the Regulated Environment, through a Bilateral Agreement and participation in the New Energy and Decrease Clearing Facility (“Mecanismo de Compensação de Sobras e Déficits - MCSD de Energia Nova”).

On December 21, 2016, the assured power of the project was revised by MME Ordinance No. 258, going from 179.6 average MW to 177.9 average MW, after full set-up.

At September 30, 2017, the expenditures incurred on UHE Colíder presented a balance of R$2,151,492 and the commitments assumed with equipment and service suppliers amounted to R$46,940.

19.5 Joint operations - consortiums

The amounts recorded under property, plant and equipment referring to the participations of Copel GeT in consortiums are shown below:

	Share	Annual average
Joint operations	Copel GeT (%)	depreciation rate (%)	09.30.2017	12.31.2016
In service
HPP Mauá (Consórcio Energético Cruzeiro do Sul)	51.00		859,917	859,917
(-) Accumulated depreciation		3.43	(139,721)	(117,625)
			720,196	742,292
In progress
HPP Baixo Iguaçu (19.5.1)	30.00		584,711	390,420
			584,711	390,420
			1,304,907	1,132,712

19.5.1Consórcio Empreendedor Baixo Iguaçu - Cebi

The purpose of the consortium is to build and operate the project known as Baixo Iguaçu Hydroelectric Plant, with minimum installed capacity of 350.20 MW and physical guarantee revised to 171.3 MW, The plant is located on the Iguaçu River between the municipalities of Capanema and Capitão Leônidas Marques, and between the Governador José Richa Hydroelectric Plant and the Iguaçu National Park, in the State of Paraná.

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The start of commercial operation of Unit 1 is scheduled for November 2018 and Units 2 and 3 for December 2018 and January 2019, respectively. The previous schedule has been changed due to the suspension of the Installation License, as per the decision of the Federal Court of the 4th Region (TRF-RS), held on June 16, 2014, that stopped the construction work as of July of that year. In March 2015, a decision authorizing the Company to resume construction work was published. However, Instituto Chico Mendes de Conservação da Biodiversidade - ICMBio imposed additional conditions for granting an environmental license to the Company, which prevented it from resuming construction work. Cebi sent IAP – Environmental Institute of Paraná the information necessary for those conditions to be met and in August 2015 the license was issued. Having obtained the IAP license, and after technical and contractual adjustments required due to the long downtime, the works were resumed as of February 2, 2016.

On August 23, 2016, the Company signed the 2nd Amendment to the Concession Agreement with the purpose of formalizing the redefinition of the work schedule, acknowledging in favor of Cebi the exclusion of responsibility for the delay in implementing the project for a period of 756 days, which was considered as an extension of the concession period, which originally was until August 19, 2047 and became September 14, 2049. Additionally, on November 7, 2017, Aneel acknowledged an additional period of 46 days for exclusion of responsibility relating to the invasions of the construction site by the “Movimento dos Atingidos por Barragens – MAB” group in 2016. The effects of this decision changes the project implementation schedule and postponed the beginning and the end of the energy trading agreements.

The river diversion to enable the construction of the second phase of the development is scheduled to be carried out in May of next year.

As of September 30, 2017, the total commitments assumed by the consortium for the complete implementation of the plant was R$645,177, and Copel’s portion was R$193,553.

19.6 Cutia wind farm project

The largest Copel wind farm called Cutia is under construction, and is divided into two large complexes:

·Cutia Complex: composed of seven wind farms (Guajiru, Jangada, Potiguar, Cutia, Maria Helena, Esperança do Nordeste and Paraíso do Ventos do Nordeste) with 180.6 MW of total installed capacity, 71.4 average MW of assured power, all located in the State of Rio Grande do Norte. The power that will be generated by the farms was sold on the 6th Reserve Auction that was held on October 31, 2014, at an average historical price of R$144.00/MWh, and the forecast for commercial generation of these farms is scheduled for June 2018; and

·Bento Miguel Complex: composed of six wind farms (São Bento do Norte I, São Bento do Norte II, São Bento do Norte III, São Miguel I, São Miguel II and São Miguel III) with a total installed capacity of 132.3 MW, 54.8 average MW assured power, all also located in the State of Rio Grande do Norte. The power that will be generated by the farms was sold on the 20th New Energy Auction that was held on November 28, 2014, at an average historical price of R$136.97/MWh, and the initial forecast for commercial generation of these farms is January 2019.

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The following are the relevant milestones for the execution of the works from January 2016 to June 2017. In January 2016, the environmental licenses were obtained, beginning the access road runs, bases and assembly platform of the generator set. In April 2016, construction of the Cutia Substation was started, with installed capacity of three 120 MVA transformers and twenty-six 34.0 kV circuits, two circuits for each wind farm. In October 2016, with the advanced stage of construction services in some farms, the first generator sets began to be delivered, and Torres Productive Center began operating, a structure in which precast elements that will constitute the towers of support of the wind turbines will be produced. In January 2017, the process of assembling the towers of the wind turbines began.

As a result of the review of the recoverable amount of these projects, a balance of estimated losses on impairment of assets of R$308,145 as of September 30, 2017 was recorded (R$314,463 as of December 31, 2016).

At September 30, 2017, the total commitments assumed with equipment and service suppliers of the wind farms under construction amounted to R$1,172,013. The amount refers mainly to the supply of wind turbines, civil works, owner’s engineering, construction of substations and medium and high tension transmission lines.

19.7 Estimated losses on impairment of generation segment assets

The Company reviewed the recoverable amount of property, plant and equipment and, as a result of these analyses, the balance of the estimated losses on impairment suffered the following changes:

Consolidated		Property, Plant
		and Equipment
	In service	In progress	Total
Balance as of January 1, 2017	(77,318)	(1,136,105)	(1,213,423)
Provision for impairment	-	(43,348)	(43,348)
Reversal of provision for impairment	76,158	68,246	144,404
Balance as of September 30, 2017	(1,160)	(1,111,207)	(1,112,367)

The projects with impairment balances recorded at September 30, 2017 are the following:

Consolidated	Property, Plant and Equipment
	Cost	Depreciation	Impairment	Value in use
Projects
UHE Colíder (a)	2,265,394	(1,700)	(638,837)	1,624,857
Complexo Eólico Cutia (a)	1,019,571	-	(231,562)	788,009
Complexo Eólico Bento Miguel (a)	155,879	-	(76,583)	79,296
Consórcio Tapajós (b)	14,464	-	(14,464)	-
Usinas no Paraná (a)	704,016	(27,721)	(150,921)	525,374
	4,159,324	(29,421)	(1,112,367)	3,017,536
(a) Under construction
(b) Project under development

The main impacts on the result for the period are as follows:

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·R$69,073 refer to the reversal of the provision for losses of Araucária Hydroelectric Plant, located in the State of Paraná. In 2017, the calculation of the value in use considers: Company’s assumptions and budgets, pre-tax discount rate in constant currency of 11.61% p.a., or 7.66% after taxes (12.13% p.a. in 2016), which derives from the WACC methodology for the electricity generation segment, plus the additional risk associated with the revenue variation. The reversal observed is justified mainly by the review of the discount rate and the reviews of the Company's projections as to the expected outcome.

·R$43,348 refer to the provision for losses of Colíder Hydroelectric Power Plant, under construction, located in the State of Mato Grosso. In 2017, the calculation of the value in use considered the Company’s assumptions and budgets and discount rate after taxes in constant currency of 5.35% p.a. (5.70% p.a. in 2016), which derives from the WACC methodology for the electricity generation segment. This additional provision was recognized mainly due to new delays in the execution, as well as due to increase in the capex estimated for the completion of the project.

·R$5,055 refer to the reversal of the provision for losses on Bento Miguel Complex and R$1,264 to the reversal of the provision for losses on Cutia Complex. Refer to wind generation assets under construction in the State of Rio Grande do Norte. In 2017, the calculation of the value in use considers: Company’s assumptions and budgets and pre-tax discount rate in constant currency of 7.11% (8.06% p.a. in 2016), which derives from the WACC methodology for the electricity generation segment, adjusted for the specific condition of taxation of those projects.The reversals observed are justified mainly by the review of the discount rate and the reviews of the projections, notably regarding the assumption of energy available for sale in the long term.

·R$15,423 refer to the reversal of the Figueira Hydroelectric Plant, a project in process of modernization. In 2017, the calculation of the value in use considered the Company’s assumptions and budgets and pre-tax discount rate in constant currency of 8.11% p.a. (8.63% p.a. in 2016), which derives from the WACC methodology for the electricity generation segment. The reversal is justified by the effects of the discount rate, offset by an increase in capex and delay in the operation after modernization.

·R$53,589 refer to the reversal of the provision for other assets of hydraulic generation in the State of Paraná. The calculation of the value in use considered: company’s assumptions and budgets, (i) for the plant in operation, a pre-tax discount rate in constant currency of 8.11% (8.63% p.a. in 2016) and (ii) for the plant under construction, a discount rate after taxes in constant currency of 5.35% p.a. (5.70% p.a. in 2016), which derives from the WACC methodology for the electricity generation segment. The reversal observed is basically due to the review of the discount rate used.

20Intangible Assets

Consolidated
	09.30.2017	12.31.2016
Distribution concession agreement (20.1)	5,667,616	5,513,381
Generation concession agreements/ authorization (20.2)	640,872	663,712
Concession agreement - gas distribution (20.3)	212,021	238,509
Others (20.4)	41,618	44,210
	6,562,127	6,459,812

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20.1 Distribution concession agreement

	in	in	Special liabilities
	service	progress	in service	in progress	Total
Balance as of January 1, 2017	7,537,158	849,715	(2,845,024)	(28,468)	5,513,381
Acquisitions	-	524,841	-	-	524,841
Customers contributions	628	-	(579)	(86,732)	(86,683)
Provision for claims added to the cost of the w orks	-	55	-	-	55
Transfers for accounts receivable related to concession (Note 10.1)	-	(30,784)	-	-	(30,784)
Capitalizations for intangible in service	553,640	(553,640)	(82,132)	82,132	-
Amortization of quotas - concession (a)	(308,403)	-	93,866	-	(214,537)
Amortization of quotas - PIS/Pasep and Cofins credits	(8,246)	-	-	-	(8,246)
Loss on disposal	(22,780)	(10,408)	2,777	-	(30,411)
Balance as of September 30, 2017	7,751,997	779,779	(2,831,092)	(33,068)	5,667,616
(a) Amortization during the concession as of the start of commercial operations of the enterprieses or based on the useful life of the assets, of thetw o the shortest.

20.2 Generation concession agreement

Consolidated	Concession contract (a)		Concession and
	in	in	authorization
	service	progress	rights	Total
Balance as of January 1, 2017	254,280	6,299	403,133	663,712
ANEEL grant - use of public property	-	491	-	491
Amortization of quotas - concession and authorization (b)	(13,478)	-	(9,853)	(23,331)
Balance as of September 30, 2017	240,802	6,790	393,280	640,872
(a) Includes the balances of use of public asset and hydrological risk renegotiation
(b) Amortization during the concession/authorization as of the start of commercial operations of the enterprieses.

20.3 Concession agreement – gas distribution

	in	in
	service	progress	Total
Balance as of January 1, 2017	198,271	40,238	238,509
Acquisitions	-	10,607	10,607
Transfers for accounts receivable related to concession	-	(15,438)	(15,438)
Capitalizations for intangible in service	6,749	(6,749)	-
Amortization of quotas - concession (a)	(21,493)	-	(21,493)
Loss on disposal	(164)	-	(164)
Balance as of September 30, 2017	183,363	28,658	212,021
(a) Amortization during the concession as of the start of commercial operations of the enterprieses or based on the useful life of theassets, of the tw o the shortest.

20.4 Other intangible assets

Consolidated	in	in
	service	progress	Total
Balance as of January 1, 2017	25,725	18,485	44,210
Acquisitions	5	4,870	4,875
Transfers from property, plant and equipment	79	-	79
Capitalizations for intangible in service	3,622	(3,622)	-
Amortization of quotas (a)	(7,301)	-	(7,301)
Amortization of quotas - PIS/Pasep and Cofins credits	(46)	-	(46)
Loss on disposal	(18)	(181)	(199)
Balance as of September 30, 2017	22,066	19,552	41,618
(a) Annual amortization rate: 20%.

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20.5 Costs of loans, financing and debentures capitalized

The costs of loans, financing and debentures capitalized during the first nine months of 2017 amounted to R$3,152, at an average rate of 0.18% p.y. (R$4,388, at an average rate of 0.24% p.y., in the same period of 2016).

20.6 Commitments assumed

At September 30, 2017, the commitments assumed with equipment and service suppliers for the acquisition of intangible assets totalled R$16,036.

21Payroll, Social Charges and Accruals

	Parent Company			Consolidated
	09.30.2017	12.31.2016	09.30.2017	12.31.2016
Social security liabilities
Taxes and social contribution	951	1,485	34,364	50,016
Social security charges on paid vacation and 13th salary	1,076	826	47,225	35,570
	2,027	2,311	81,589	85,586
Labor liabilities
Payroll, net	-	35	72	835
Vacation and 13th salary	3,433	2,577	148,385	111,021
Profit sharing	546	650	44,024	64,814
Voluntary termination	2,744	-	45,981	25,532
Profit sharing	-	-	14	9
	6,723	3,262	238,476	202,211
	8,750	5,573	320,065	287,797

22Suppliers

Consolidated
		09.30.2017	12.31.2016
Energy supplies (22.1)		1,335,879	673,442
Materials and supplies		560,645	399,576
Natural gas for resale		200,448	132,985
Charges for use of grid system		114,768	86,347
		2,211,740	1,292,350
	Current	2,175,030	1,255,639
	Noncurrent	36,710	36,711

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22.1 Main power purchase agreements

Power purchase agreements signed in the regulated power trading environment, shown at original value and adjusted annually according to the IPCA index:

Auctions	Supply period	Energy purchased (annual average MW)	Auction date	Average purchase price (R$/MWh)
				historical	updated
Auction of power from existing facilities
13thAuction - Product 2014 - DIS	05.01.2014 to 12.31.2019	109.05	04.30.2014	262.00	324.51
13thAuction - Product 2014 - QTD	05.01.2014 to 12.31.2019	48.12	04.30.2014	271.00	335.66
14thAuction - Product 2015 - 03 DIS	01.01.2015 to 12.31.2017	13.28	12.05.2014	191.99	229.87
14thAuction - Product 2015 - 03 QTD	01.01.2015 to 12.31.2017	2.99	12.05.2014	201.00	240.66
		173.44
Auction of power from new facilities
1stAuction - Product 2008 Hydro	2008 to 2037	3.61	12.16.2005	106.95	205.04
1stAuction - Product 2008 Thermo	2008 to 2022	24.30	12.16.2005	132.26	253.57
1stAuction - Product 2009 Hydro	2009 to 2038	3.54	12.16.2005	114.28	219.10
1stAuction - Product 2009 Thermo	2009 to 2023	40.29	12.16.2005	129.26	247.82
1stAuction - Product 2010 Hydro	2010 to 2039	69.87	12.16.2005	115.04	220.55
1stAuction - Product 2010 Thermo	2010 to 2024	59.46	12.16.2005	121.81	233.53
3rdAuction - Product 2011 Hydro	2011 to 2040	57.66	10.10.2006	120.86	226.43
3rdAuction - Product 2011 Thermo	2011 to 2025	54.22	10.10.2006	137.44	257.49
4thAuction - Product 2010 Thermo	2010 to 2024	15.44	07.26.2007	134.67	244.64
5thAuction - Product 2012 Hydro	2012 to 2041	53.24	10.16.2007	129.14	232.38
5thAuction - Product 2012 Thermo	2012 to 2026	115.38	10.16.2007	128.37	231.00
6thAuction - Product 2011 Thermo	2011 to 2025	9.89	09.17.2008	128.42	218.14
7thAuction - Product 2013 Thermo	2013 to 2027	110.96	09.30.2008	145.23	246.70
8thAuction - Product 2012 Hydro	2012 to 2041	0.01	08.27.2009	144.00	234.99
8thAuction - Product 2012 Thermo	2012 to 2026	0.15	08.27.2009	144.60	235.97
15thAuction - Product 2017 Hydro	2017 to 2046	12.11	12.14.2012	93.46	126.11
15thAuction - Product 2017 Wind farm	2017 to 2036	0.33	12.14.2012	87.94	118.66
17thAuction - Product 2016 Wind farm	2016 to 2035	21.16	11.18.2013	124.43	159.98
19thAuction - Product 2017 Hydro	2017 to 2046	13.58	06.06.2014	121.00	148.59
19thAuction - Product 2017 Wind farm	2017 to 2036	10.09	06.06.2014	129.97	159.60
		675.29
Structuring projects auction
Santo Antônio	2012 to 2041	120.25	12.10.2007	78.87	140.35
Jirau	2013 to 2042	115.43	05.19.2008	71.37	123.44
Belo Monte	2015 to 2044	51.31	04.20.2010	77.97	122.36
		286.99

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23Loans and Financing

		Company	Issue Date	Number installment	of Final maturity	Annual rate p.y. (interest + commission)	Finance charges	Principal	Consolidated
	Contracts								09.30.2017	12.31.2016
Foreign currency
National Treasury Department - STN
(Secretaria do Tesouro Nacional)
(1)	Par Bond	Copel	05.20.1998	1	04.11.2024	6.0% + 0.20%	Half-yearly	17,315	51,394	53,498
(1)	Discount Bond	Copel	05.20.1998	1	04.11.2024	1.1875%+0.20%	Half-yearly	12,082	35,196	37,007
Total foreign currency									86,590	90,505
Local currency
Banco do Brasil
(2)	21/02155-4	Copel DIS	09.10.2010	2	08.15.2018	109.0% of DI	Half-yearly	116,667	58,878	122,713
(3)	21/02248-8	Copel DIS	06.22.2011	2	05.16.2018	109.0% of DI	Half-yearly	150,000	77,798	152,314
(4)	CCB 21/11062X	Copel DIS	08.26.2013	3	07.27.2018	106.0% of DI	Half-yearly	151,000	50,901	151,359
(5)	CCB 330.600.773	Copel DIS	07.11.2014	3	07.11.2019	111.8% of DI	Half-yearly	116,667	79,033	124,170
(6)	CFX 17/35959-7	Copel DIS	05.16.2017	2	05.06.2019	12.0%	Quarterly	75,000	75,092	-
(7)	CCB 21/00851-5	Copel DIS	06.30.2017	2	06.13.2019	11.0%	Quarterly	38,889	38,065	-
(8)	CCB 17/35960-0	Copel DIS	07.27.2017	2	07.17.2019	11.0%	Quarterly	50,333	50,590	-
(9)	CFX 17/35958-9	Copel DIS	08.15.2017	2	08.05.2019	11.0%	Quarterly	58,333	58,286	-
(10)	NCI 330.600.132	Copel	02.28.2007	3	02.28.2019	107.8% of DI	Half-yearly	231,000	154,650	241,312
(11)	NCI 330.600.151	Copel	07.31.2007	3	07.31.2017	111.0% of DI	Half-yearly	18,000	-	6,366
(12)	CCB 306.401.381	Copel	07.21.2017	3	07.21.2020	120.0% of DI	Half-yearly	640,005	646,546	677,177
(13)	NCI 306.401.445	Copel	02.24.2017	2	02.15.2020	124.5% of DI	Half-yearly	77,000	76,292	-
									1,366,131	1,475,411
Eletrobras
(14)	980/95	Copel DIS	12.22.1994	80	08.15.2019	8.0%	Quarterly	11	3	5
(14)	981/95	Copel DIS	12.22.1994	80	02.15.2020	8.0%	Quarterly	1,169	131	180
(14)	982/95	Copel DIS	12.22.1994	80	11.15.2020	8.0%	Quarterly	1,283	53	71
(14)	983/95	Copel DIS	12.22.1994	80	11.15.2020	8.0%	Quarterly	11	83	103
(14)	984/95	Copel DIS	12.22.1994	80	08.15.2021	8.0%	Quarterly	14	36	44
(14)	985/95	Copel DIS	06.07.2004	80	07.30.2016	8.0%	Quarterly	61	24	29
(15)	142/06	Copel DIS	03.03.2008	120	08.30.2020	5.0% + 1.0%	Monthly	74,340	3,639	6,369
(15)	206/07	Copel DIS	02.18.2010	120	12.30.2022	5.0% + 1.0%	Monthly	109,642	25,969	32,648
(15)	273/09	Copel DIS	05.12.2009	120	10.30.2016	5.0% + 1.5%	Monthly	63,944	8,632	9,866
									38,570	49,315
Caixa Econômica Federal
(15)	415.855-22/14	Copel DIS	03.31.2015	120	12.08.2026	6.0%	Monthly	2,844	5,440	5,631
(16)	3153-352	Copel DIS	03.31.2015	36	12.08.2026	5.5 % above TJLP	Quarterly	489	501	-
									5,941	5,631
Finep
(17)	21120105-00	Copel TEL	07.17.2012	81	10.15.2020	4%	Monthly	35,095	9,635	11,983
(17)	21120105-00	Copel TEL	07.17.2012	81	10.15.2020	3.5% + TR	Monthly	17,103	8,141	10,043
									17,776	22,026
BNDES
(18)	820989.1	Copel GeT	03.17.2009	179	01.15.2028	1.63% above TJLP	Monthly	169,500	120,990	128,722
(19)	1120952.1-A	Copel GeT	12.16.2011	168	04.15.2026	1.82% above TJLP	Monthly	42,433	26,790	28,895
(20)	1120952.1-B	Copel GeT	12.16.2011	168	04.15.2026	1.42% above TJLP	Monthly	2,290	1,445	1,559
(21)	1220768.1	Copel GeT	09.28.2012	192	07.15.2029	1.36% above TJLP	Monthly	73,122	56,404	59,493
(22)	13211061	Copel GeT	12.04.2013	192	10.15.2031	1.49% above TJLP	Monthly	1,041,155	884,449	923,982
(23)	13210331	Copel GeT	12.03.2013	167	08.15.2028	1.49% and 1.89% above TJLP	Monthly	17,644	14,167	15,017
(24)	15206041	Copel GeT	12.28.2015	168	06.15.2030	2.42% above TJLP	Monthly	34,265	26,346	27,666
(25)	15205921	Copel GeT	12.28.2015	168	12.15.2029	2.32% above TJLP	Monthly	21,584	16,019	16,860
(26)	14205611-A	Copel DIS	12.15.2014	72	01.15.2021	2.09% p.y. above TJLP	Monthly	41,583	22,938	27,893
(26)	14205611-B	Copel DIS	12.15.2014	6	02.15.2021	2.09 p.y. above TR BNDES	Annual	17,821	14,989	18,735
(27)	14205611-C	Copel DIS	12.15.2014	113	06.15.2024	6% p.y.	Monthly	78,921	52,900	58,787
(28)	14205611-D	Copel DIS	12.15.2014	57	02.15.2021	TJLP	Monthly	750	31	38
(29)	14212711	Santa Maria	06.01.2015	192	08.15.2031	1.66% p.y. above TJLP	Monthly	59,462	52,380	54,734
(29)	14212721	Santa Helena	06.01.2015	192	08.15.2031	1.66% p.y. above TJLP	Monthly	64,520	56,803	59,355
(30)	11211521	GE Farol	03.19.2012	192	06.15.2030	2.34% p.y. above TJLP	Monthly	54,100	49,580	52,053
(30)	11211531	GE Boa Vista	03.19.2012	192	06.15.2030	2.34% p.y. above TJLP	Monthly	40,050	36,653	38,482
(30)	11211541	GE S.B. do Norte	03.19.2012	192	06.15.2030	2.34% p.y. above TJLP	Monthly	90,900	83,127	87,275
(30)	11211551	GE Olho D'Água	03.19.2012	192	06.15.2030	2.34% p.y. above TJLP	Monthly	97,000	88,778	93,229
									1,604,789	1,692,775
							Single
(31)	Promissory notes	Copel GeT	12.29.2015	1	12.18.2017	117% of DI	installment	500,000	638,451	581,909
							Single
(32)	Promissory notes	Copel GeT	05.12.2017	1	05.12.2019	117% of DI	installment	500,000	518,739	-
									1,157,190	581,909
Banco do Brasil
BNDES Transfer
(33)	21/02000-0	Copel GeT	04.16.2009	179	01.15.2028	2.13% above TJLP	Monthly	169,500	120,990	128,721
									120,990	128,721
Total local currency									4,311,387	3,955,788
									4,397,977	4,046,293
								Current	1,346,549	1,470,742
								Noncurrent	3,051,428	2,575,551

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		Issue	Number of	Final	Annual rate p.y.	Finance		Parent Company
	Contracts	Date	installment	maturity	(interest + commission)	charges	Principal	09.30.2017	12.31.2016
Foreign currency
	STN
(1)	Par Bond	05.20.1998	1	04.11.2024	6.0% + 0.20%	Half-yearly	17,315	51,394	53,498
(1)	Discount Bond	05.20.1998	1	04.11.2024	1.1875%+0.20%	Half-yearly	12,082	35,196	37,007
								86,590	90,505
Local currency
	Banco do Brasil
(10)	NCI 330.600.132	02.28.2007	3	02.28.2019	107.8% of DI	Half-yearly	231,000	154,650	241,312
(11)	NCI 330.600.151	07.31.2007	3	07.31.2017	111.0% of DI	Half-yearly	18,000	-	6,366
(12)	CCB 306.401.381	07.21.2017	3	07.21.2020	120.0% of DI	Half-yearly	640,005	646,546	677,177
(13)	NCI 306.401.445	02.24.2017	2	02.15.2020	124.5% of DI	Half-yearly	77,000	76,292	-
								877,488	924,855
								964,078	1,015,360
							Circulante	304,519	453,288
						Não circulante		659,559	562,072

Allocation:

(1) The restructuring of medium and long-term debt in connection w ith the financing received under Law No. 4,131/1962.

(2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12) (13) Working capital.

(14) National Program for Watering - Proni. (15) Rural Electricity Program -Luz para Todos.

(16) Operation for the acquisition of machinery and/or equipment and IT and automation equipment. (17) BEL project - ultra w ide band intranet service (Ultra Wide Band - UWB).

(18) (33) Construction of the Mauá Hydroelectric Pow er Plant and its transmission system, in consortium w ith Eletrosul. (19) Implementation of transmission line betw een substations Foz do Iguaçu and Cascavel Oeste.

(20) Purchase of machinery and equipment for implementation of the transmission line described above. (21) Implementation of Cavernoso II SHP.

(22) Implementation of HPP Colíder and associated transmission system. (23) Implementation of the 230/138kV Cerquilho III Substation.

(24) Implementation of transmission line Assis – Paraguaçu Paulista II.

(25) Implementation of transmission lines Londrina – Figueira and Salto Osório – Foz do Chopim C2.

(26) Investment in preservation of businesses, improvements, operational support and general investments in expansion. (27) National machinery and equipment accredited by BNDES.

(28) Implementation, expansion and consolidation of projects and Enterprises Social Investment Programs (ISE). (29) (30) Construction and implementation of w ind generating plant.

(31) Payment of grant – auction 012/2015, relative to HPP GPS.

(32) Payment of the first installment of Copel’s debentures and w orking capital improvement of Copel GeT.

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Guarantees:

(1) Company’s centralized revenues account. Deposited Collateral (23.1).

(2) (3) Pledge until 360 days.

(2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12) (13) (20) Credit assignment.

(14) (15) Ow n revenue, supported by pow er of attorney granted by a public instrument, and the issue of promissory notes and commercial duplicates equal to the number of installments falling due.

(16) Fiduciary assignment of trade notes.

(17) Withhold the amounts from the checking account in w hich revenues are deposited.

(18) (21) (33) Total revenue from the sale and/or transaction of CCEAR energy, related to the project, through Concession Agreement of Attachment of Revenues, Account Management and Other Covenants.

(19) (20) Fiduciary assignment of rights under the Concession Agreement No. 027/2009-ANEEL, Transmission Service Provision Contract No. 09/2010-ONS and contracts for use of Transmission System, signed by the ONS, the Dealerships and the Transmission System users, including the total income from the provision of transmission services.

(22) Fiduciary assignment of rights under the Concession Agreement No. 01/2011MME-HPP Colíder and fiduciary assignment due to the Purchase and Sale of Energy Eétrica (CCVEE) betw een Copel and BRF - Brasil Foods S.A.

(23) Fiduciary assignment of rights under the Public Service Concession Agreement for Electric Pow er Transmission No. 015/2010-ANEEL, signed betw een Copel and the Federal Government.

(24) Assignment of credit rights deriving from Concession Agreement No. 002/2013 - ANEEL. (25) Assignment of credit rights deriving from Concession Agreement No. 022/2012 - ANEEL.

(26) (27) (28) Surety of Companhia Paranaense de Energia; fiduciary assignment of income and indemnity rights of the concession.

(29) Guarantee from Companhia Paranaense de Energia; pledge of shares; assignment of credit rights deriving from Electricity Agreement Reservation No. 153/2011; assignment of revenues arising from the project.

(30) Pledge of shares (GE Farol, GE Boa Vista, GE São Bento do Norte and GE Olho D'Água); assignment of receivables arising from the sale of electricity produced by the project; assignment of machinery and equipment assembled or built w ith the funds pegged to it.

(31) (32) Surety of Companhia Paranaense de Energia.

23.1 Collateral and escrow deposits - STN

Guarantees provided in the form of Par Bonds for R$42,838 (R$42,988 at December 31, 2016), and Discount Bonds in the amount of R$29,927 (R$30,086 at December 31, 2016), to be used to repay amounts of principal corresponding to STN contracts, when these payments are due on April 11, 2024. The amounts are updated by applying the weighted average percentage changes of United States Treasury Zero Coupon bond prices, by the share of each series of the instrument in the portfolio of collateral for principal, provided in the context of the Brazilian Financing Plan – 1992;

23.2 Breakdown of loans and financing by currency and index

Consolidated
		09.30.2017	%	12.31.2016	%
Foreign currency - change in currencies in the period (%)
U.S. Dolar	(5.50)	86,590	1.97	90,505	2.24
		86,590	1.97	90,505	2.24
Local currency - accumulated index in the period (%)
CDI	8.14	2,301,288	52.33	2,057,320	50.84
TJLP	7.00	1,658,391	37.71	1,743,974	43.10
TR	0.00	23,130	0.53	28,778	0.71
Without indexer	0.00	328,578	7.46	125,716	3.11
		4,311,387	98.03	3,955,788	97.76
		4,397,977	100.00	4,046,293	100.00

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(CONVENIENCE TRANSLATION INTO ENGLISH FROM THE ORIGINAL PREVIOUSLY ISSUED IN PORTUGUESE)

23.3 Maturity of noncurrent installments

	Parent Company			Consolidated
	Foreign	Local		Foreign	Local
09.30.2017	currency	currency	Total	currency	currency	Total
2018	-	-	-	-	95,240	95,240
2019	-	325,756	325,756	-	1,207,943	1,207,943
2020	-	248,929	248,929	-	406,794	406,794
2021	-	-	-	-	140,818	140,818
2022	-	-	-	-	136,500	136,500
After 2022	84,874	-	84,874	84,874	979,259	1,064,133
	84,874	574,685	659,559	84,874	2,966,554	3,051,428

23.4 Changes in loans and financing

Consolidated	Foreign currency		Local currency
	Current	Noncurrent	Current	Noncurrent	Total
Balance as of January 1, 2017	836	89,669	1,469,906	2,485,882	4,046,293
Funding	-	-	50,333	749,712	800,045
Charges	2,816	-	299,590	13,190	315,596
Monetary and exchange variations	-	(4,795)	4,273	10,275	9,753
Transfers	-	-	292,505	(292,505)	-
Amortization - principal	-	-	(430,538)	-	(430,538)
Payment - charges	(1,936)	-	(341,236)	-	(343,172)
Balance as of September 30, 2017	1,716	84,874	1,344,833	2,966,554	4,397,977

23.5 Covenants

The Company and its subsidiaries signed loan and financing agreements containing covenants that require economic and financial ratios to remain within pre-determined parameters, requiring annual fulfillment and other conditions to be observed, such as not making any alteration to the Company’s shareholdings in the capital stock of subsidiaries that would alter control without prior consent. Failing to fulfil these conditions may lead to accelerated debt repayment and/or fines.

At December 31, 2016, all financial ratios measured only annually and at September 30. 2017, all the other indicators and conditions agreed had been fulfilled.

The financial covenants contained in the loan and financing agreements are presented below:

Company	Contract	Financial index	Limit
	BNDES Finem nº 820989.1 - Mauá
		EBITDA / Net financial results	≥ 1.3
	Banco do Brasil nº 21/02000-0 - Mauá
Copel GeT
	2ndissue of Promissory Notes	Consolidated net debt / Consolidated EBITDA	≤ 3.5
		Debt service coverage ratio	≥1.5
Copel DIS	BNDES Finem nº 14205611	Financial indebtedness / adjusted EBITIDA	≤5.0
Santa Maria Energias Renováveis	BNDES Finem nº 14212711
		Debt service coverage ratio	≥1.3
Santa Helena Energias Renováveis	BNDES Finem nº 14212721
São Bento Energia, Investimento e Participações	BNDES Assignment Agreement
GE Boa Vista S.A.	BNDES Finem nº 11211531
GE Farol S.A.	BNDES Finem nº 11211521	Debt service coverage ratio	≥1.3
GE Olho D´Água S.A.	BNDES Finem nº 11211551
GE São Bento do Norte S.A.	BNDES Finem nº 11211541
Financing for businesses - Finem

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24Debentures

Issue		Company	IssueDate	Number of installment	Maturity		Annual rate p.y.(interest)	Principal	Consolidated
					initial	final			09.30.2017	12.31.2016
(1)	5th	Copel	05.13.2014	3	05.13.2017	05.13.2019	111.5% of DI	1,000,000	692,646	1,017,099
(2)	6th	Copel	06.29.2017	1	-	06.28.2019	117.0% of DI	520,000	531,556	-
(3)	1st	Copel GeT	05.15.2015	3	05.15.2018	05.15.2020	113.0% of DI	1,000,000	1,038,682	1,094,731
(4)	2nd	Copel GeT	07.13.2016	2	07.13.2018	07.13.2019	121.0% of DI	1,000,000	1,014,485	1,060,613
(5)	1st	Copel DIS	10.30.2012	2	10.30.2016	10.30.2017	DI + Spread 0.99% p.y.	1,000,000	522,148	511,525
(6)	2nd	Copel DIS	10.27.2016	2	10.27.2018	10.27.2019	124.0% of DI	500,000	558,374	504,699
(7)	1st	Copel TEL	10.15.2015	5	10.15.2020	10.15.2024	IPCA + 7.9633% p.y.	160,000	181,227	174,184
(8)	2nd	Copel TEL	07.15.2017	1	-	07.15.2022	IPCA + 5.4329	220,000	215,675	-
(9)	2nd	Elejor	09.26.2013	60	10.26.2013	09.26.2018	DI + Spread 1.00% p.y.	203,000	40,499	70,984
(10)	1st	Compagás	06.15.2013	40	09.15.2015	12.15.2018	TJLP+1.7% p.y.+1.0% p.y.	62,626	23,955	38,018
(11)	2nd	Compagás	04.15.2016	57	07.15.2017	12.15.2021	TJLP/Selic + 2.17% p.y.	33,620	24,909	23,768
(12)	2nd	(a)	03.24.2016	192	08.15.2016	07.15.2032	TJLP + 2.02% p.y.	147,575	138,776	143,407
(13)	2nd	(a)	03.24.2016	192	08.15.2016	07.15.2032	IPCA + 9.87% p.y.	153,258	145,786	151,781
									5,128,718	4,790,809
								Current	1,930,858	1,131,198
							Noncurrent		3,197,860	3,659,611
(a)	Nova Asa Branca I, Nova Asa Branca II, Nova Asa Branca III, Nova Eurus IV e Ventos de Santo Uriel.

Characteristics:

(1) (2) (3) (4) (5) (6) (7) (8) (9) Simple debentures, single series, not convertible into shares, unsecured, for public distribution w ith restricted placement efforts, according to CVM No. 476.

(10) (11) Simple floating debentures, issued privately in a single series and not convertible into shares.

(12) Simple debentures, 1^stserie, issued privately and not convertible into shares.

(13) Simple debentures, 2^ndserie, issued privately and not convertible into shares.

Finance charges:

(1) Half-yearly interest - May and November.

(2) Interest on the maturity of the agreement

(3) Anuual interest - May.

(4) Anuual interest - July.

(5) (7) Half-yearly interest - April and October.

(6) Anuual interest - October.

(8) Half-yearly interest - January and July.

(9) (12) (13) Monthly interest.

(10) (11) Quarterly interest - March, June, September and December.

Allocation:

(1) (2) (3) (4) (5) (6) Working capital or used to make investments in the issuer.

(7) (8) Deployment, expansion and modernization of the telecommunication netw ork.

(9) Full settlement of the loan agreement w ith Copel.

(10) (11) Fund investment plan of the issuer.

(12) (13) Implementation of w ind farms and associated transmission systems.

Collaterals:

(1) (2) (3) (4) (5) (6) (7) (8) (9) Personal guarantee

(10) (11) Floating

(12) (13) Real and personal guarantee and pledge of Copel Geração e Transmissão's shares.

Guarantor:

(1) (2) (3) (4) (5) (6) (7) (8) (12) (13) Copel.

(9) Copel, at the ratio of 70% and Paineira Participações S.A., at the ratio of 30%.

(10) (11) Compagás.

Trustee:

(1) (2) (3) (4) (5) (6) (7) (8) (9) Pentágono S.A. DTVM.

(10) (11) BNDES Participações S.A. - BNDESPAR.

(12) (13) None.

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24.1 Maturity of noncurrent installments

09.30.2017	Parent Company	Consolidated
2018	-	258,132
2019	864,653	1,965,782
2020	-	366,566
2021	-	42,446
2022	-	282,626
After 2022	-	282,308
	864,653	3,197,860

24.2 Changes in debentures

Consolidated
	Current	Noncurrent	Total
Balance as of January 1, 2017	1,131,198	3,659,611	4,790,809
Funding	-	742,521	742,521
Charges and monetary variations	434,230	4,313	438,543
Transfers	1,208,585	(1,208,585)	-
Amortization - principal	(393,800)	-	(393,800)
Payment - charges	(449,355)	-	(449,355)
Balance as of September 30, 2017	1,930,858	3,197,860	5,128,718

24.3 Covenants

Copel and its subsidiaries issued debentures containing covenants that require certain economic and financial ratios to be kept within pre-determined parameters, requiring annual fulfillment and other conditions to be observed, such as not making any alteration to the Company’s shareholdings in capital stock that would alter control without prior consent from the debenture holders; not paying out dividends or interest on capital if it is in arrears in relation to honoring any of its financial obligations or not keeping the financial ratios as determined without prior written consent of the debenture holders. Failing to fulfil these conditions may lead to accelerated redemption of debentures and regulatory penalties.

At December 31, 2016, all financial ratios measured only annually and at September 30. 2017, all the other indicators and conditions agreed had been fulfilled.

The financial covenants contained in the debenture agreements are presented below:

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Company	Contract	Financial index	Limit
Copel	5thissue de Debentures
	6thissue de Debentures
Copel GeT	1stissue de Debentures	Consolidated net debt / Consolidated EBITDA	≤3.5
	2ndissue de Debentures	Debt service coverage ratio	≥ 1.5
Copel DIS	2ndissue de Debentures
Copel TEL	1stissue de Debentures
	2ndissue de Debentures
Copel DIS	1stissue de Debentures	Consolidated net debt / Consolidated EBITDA	≤ 4.0
Elejor	2ndissue de Debentures	Debt service coverage ratio	≥1.2
Compagás	2ndissue de Debentures	Consolidated net debt / Consolidated EBITDA	≤ 3.5
		General Indebtedness	≤ 0.7
Nova Asa Branca I
Nova Asa Branca II
Nova Asa Branca III	2ndissue de Debentures	Debt service coverage ratio	≥ 1.3
Nova Eurus IV
Ventos de Santo Uriel

25Post-employment Benefits

The Company and its subsidiaries sponsor private retirement and pension plans (Unified Pension Plan and Pension Plan III) and medical and dental care (“ProSaúde II” and “ProSaúde III” Plans) for their active employees and their dependents. The lifetime sponsorship of the healthcare plan for retirees, pensioners and legal dependents is only applied to “Prosaúde II” plan participants.

25.1 Benefit Pension Plan

The unified pension plan is a Defined Benefit Plan - BD in which the income is predetermined, according to each individual’s salary, and pension plan III is a Variable Contribution Plan - CV.

The Defined Benefit plan - BD is a closed plan for new participants since 1998. The Variable Contribution plan - CV is the only plan available for new participants.

The costs assumed by the sponsors for these plans are recognized according to the actuarial valuation prepared annually by independent actuaries in accordance with CPC 33 (R1) and correlated to IAS 19 (R1) and IFRIC 14. The economic and financial assumptions for purposes of the actuarial valuation are discussed with the independent actuaries and approved by the sponsor’s management.

25.2 Healthcare Plan

The Company and its subsidiaries allocate resources for the coverage of healthcare expenses incurred by their employees and their dependents, within rules, limits, and conditions set in “ProSaúde II” and “ProSaúde III” Plans’ regulations. Coverage includes periodic medical exams in both plans and is only extended to all retirees and pensioners for life in the “ProSaúde II” plan.

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25.3 Statement of financial position and statement of income

Amounts recognized in liabilities, under Post-employment Benefits, are summarized below:

		Parent Company			Consolidated
		09.30.2017	12.31.2016	09.30.2017	12.31.2016
Pension plans		3	7	636	1,252
Healthcare plans		3,955	3,698	805,553	768,613
		3,958	3,705	806,189	769,865
	Current	171	188	47,572	47,894
	Noncurrent	3,787	3,517	758,617	721,971

The consolidated amounts recognized in the statement of income are shown below:

.	Parent Company		Consolidated
	09.30.2017	09.30.2016	09.30.2017	09.30.2016
Employees
Pension plans	1,335	1,266	58,281	54,930
Healthcare plan - post employment	389	1,891	72,321	96,573
Healthcare plan - active employees	509	591	60,341	55,664
(-) Transfers to construction in progress	-	-	(16,569)	(15,748)
	2,233	3,748	174,374	191,419
Management
Pension plans	557	348	1,003	775
Healthcare plan	80	74	135	169
	637	422	1,138	944
	2,870	4,170	175,512	192,363

	Parent Company		Consolidated
	07.01.2017	07.01.2016	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016	to 09.30.2017	to 09.30.2016
Employees
Pension plans	451	323	19,074	18,303
Healthcare plan - post employment	130	(1,826)	24,106	32,152
Healthcare plan - active employees	177	132	20,158	21,090
(-) Transfers to construction in progress	-	-	(5,375)	(5,511)
	758	(1,371)	57,963	66,034
Management
Pension plans	208	114	353	270
Healthcare plan	24	22	42	31
	232	136	395	301
	990	(1,235)	58,358	66,335

25.4 Changes in post-employment benefits

Consolidated
	Current	Noncurrent	Total
Balance as of January 1, 2017	47,894	721,971	769,865
Appropriation of actuarial calculation	-	72,321	72,321
Appropriation of pension and healthcare contributions	108,034	-	108,034
Transfers	35,675	(35,675)	-
Amortizations	(144,031)	-	(144,031)
Balance as of September 30, 2017	47,572	758,617	806,189

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 25.5 Actuarial valuation in accordance with CPC 33 (R1)

In compliance with CPC 33 (R1), the Company and its subsidiaries choose to prepare the actuarial report annually.

The information prepared in compliance with the Actuarial Valuation Report is described in Note 25 to the financial statements for the year ended December 31, 2016.

26Customer Charges Due

Consolidated
	09.30.2017	12.31.2016
Energy Development Account - CDE (a)	121,941	136,450
Tariff flags	15,565	-
Global Reversal Reserve - RGR	5,962	5,262
	143,468	141,712
(a) Aneel published Resolutions No. 2,004/2015 and No. 2,202/2017.

27Research and Development and Energy Efficiency

27.1 Balances recognized for investment in Research and Development (R&D) and the Energy Efficiency Program (EEP)

Consolidated	Amounts payable,		Other	Balance	Balance
	before any related	Amounts payable to	amounts	as of	as of
	prepayments	regulatory agencies	payable	09.30.2017	12.31.2016
Research and Development - R&D
National Fund for Scientific and Technological Development - FNDCT	-	5,648	-	5,648	4,603
MME	-	2,824	-	2,824	2,302
R&D	86,458	-	219,044	305,502	294,088
	86,458	8,472	219,044	313,974	300,993
Energy efficiency program - EEP
National Program of Electricity Conservation - Procel	-	3,723	-	3,723	4,932
EEP	24,847	-	171,995	196,842	177,964
	24,847	3,723	171,995	200,565	182,896
	111,305	12,195	391,039	514,539	483,889
			Current	269,755	231,513
		Noncurrent		244,784	252,376

27.2 Changes in R&D and EEP balances

Consolidated	FNDCT	MME	R&D		Procel	EEP
	current	current	current	noncurrent	current	current	noncurrent	Total
Balance as of January 1, 2017	4,603	2,302	135,401	158,687	4,932	84,275	93,689	483,889
Additions	21,599	10,799	875	20,723	6,183	-	24,731	84,910
Performance agreement	-	-	-	-	-	-	1,057	1,057
Selic interest rate (Note 34)	-	-	4,810	11,108	(128)	5,219	6,751	27,760
Transfers	-	-	59,818	(59,818)	-	12,144	(12,144)	-
Payments	(19,688)	(9,844)	-	-	(7,264)	-	-	(36,796)
Concluded projects	(866)	(433)	(26,102)	-	-	(18,880)	-	(46,281)
Balance as of September 30, 2017	5,648	2,824	174,802	130,700	3,723	82,758	114,084	514,539

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28Accounts Payable Related to Concession

Consolidated	Company	Grant	Signature	Closing	Discount Rate	Annual Adjustment	09.30.2017	12.31.2016
(1) HPP Mauá	Copel GeT	06.29.2007	07.03.2007	07.2042	5.65% p.y.	IPCA	16,321	16,235
(2) HPP Colider	Copel GeT	12.29.2010	01.17.2011	01.2046	7.74% p.y.	IPCA	23,050	22,783
(3) HPP Baixo Iguaçu	Copel GeT	07.19.2012	08.20.2012	01.2047	7.74% p.y.	IPCA	6,789	6,299
(4) SHP Cavernoso	Copel GeT	07.11.2013	07.11.2013	07.2018	7.74% p.y.	IPCA	37	66
(5) HPP Apucaraninha	Copel GeT	07.11.2013	07.11.2013	07.2018	7.74% p.y.	IPCA	258	460
(6) HPP Chaminé	Copel GeT	07.11.2013	07.11.2013	07.2018	7.74% p.y.	IPCA	447	795
(7) HPP Derivação Rio Jordão	Copel GeT	07.11.2013	02.24.2014	02.2019	7.74% p.y.	IPCA	371	532
(8) HPP Fundão e HPP Santa Clara	Elejor	10.23.2001	10.25.2001	10.2036	11.00% p.y.	IGPM	501,565	518,372
							548,838	565,542
						Current	61,798	66,210
						Noncurrent	487,040	499,332

Discount rate applied to calculate present value:

Actual net discount rate, in line w ith the estimated long-term rate. It bears no relationship w ith the expected project return.

Payment to the federal government:

Monthly installments equivalent to 1/12 of the annual payment restated, as defined in the concession agreement.

 28.1  Changes in accounts payable related to concession

Consolidated
	Current	Noncurrent	Total
Balance as of January 1, 2017	66,210	499,332	565,542
Additions	-	491	491
Adjust to present value	-	1,151	1,151
Monetary variations	-	31,104	31,104
Transfers	45,038	(45,038)	-
Payments	(49,450)	-	(49,450)
Balance as of September 30, 2017	61,798	487,040	548,838

29Other Accounts Payable

Consolidated
		09.30.2017	12.31.2016
Agreement Ivaí Engenharia (Note 30.1.2 - g)		30,811	122,068
Aneel Order No. 084/2017 provision		21,311	20,542
Public lighting rate collected		21,298	27,565
Customers		27,946	32,283
Pledges in guarantee		15,721	8,067
Financial offset for the use of w ater resources		15,423	28,880
Investment acquisition		9,447	9,595
Reimbursements to customer contributions		5,128	10,894
Other liabilities		51,261	35,422
		198,346	295,316
	Current	143,670	264,791
	Noncurrent	54,676	30,525

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30Provisions for Legal Claims

The Company and its subsidiaries are defendants in various judicial and administrative proceedings before different courts. Based on assessments made by the Company’s legal counsel, Management makes provisions for actions in which losses are rated probable, thus meeting the criteria for recognition of provisioning described in Note 4.9 to the financial statements at December 31, 2016.

The Company’s management believes that, at the time of preparation of financial statements, it is not practicable to provide information regarding the expected timing of any cash outflows resulting from these legal actions in which the Company and its subsidiaries are involved, due to the slow pace and unpredictability of Brazilian legal, tax and regulatory systems, and since final resolution of the proceedings for which a provision has been registered depends on the conclusions of court proceedings. Therefore, this information is not being provided.

30.1 Provisions for litigation

30.1.1Changes in provisions for litigation in actions rated as probable losses

Parent company	Balance as of January 1, 2017	Income		Discharges	Balance as of September 30, 2017
		Additions	Reversals
Tax
Cofins (a)	93,892	7,476	(23,032)	-	78,336
Others (b)	23,335	780	-	(59)	24,056
	117,227	8,256	(23,032)	(59)	102,392
Labor (c)	18	322	(4)	(7)	329
Civil (f)	20,578	2,112	-	-	22,690
Regulatory (j)	15,121	-	-	-	15,121
	152,944	10,690	(23,036)	(66)	140,532

30.1.2Description of nature and/or details of the principal actions

a)Contribution for Social Security Funding (COFINS)

Plaintiff:Federal Tax Authority

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Cofins payables and respective interest and fines from August 1995 to December 1996 due to the termination of a judicial decision that had recognized the Company’s exemption from Cofins.

Current status:awaiting judgment.

b)Other tax provisions

Actions relating to federal, state and municipal taxes, fees and other charges . The principal action is described below:

Defendant: Federal Tax Authority

By the case 5037809-14.2015.4.04.7000, Copel GeT required payment in installments of the balance owed on the annual adjustment of corporate income tax (IRPJ) and social contribution (CSLL) for the fiscal year 2014. The Federal Tax Authority consolidated the amount and applied the maximum fine. An injunction was filed against this decision since the Federal Tax Authority failed to obey the limit established in legislation.

Current status Awaiting judgment of the Special Appeal. On December 31, 2016, the amount of R$32,318 was transferred to Other Tax Liabilities.

c)Labor

Labor claims comprise claims filed by employees and former employees of Copel and its subsidiaries in connection with the payment of overtime, hazardous working conditions, transfer bonuses, salary equality/reclassification, and other matters, and also claims by former employees of contractors and third-parties (secondary responsibility) involving indemnity and other matters.

d)Employee benefits

Labor claims comprise claims filed by retired former employees of the Company and its wholly owned subsidiaries against the Copel Foundation, which will have consequential impact on the Company and its wholly owned subsidiaries, since additional contributions will be required.

e)Civil and administrative claims

Actions involving billing, irregular procedure, administrative contracts and contractual fine, indemnity for accidents with the electric power grid or vehicles. The main lawsuits are as follows:

Plaintiff: Tradener Ltda.                                                                      Estimated amount: R$112,834

Class action No. 588/2006 has already been rendered final and unappeasable, and the ruling recognized as valid commissions payable by the Company to Tradener. In the civil public action No. 0000219-78.2003.8.16.0004, filed by the Prosecution Office, a decision has also been rendered ruling on the absence of irregularities in the electric power purchase agreement. Therefore, Tradener brought recovery lawsuits, seeking to receive its commissions.

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Current status:Case record 0005990.22.2012.8.16.0004 - the Company was ordered to pay the amount of R$112,834, which is the value updated by the (INPC/IBGE) from the maturity of the commissions, plus default interest of 1% per month, as of the date of notification (October 31, 2012), as well as attorneys’ fees. The Company filed an appeal against this decision, however, on November 8, 2016, by majority votes, the Court dismissed the appeal. Copel filed a request for Amendment of Judgment, which was partially granted to resolve obscurity, although without changing the result of the appeal. Copel filed a Special Appeal with the Superior Court of Justice.

f)Easements

Lawsuits are filed when there is a difference between the amount determined by Copel for payment and the amount claimed by the owner and/or when the owner's paper title may not be registered (probate proceedings are underway, properties have no registry number, etc.).

They may also involve third-party interventions for adverse possession, whether from owners or occupants of contiguous properties or even in cases of properties where right of way easements is required to preserve limits and boundaries of these areas.

g)Expropriations and property

Lawsuits are filed challenging expropriation when there is a difference between the amount determined by Copel for payment and the amount claimed by the owner and/or when the owner's paper title may not be registered (probate proceedings are underway, properties have no registry number, etc.).

Possessory case actions include those for repossession of property owned by the concessionaire. Litigation arises when there is a need to repossess properties invaded or occupied by third parties in areas owned by the Company. Cases may also arise from intervention in third-party adverse possession, or owners or occupants of contiguous properties or even in cases of properties to preserve limits and boundaries of expropriated areas. The principal action is described below:

Plaintiff: Ivaí Engenharia de Obras S.A.

Declaratory action brought by the plaintiff in order to recognize the right to economic and financial rebalancing of the contract signed with Copel GeT, followed by an action for relief from judgment filed by Copel to vacate the final and unappealable decision in the declaratory judgment action, followed by a collection suit filed by the plaintiff to collect the amounts arising from the economic and financial rebalance of the agreement and followed by compliance with the provisional decision proposed by the plaintiff.

Current status: On October 21, 2016, Copel signed an agreement, previously approved by the Board of Directors, whereby it undertook to pay to Ivaí Engenharia R$152,250, in 15 monthly and consecutive installments of R$10,150. From the second installment, the base amount will be adjusted for inflation, as of the signature of the agreement, at 50% of the last IPCA index disclosed until the maturity date of each installment. The agreement comprises the existing discussions between the parties and suspends the ongoing collection suits, under appeal in the STJ, and compliance with provisional sentence, until the payment of all the installments of the agreement, when the abovementioned lawsuits will be dismissed. On September 30, 2016, R$152,250 was transferred to Other accounts payable (Note 29). The agreement has been complied with by Copel and the installments have been timely paid.

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h)Consumers

Lawsuits seeking compensation for damages caused in household appliances, lawsuits claiming damages for pain and suffering caused by service interruption and lawsuits filed by industrial consumers challenging the lawfulness of the increase in electricity prices while Plano Cruzado (anti-inflation plan) was in effect and claiming reimbursement for the amounts paid by the Company.

i)Environmental

Class actions whose purpose is to obstruct the progress of environmental licensing for new projects or to recover permanent preservation areas located around the hydroelectric power plant dams unlawfully used by private individuals. If the outcome of the lawsuits is unfavorable to the Company, management estimates only the cost to prepare new environmental studies and to recover the areas owned by Copel GeT.

They also contemplate the “Termos de Ajuste de Conduta –TAC”, which refers to the commitments agreed upon and approved between the Company and the competent bodies for noncompliance with any condition contained in the Installation and Operation Licenses. As they are considered liabilities, these amounts are recorded as "obligations" in current and non-current liabilities and the balancing items in property, plant and equipment (construction cost).

j)Regulatory

The Company is challenging, both at the administrative and judicial levels, notifications issued by the Regulatory Agency of alleged violations against regulations. The main lawsuit is described below:

Plaintiffs: Companhia Estadual de Energia Elétrica - CEEE and Dona Francisca Energética S.A.

Estimated amount: R$49,655

Copel, Copel GeT and Copel DIS are challenging lawsuits filed against ANEEL's decision No. 288/2002 involving these companies.

Current status:awaiting judgment.

30.2 Contingent liabilities

30.2.1Classification of actions rated as possible losses

Contingent liabilities are present obligations arising from past events for which no provisions are recognized because it is probable that an outflow of resources embodying economic benefits will be required to settle the obligation. The following information concerns the nature of the Company’s contingent liabilities and potential losses arising thereof.

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	Parent company		Consolidated
	09.30.2017	12.31.2016	09.30.2017	12.31.2016
Tax (a)	507,427	484,539	846,557	752,625
Labor (b)	347	146	319,111	423,495
Employee benefits (c)	-	-	24,231	23,631
Civil (d)	11,170	10,302	587,205	594,220
Regulatory (e)	-	-	790,640	765,906
	518,944	494,987	2,567,744	2,559,877

30.2.2Description of nature and/or details of the principal actions

a)Tax

Actions relating to federal, state and municipal taxes, fees and other charges in which the Company challenges their applicability, calculation bases and amounts due to be collected. The main lawsuits are as follows:

Plaintiff: Social Security National Institute (INSS)                                 Estimated amount: R$322,401

Tax claims against Copel related to social security contribution on assignment of manpower (lawsuit No. 5003583-56.2010.404.7000); it is worth emphasizing that the case has already been judged favorably to the Company at two court levels, awaiting judgment by the Superior Court of Justice (STJ).

Current status:awaiting judgment.

Plaintiff: Social Security National Institute (INSS)                                 Estimated amount: R$27,698

Tax collections against Copel consisting of social security contribution imposed on the assignment of labor (NFLD - 35.273.876-6). The case has been at Carf (Brazilian Administrative Tax Court) for judgment since 2010. The assessment of risk as possible is due to the existence of several legal arguments to defend the Company, particularly (a) the fact that no services were provided and no labor was assigned and (b) the fact that service providers classified into the Simples (lower taxation) category are not required to withhold that contribution.

Current status:awaiting judgment.

Plaintiff: State Tax Authority (SEFAZ)                                                 Estimated amount: R$67,624

Copel DIS received tax deficiency notice 6.587.156-4 from the State of Paraná for allegedly failing to pay ICMS (VAT) tax on the ‘metered demand’ line in the electricity bills issued to a major consumer between May 2011 and December 2013.

Copel DIS maintains its illegitimacy to appear in the taxable position of this tax assessment, since it was not included in the judicial process, cannot suffer the effects of the judicial decision pronounced in it, which would imply in its illegitimacy to appear in the taxable position of thetax deficiency notice 6.587.156-4.

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b)Labor

Labor claims comprise claims filed by Copel employees and former employees in connection with the payment of overtime, hazardous working conditions, transfer bonuses, salary equality/reclassification, and other matters, and also claims by former employees of contractors and third-parties (secondary responsibility) involving indemnity and other matters.

c)Employee benefits

Labor claims comprise claims filed by retired former employees of the Company and its wholly owned subsidiaries against the Copel Foundation, which will have consequential impact on the Company and its wholly owned subsidiaries, since additional contributions will be required.

d)Civil

Actions involving billing, irregular procedure, administrative contracts and contractual fine, indemnity for accidents with the electric power grid and vehicles. The main lawsuits are as follows:

Plaintiff: Mineradora Tibagiana Ltda.                                                          Estimated amount: R$153,022

Action claiming compensation for alleged losses when this mining company was involved in the construction of the Mauá plant by the Energético Cruzeiro do Sul consortium in which Copel GeT has a 51% stake. The action challenges the validity of the mining permit granted by Mineradora Tibagiana for the Mauá job site and the indemnifying effects arising thereof.

Current status:action awaiting judgment in lower court.

Plaintiff: Ivaí Engenharia de Obras S.A.

Action for collection brought by the plaintiff in order to collect amounts arising from economic and financial rebalancing of the contract signed with Copel GeT, recognized in the declaratory action.

Current status: As described in Note 30.1.2, the parties entered into an agreement, that comprises the discussions between the parties on the economic and financial balance of the agreement and suspends the ongoing collection suits, under appeal in the STJ, and compliance with provisional sentence, until the payment of all the installments of the agreement, when the abovementioned lawsuits will be dismissed. The agreement has been complied with by Copel and the installments have been timely paid.

Plaintiffs:franchises of the Agency / Copel store                                Estimated amount: R$52,775

Filing of two individual claims against Copel Distribuição regarding the franchise contracts of Copel branches/stores, with the main petition claiming an extension of the term of the contract and secondary petition to recognize the existence of a sub concession, with transfer of the services provided and full pass-through of the fees, amongst other amounts, currently have appeals awaiting trial.

Current status:awaiting judgment.

e)Regulatory

The Company is challenging, both at the administrative and judicial levels, notifications issued by the Regulatory Agency of alleged violations against regulations. The main lawsuits are as follows:

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Plaintiff: ANEEL                                                                                Estimated amount: R$18,922

Copel DIS filed an appeal against a decision by ANEEL's Director-General under Resolution No. 3,959 from December 8, 2015 imposing an inefficiency penalty on Copel DIS due to over-contracting for use of the distribution system (MUSD) with the National Power Network Operator (ONS), obtaining an injunction to suspend the requirement of such penalty.

Current status:awaiting judgment.

Plaintiff: Energia Sustentável do Brasil S.A. - ESBR                            Estimated amount: R$729,609

ESBR brought Ordinary Action No. 10426-71.2013.4.01.4100 against Aneel in the federal courts of Rondônia, the decision on which: (i) excludes liability for the 535-day schedule overrun in the construction of the Jirau Hydropower Station; (ii) declares any obligations, penalties and costs imposed on ESBR as a result of the schedule overrun to be unenforceable, and (iii) annuls ANEEL Resolution No. 1,732/2013, which recognized a schedule overrun of only 52 days. An appeal has been brought by ANEEL, in progress at the TRF of the 1st Region.

The practical outcome of the decision is that, by exempting ESBR, it exposed the distribution utilities with which it had concluded regulated power trading contracts (CCEARs) – including Copel DIS – to the spot market and spot prices during the period. The reason is that electricity trading rules require that all electricity consumed be covered by a contract.

The risk of loss in this case is rated ‘possible’, considering the amount of R$729,609, on September 30, 2017. If the actions are judged unfavorably, the amount will be classified as Sectorial Financial Asset to be recovered through tariff rates.

Current status:awaiting judgment.

31Equity

31.1 Capital

The paid-in share capital is R$7,910,000. The different classes of shares (with no par value) and main shareholders are detailed below:

	Number of shares in units
Shareholders	Common		Class "A” Preferred		Class “B” preferred		Total
	in share	%	in share	%	in share	%	in share	%
State of Paraná	85,028,598	58.63	-	-	-	-	85,028,598	31.07
BNDES	38,298,775	26.41	-	-	27,282,006	21.26	65,580,781	23.96
Eletrobrás	1,530,774	1.06	-	-	-	-	1,530,774	0.56
Free float:	-	-	-	-	-	-		-
B3	18,638,728	12.85	76,763	23.36	70,089,876	54.64	88,805,367	32.46
NYSE	1,197,416	0.83	-	-	30,753,498	23.97	31,950,914	11.68
Latibex	-	-	-	-	121,531	0.09	121,531	0.04
Municipalities	178,393	0.12	9,326	2.84	3,471	-	191,190	0.07
Other shareholders	158,396	0.10	242,538	73.80	45,286	0.04	446,220	0.16
	145,031,080	100.00	328,627	100.00	128,295,668	100.00	273,655,375	100.00

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31.2 Equity value adjustments

	Parent company	Consolidated
Balance as of January 1, 2017	998,466	998,466
Adjustments to financial assets available for sale
Financial investments (a)	2	3
Taxes on adjustments	-	(1)
Investments in equity interests	3,560	7,677
Taxes on adjustments	(1,210)	(2,610)
Investments in equity interests - equity (a)	2,717	-
Realization of equity evaluation adjustment
Deemed cost of fixed assets	-	(82,612)
Taxes on adjustments	-	28,088
Deemed cost of fixed assets - equity (a)	(54,524)	-
Balance as of September 30, 2017	949,011	949,011
(a) Equity in the parent company, net of taxes.

31.3 Earnings per share - basic and diluted

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32Net Operating Revenue

Consolidated	Gross revenues	PIS/Pasep and Cofins	ICMS (VAT)	Regulatory charges (31.5)	Service tax (ISSQN)	Net revenues 09.30.2017
Electricity sales to final customers (32.1)	6,241,279	(521,823)	(1,454,051)	(842,787)	-	3,422,618
Electricity sales to distribuitors (32.2)	2,539,716	(203,806)	-	(39,399)	-	2,296,511
Use of the main distribution and transmission grid (32.3)	4,854,026	(434,115)	(1,104,696)	(552,593)	-	2,762,622
Construction income	591,810	-	-	-	-	591,810
Fair value of assets from the indemnity for the concession	8,425	-	-	-	-	8,425
Telecommunications	312,768	(11,540)	(72,296)	-	(1,877)	227,055
Distribution of piped gas	491,241	(46,267)	(84,904)	-	-	360,070
Sectorial financial assets and liabilities result	368,254	(30,549)	-	-	-	337,705
Other operating revenue (32.4)	129,283	(20,248)	-	-	(1,942)	107,093
	15,536,802	(1,268,348)	(2,715,947)	(1,434,779)	(3,819)	10,113,909
Consolidated	Gross revenues	PIS/Pasep and Cofins	ICMS (VAT)	Regulatory charges (31.5)	Service tax (ISSQN )	Net revenues 07.01.2017 to 09.30.2017
Electricity sales to final customers (32.1)	2,180,624	(147,037)	(518,998)	(317,231)	-	1,197,358
Electricity sales to distribuitors (32.2)	896,406	(84,625)	-	(13,299)	-	798,482
Use of the main distribution and transmission grid (32.3)	1,509,598	(148,186)	(371,551)	(195,169)	-	794,692
Construction income	196,994	-	-	-	-	196,994
Fair value of assets from the indemnity for the concession	2,980	-	-	-	-	2,980
Telecommunications	112,663	(4,261)	(25,834)	-	(650)	81,918
Distribution of piped gas	160,853	(15,273)	(28,014)	-	-	117,566
Sectorial financial assets and liabilities result	448,438	(30,549)	-	-	-	417,889
Other operating revenue (32.4)	43,707	(7,276)	-	-	(641)	35,790
	5,552,263	(437,207)	(944,397)	(525,699)	(1,291)	3,643,669
Consolidated	Gross revenues	PIS/Pasep and Cofins	ICMS (VAT)	Regulatory charges (31.5)	Service tax (ISSQN)	Net revenues 09.30.2016 Restated
Electricity sales to final customers (32.1)	7,578,264	(698,178)	(1,934,982)	(814,130)	-	4,130,974
Electricity sales to distribuitors (32.2)	2,207,291	(177,058)	-	(35,269)	-	1,994,964
Use of the main distribution and transmission grid (32.3)	5,457,157	(438,117)	(1,163,066)	(707,026)	-	3,148,948
Construction income	934,665	-	-	-	-	934,665
Fair value of assets from the indemnity for the concession	129,311	-	-	-	-	129,311
Telecommunications	256,907	(9,831)	(57,990)	-	(1,737)	187,349
Distribution of piped gas	506,457	(48,900)	(88,554)	-	-	369,003
Sectorial financial assets and liabilities result	(1,190,132)	-	-	-	-	(1,190,132)
Other operating revenue (32.4)	119,386	(18,039)	-	-	(1,728)	99,619
	15,999,306	(1,390,123)	(3,244,592)	(1,556,425)	(3,465)	9,804,701
Consolidated	Gross revenues	PIS/Pasep and Cofins	ICMS (VAT)	Regulatory charges (31.5)	Service tax (ISSQN )	Net revenues 07.01.2016 to 09.30.2016 Restated
Electricity sales to final customers (32.1)	1,970,839	(181,156)	(500,424)	(217,961)	-	1,071,298
Electricity sales to distribuitors (32.2)	754,903	(59,647)	-	(11,243)	-	684,013
Use of the main distribution and transmission grid (32.3)	1,177,763	(132,308)	(345,816)	(196,236)	-	503,403
Construction income	362,220	-	-	-	-	362,220
Fair value of assets from the indemnity for the concession	6,916	-	-	-	-	6,916
Telecommunications	87,581	(3,344)	(20,250)	-	(628)	63,359
Distribution of piped gas	162,305	(15,256)	(28,214)	-	-	118,835
Sectorial financial assets and liabilities result	64,355	-	-	-	-	64,355
Other operating revenue (32.4)	47,067	(6,745)	-	-	(609)	39,713
	4,633,949	(398,456)	(894,704)	(425,440)	(1,237)	2,914,112

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32.1 Electric sales to final customers by category

Consolidated		Gross revenue		Net revenue
	09.30.2017	09.30.2016	09.30.2017	09.30.2016
Residential	2,020,795	2,514,911	1,008,408	1,372,447
Industrial	1,729,852	2,414,604	1,093,042	1,417,199
Trade, services and other activities	1,371,244	1,661,098	664,775	820,949
Rural	555,450	404,959	371,083	228,392
Public entities	166,881	183,791	95,873	107,929
Public lighting	170,385	178,736	81,886	90,025
Public service	226,672	220,165	107,551	94,033
	6,241,279	7,578,264	3,422,618	4,130,974
Consolidated		Gross revenue		Net income
	07.01.2017	07.01.2016	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016	to 09.30.2017	to 09.30.2016
Residential	717,489	664,474	358,143	360,588
Industrial	600,728	644,416	381,868	382,252
Trade, services and other activities	473,311	409,277	228,961	198,193
Rural	184,956	95,647	124,760	53,351
Public entities	58,730	48,059	33,743	27,876
Public lighting	64,543	48,661	30,981	24,357
Public service	80,867	60,305	38,902	24,681
	2,180,624	1,970,839	1,197,358	1,071,298

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32.2 Electricity sales to distributors

Consolidated		Gross revenue
	09.30.2017	09.30.2016
Bilateral contracts	1,358,780	1,006,160
Electric Energy Trade Chamber - CCEE	800,075	549,885
Agreements for Pow er Trade on the Regulated Market - CCEAR (auction)	279,768	519,419
Interest (Note 10.2)	61,032	77,578
Quota system	40,061	54,249
	2,539,716	2,207,291
Consolidated		Gross revenue
	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016
Bilateral contracts	559,565	346,296
Electric Energy Trade Chamber - CCEE	199,428	196,264
Agreements for Pow er Trade on the Regulated Market - CCEAR (auction)	104,409	173,559
Interest	18,673	20,683
Quota system	14,331	18,101
	896,406	754,903

32.3 Use of the main distribution and transmission grid by customer class

Consolidated		Gross revenue		Net revenue
	09.30.2017	09.30.2016	09.30.2017	09.30.2016
Residential	1,500,912	1,570,219	751,331	736,398
Industrial	823,352	979,589	368,995	449,711
Trade, services and other activities	968,923	1,069,588	469,492	499,959
Rural	257,240	258,340	182,211	180,865
Public entities	127,256	127,074	75,263	70,530
Public lighting	123,540	127,737	60,853	59,471
Public service	94,552	94,933	47,140	44,179
Free consumers	490,681	280,622	382,371	211,202
Basic netw ork, BN connections, and connection grid	1,040	1,148	811	863
Operating and maintenance income - O&M	93,039	113,351	78,023	104,265
Interest income	373,491	834,556	346,132	791,505
	4,854,026	5,457,157	2,762,622	3,148,948
Consolidated		Gross revenue		Net income
	07.01.2017	07.01.2016	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016	to 09.30.2017	to 09.30.2016
Residential	494,425	461,498	242,486	221,303
Industrial	256,095	288,429	100,708	127,572
Trade, services and other activities	328,715	321,004	160,247	156,166
Rural	77,845	72,460	52,895	53,954
Public entities	42,812	38,931	25,035	22,095
Public lighting	42,982	39,610	20,908	18,776
Public service	30,993	29,909	15,104	14,318
Free consumers	173,148	103,077	133,963	78,520
Basic netw ork, BN connections, and connection grid	348	346	270	264
Operating and maintenance income - O&M	11,265	30,367	2,773	25,488
Interest income	50,970	(207,868)	40,303	(215,053)
	1,509,598	1,177,763	794,692	503,403

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32.4 Other operating revenues

Consolidated		Gross revenue
	09.30.2017	09.30.2016
Leasing and rent (32.4.1)	80,708	75,664
Income from rendering of services	22,988	18,110
Charged service	11,211	7,177
Other income	14,376	18,435
	129,283	119,386

Consolidated		Gross revenue
	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016
Leasing and rent (32.4.1)	27,371	26,276
Income from rendering of services	7,578	6,827
Charged service	4,470	2,786
Other income	4,288	11,178
	43,707	47,067

32.4.1Revenues from leases and rentals

Consolidated
	09.30.2017	09.30.2016
Equipment and framew ork	78,586	75,435
Facilities sharing	1,912	43
Real estate	210	186
	80,708	75,664
Consolidated	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016
Equipment and framew ork	27,058	26,193
Facilities sharing	243	12
Real estate	70	71
	27,371	26,276

32.5 Regulatory charges

Consolidated
	09.30.2017	09.30.2016
Energy Development Account - "CDE Energia" (32.5.1)	545,523	680,290
Energy Development Account - "CDE Uso" (32.5.1)	523,252	586,753
Other charges - rate flags	238,346	178,152
Research and development and energy efficiency - R&D and PEE	84,910	73,092
Global Reversion Reserve - RGR quota	35,492	31,362
Inspection fee	7,256	6,776
	1,434,779	1,556,425
Consolidated	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016
Energy Development Account - "CDE Energia"	176,100	293,189
Energy Development Account - "CDE Uso"	185,183	94,194
Research and development and energy efficiency - R&D and PEE	31,800	25,645
Other charges - rate flags	117,710	110
Global Reversion Reserve - RGR quota	12,440	9,849
Inspection fee	2,466	2,453
	525,699	425,440

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32.5.1Energy Development Account - CDE

The primary objectives of the Energy Development Account (CDE) created by Law No. 10,438/2002 and amended by Law No. 12,783/2013, are: (i) universalization; (ii) subsidy to the low income residential subclass; (iii) Fuel Consumption Account - CCC; (iv) amortization of financial operations related to the reversal of assets at the end of the concessions; (v) competitiveness of energy produced from wind power, small hydroelectric plants, biomass, natural gas and coal. CDE’s quotas were originally defined based on the CCC figures for the 2001 Interconnected Systems, the values of which were adjusted annually starting in 2002 in proportion to the market growth of each agent, and in 2004 also by the IPCA. As of Law 12,783/2013, the system is changed and quotas are defined based on the resources needed to achieve its purposes and other revenues related to the CDE. The CDE charge incorporates:

i) annual quota of “CDE-Uso”: this quota is allocated to the financing of the objectives of the CDE, set forth in its annual budget, defined by the Federal Government, as provided in §§ 2 and 3 of art. 13 of Law 10,438/2002, with wording given by Law No. 12,783/2013.

ANEEL Resolution No. 2202/2017 defined the CDE-Uso quota, in the monthly amount of R$53,329 as of January 2017. However, as of February of the same year, the monthly amount of the quota was changed to R$61,159, established by ANEEL Resolution No. 2,204/2017;

ii) annual quota “CDE - Energia” (ACR account): this quota is intended for the discharge of credit operations contracted by CCEE in the management of the Regulated Contracting Environment - ACR Account, in compliance with Decree No. 8,222/2014, and pursuant to Normative Resolution No. 612/2014.

The purpose of the ACR Account is to cover costs relating to involuntary spot market exposure and the costs of thermal power dispatching in 2014.

Resolution No. 1,863/2015 defined the value of the CDE quota (ACR Account) at R$46,638, as of June 2015. Beginning June 2016, by means of Resolution No. 2004/2015, the amount of the quota was updated to R$49,362. In April 2017, the quota was reduced to R$37,907 until March 2018, and from April 2018 to March 2020, the quota will be R$49,362, as approved by Resolution No. 2,231/2017. These installments are updated annually, in accordance with the conditions contracted by CCEE for each of the loans made with the participating financial institutions; and

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iii) annual quota CDE-Energia: this quota is destined to the return of the resources received by the distribution concessionaires, from January 2013 to January 2014, to cover costs relating to involuntary spot market exposure and the hydrological risk of the plants contracted on a regime of quotas, and the costs of thermal power dispatching for reasons of energy security, in compliance with Decree 7,895/2013 and Decree 8,203/2014.

From June 2016 to May 2017, the monthly amount of the CDE-Energia quota was established at R$18,947 by ANEEL Resolution No. 2,077/2016. From June 2017, the monthly quota was changed to R$20,138, by Resolution No. 2,204/2017.

Preliminary injunctions

As a result of preliminary injunctions in favor of the Brazilian Association of Large Industrial Consumers and Free Consumers - Abrace, and of the National Association of Energy Consumers - Anace and other associates, which challenge at court the tariff components of CDE-Uso and CDE-Energia, ANEEL, through Resolutions 1,967/2015, 1,986/2015 and 2,083/2016, ratified the tariff calculation deducting these charges from associates of those entities, as long as the preliminary injunctions granted in Judicial Proceedings No. 24648-39.2015.4.01.3400 and No. 0069262-32.2015.4.01.3400 / 16th Federal Court are in effect.

On the other hand, by the preliminary injunction in favor of Abradee, the associated distributors are guaranteed the right of non-transfer, deducting from the portion of CDE-Uso and CDE-Energia the amounts not collected due to the effects of the preliminary injunction. This deduction, which covers all preliminary injunctions, was approved by Aneel by Order No. 1,576, dated June 14, 2016.

Moreover, in compliance with the preliminary injunction granted in the Judicial Proceedings No. 0028882-30.2016.4.01.3400 of the 2nd Federal Court, ANEEL, through Order No. 2,634, dated September 30, 2016, ratified, regarding the 2016 tariff process, new Tariffs for Use of Distribution Systems - Tusd for Abrace members, effective as of June 29, 2016 for as long as the effects of the preliminary injunction relief remain. In addition to the Abrace and Anace associates, other companies have also obtained favorable injunctions, with publication of new tariffs.

By means of Resolution No. 2,255 of 6/20/2017, Article 14, the tariff components of the Energy Tariff (TE) in R$/MWh, which must be applied in compliance with the injunctions granted in lawsuits that remain for the 2017 tariff process. As shown in table 11 to this Resolution, the customer units included in injunctions 0069262-32.2015.4.01.3400, of the National Association of Energy Consumers - Anace, and No. 0028996-66.2016.4.01.3400, of the Labor Union of Cement Industry - SNIC, currently totaling 7 customer units, will continue to benefit from the reduced tariffs.

Accordingly, the Company has been carrying out the deduction of the payment of the CDE quota from the unbilled amounts resulting from these injunctions, thus not impacting the distributor’s result. The differences between the rate coverage for this charge and the amount actually paid, from the beginning of the preliminary injunction to September 2017, represent the amount of R$111,912 for CDE Uso and R$13,370 for CDE Energy.

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32.6 Copel DIS periodic tariff adjustment

Aneel’s Resolution No. 2,255 of June 20, 2017 approved the result of Copel DIS Annual Tariff Review and authorized a 5.85% average adjustment to be perceived by consumers, consisting of: -0.73% related to the inclusion of financial components; 1.07% from updating Portion B; 2.78% from adjusting Portion A; and 2.73% reflecting the withdrawal of the financial components from the previous tariff process.

This adjustment was fully applied to Copel DIS tariffs as of June 24, 2017.

33Operating Costs and Expenses

Consolidated	Operational costs	Selling expenses	General and administrative expenses	Other operating expenses, net	09.30.2017
Electricity purchased for resale (33.1)	(4,373,174)	-	-	-	(4,373,174)
Charge of the main distribution and transmission grid	(482,258)	-	-	-	(482,258)
Personnel and management (33.2)	(672,712)	(13,516)	(233,766)	-	(919,994)
Pension and healthcare plans (Note 25.3)	(130,876)	(1,770)	(42,866)	-	(175,512)
Materials and supplies	(50,642)	(542)	(7,650)	-	(58,834)
Materials and supplies for pow er electricity	(22,390)	-	-	-	(22,390)
Natural gas and supplies for gas business	(247,914)	-	-	-	(247,914)
Third-party services (33.3)	(282,584)	(13,993)	(88,915)	-	(385,492)
Depreciation and amortization	(513,393)	(11)	(25,858)	(10,129)	(549,391)
Estimated losses, provisions and reversals (33.4)	97,069	(72,254)	-	(122,002)	(97,187)
Construction cost (33.5)	(706,110)	-	-	-	(706,110)
Other operating costs and expenses, net (33.6)	(149,453)	(22,065)	(131,486)	(45,547)	(348,551)
	(7,534,437)	(124,151)	(530,541)	(177,678)	(8,366,807)

Consolidated	Operational costs	Selling expenses	General and administrative expenses	Other operating expenses, net	07.01.2017 to 09.30.2017
Electricity purchased for resale (33.1)	(1,958,195)	-	-	-	(1,958,195)
Charge of the main distribution and transmission grid	(173,068)	-	-	-	(173,068)
Personnel and management (33.2)	(213,254)	(4,816)	(76,684)	-	(294,754)
Pension and healthcare plans (Note 25.3)	(43,417)	(600)	(14,341)	-	(58,358)
Materials and supplies	(16,538)	(115)	(3,222)	-	(19,875)
Materials and supplies for pow er electricity	(8,902)	-	-	-	(8,902)
Natural gas and supplies for gas business	(78,079)	-	-	-	(78,079)
Third-party services (33.3)	(99,974)	(5,139)	(29,793)	-	(134,906)
Depreciation and amortization	(171,360)	(4)	(7,456)	(3,377)	(182,197)
Estimated losses, provisions and reversals (33.4)	158,080	(21,877)	-	(36,165)	100,038
Construction cost (33.5)	(189,011)	-	-	-	(189,011)
Other operating costs and expenses, net (33.6)	(49,857)	(7,888)	(83,222)	(21,428)	(162,395)
	(2,843,575)	(40,439)	(214,718)	(60,970)	(3,159,702)
Consolidated	Operational costs	Sellingexpenses	General and administrative  expenses	Other operating  expenses, net	09.30.2016
Electricity purchased for resale (33.1)	(3,427,377)	-	-	-	(3,427,377)
Charge of the main distribution and transmission grid	(681,554)	-	-	-	(681,554)
Personnel and management (33.2)	(630,181)	(11,920)	(204,412)	-	(846,513)
Pension and healthcare plans (Note 25.3)	(144,108)	(1,908)	(46,347)	-	(192,363)
Materials and supplies	(56,249)	(577)	(6,272)	-	(63,098)
Materials and supplies for pow er electricity	(24,577)	-	-	-	(24,577)
Natural gas and supplies for gas business	(264,236)	-	-	-	(264,236)
Third-party services (33.3)	(270,144)	(39,373)	(93,040)	-	(402,557)
Depreciation and amortization	(499,655)	(26)	(22,298)	(10,129)	(532,108)
Estimated losses, provisions and reversals (33.4)	-	(127,622)	-	(37,345)	(164,967)
Construction cost (33.5)	(927,025)	-	-	-	(927,025)
Other operating costs and expenses, net (33.6)	(180,350)	6,910	(120,962)	(62,446)	(356,848)
	(7,105,456)	(174,516)	(493,331)	(109,920)	(7,883,223)
Consolidated	Operational costs	Sellingexpenses	General and administrative expenses	Other operating expenses, net	07.01.2016 to 09.30.2016
Electricity purchased for resale (33.1)	(1,173,733)	-	-	-	(1,173,733)
Charge of the main distribution and transmission grid	(203,878)	-	-	-	(203,878)
Personnel and management (33.2)	(212,373)	(4,138)	(69,499)	-	(286,010)
Pension and healthcare plans (Note 25.3)	(50,779)	(608)	(14,948)	-	(66,335)
Materials and supplies	(16,942)	(283)	(2,229)	-	(19,454)
Materials and supplies for pow er electricity	(6,365)	-	-	-	(6,365)
Natural gas and supplies for gas business	(64,471)	-	-	-	(64,471)
Third-party services (33.3)	(84,725)	(17,027)	(34,448)	-	(136,200)
Depreciation and amortization	(168,051)	(9)	(7,925)	(3,376)	(179,361)
Estimated losses, provisions and reversals (33.4)	-	(33,736)	-	(74,415)	(108,151)
Construction cost (33.5)	(373,521)	-	-	-	(373,521)
Other operating costs and expenses, net (33.6)	(49,215)	2,872	(51,686)	(12,557)	(110,586)
	(2,404,053)	(52,929)	(180,735)	(90,348)	(2,728,065)

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Parent company	General and administrative expenses	Other operacional income (expenses), net	09.30.2017
Personnel and management (33.2)	(28,314)	-	(28,314)
Pension and healthcare plans (Note 25.3)	(2,870)	-	(2,870)
Materials and supplies	(476)	-	(476)
Third party services	(10,663)	-	(10,663)
Depreciation and amortization	(59)	(840)	(899)
Estimated losses, provisions and reversals (33.4)	-	19,417	19,417
Other operating income (expenses)	(15,261)	13,088	(2,173)
	(57,643)	31,665	(25,978)
Parent company	General and administrative expenses	Other operacional income (expenses), net	07.01.2017 to 09.30.2017
Personnel and management (33.2)	(9,191)	-	(9,191)
Pension and healthcare plans (Note 25.3)	(990)	-	(990)
Materials and supplies	(107)	-	(107)
Third party services	(2,731)	-	(2,731)
Depreciation and amortization	(22)	(279)	(301)
Estimated losses, provisions and reversals (33.4)	-	22,456	22,456
Other operating income (expenses)	(7,544)	-	(7,544)
	(20,585)	22,177	1,592
Parent company	General and administrative expenses	Other operacional income (expenses), net	09.30.2016
Personnel and management (33.2)	(21,992)	-	(21,992)
Pension and healthcare plans (Note 25.3)	(4,170)	-	(4,170)
Materials and supplies	(473)	-	(473)
Third party services	(17,165)	-	(17,165)
Depreciation and amortization	(33)	(840)	(873)
Estimated losses, provisions and reversals (33.4)	-	176,407	176,407
Other operating income (expenses)	(29,865)	1,384	(28,481)
	(73,698)	176,951	103,253
Parent company	General and administrative expenses	Other operacional income (expenses), net	07.01.2016 to 09.30.2016
Personnel and management (33.2)	(6,056)	-	(6,056)
Pension and healthcare plans (Note 25.3)	1,235	-	1,235
Materials and supplies	(289)	-	(289)
Third party services	(9,220)	-	(9,220)
Depreciation and amortization	(17)	(279)	(296)
Estimated losses, provisions and reversals (33.4)	-	(2,740)	(2,740)
Other operating income (expenses)	(10,568)	945	(9,623)
	(24,915)	(2,074)	(26,989)

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33.1 Electricity purchased for resale

Consolidated	09.30.2017	09.30.2016
Purchase of Energy in the Regulated Environment - CCEAR	2,013,226	2,370,387
Electric Energy Trade Chamber - CCEE	1,228,351	347,122
Itaipu Binacional	839,743	838,673
Bilateral contracts	418,033	13,691
Program for incentive to alternative energy sources - Proinfa	163,257	182,374
Micro and mini generators and repurchase of customers	2,414	357
(-) PIS/Pasep/Cofins taxes on electricity purchased for resale	(291,850)	(325,227)
	4,373,174	3,427,377
Consolidated	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016
Purchase of Energy in the Regulated Environment - CCEAR	589,713	830,017
Itaipu Binacional	284,707	260,139
Electric Energy Trade Chamber - CCEE	745,951	126,169
Program for incentive to alternative energy sources - Proinfa	54,433	61,173
Bilateral contracts	398,312	5,261
Micro and mini generators and repurchase of customers	1,539	191
(-) PIS/Pasep/Cofins taxes on electricity purchased for resale	(116,460)	(109,217)
	1,958,195	1,173,733

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33.2 Personnel and management

.	Parent company			Consolidated
	09.30.2017	09.30.2016	09.30.2017	09.30.2016
Personnel
Wages and salaries	12,054	11,205	550,066	518,676
Social charges on payroll	4,289	4,023	197,601	185,930
Meal assistance and education allow ance	767	860	83,783	74,091
Provisons for profit sharing (a)	338	345	37,000	34,301
Compensation - Voluntary termination program/retirement	3,301	-	31,006	15,726
	20,749	16,433	899,456	828,724
Management
Wages and salaries	5,960	4,392	16,312	14,130
Social charges on payroll	1,535	1,123	3,968	3,488
Other expenses	70	44	258	171
	7,565	5,559	20,538	17,789
	28,314	21,992	919,994	846,513
(a) According to Federal Law No. 10,101/2000, State Decree No. 1,978/2007 and State Law No. 16,560/2010.

.	Parent company			Consolidated
	07.01.2017	07.01.2016	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016	to 09.30.2017	to 09.30.2016
Personnel
Wages and salaries	4,123	2,868	183,420	173,444
Social charges on payroll	1,455	1,021	65,062	61,876
Meal assistance and education allow ance	268	209	27,968	24,517
Provisons for profit sharing	29	88	(340)	11,518
Compensation - Voluntary termination Program/retirement	851	-	11,784	8,627
	6,726	4,186	287,894	279,982
Management
Wages and salaries	1,939	1,454	5,427	4,790
Social charges on payroll	507	372	1,347	1,158
Other expenses	19	44	86	80
	2,465	1,870	6,860	6,028
	9,191	6,056	294,754	286,010

33.3 Third-party services

Consolidated	09.30.2017	09.30.2016
Maintenance of electrical system	98,227	112,507
Maintenance of facilities	71,689	67,613
Communication, processing and transmission of data	66,142	41,716
Meter reading and bill delivery	37,434	39,237
Consumer service	21,884	15,791
Consulting and audit	17,871	30,116
Other services	72,245	95,577
	385,492	402,557
Consolidated	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016
Maintenance of electrical system	36,149	28,560
Maintenance of facilities	23,683	22,844
Communication, processing and transmission of data	24,905	13,464
Meter reading and bill delivery	12,212	14,580
Consulting and audit	6,263	16,561
Consumer service	8,956	5,302
Other services	22,738	34,889
	134,906	136,200

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33.4 Estimated losses, provisions and reversals

.	Parent company			Consolidated
	09.30.2017	09.30.2016	09.30.2017	09.30.2016
Provision (reversal) for litigations	(19,417)	(176,407)	115,832	23,113
Impairment of assets	-	-	(97,069)	14,462
Allow ance for doubtful accounts (Client and Other credits)	-	-	72,365	127,622
Tax credits estimated losses	-	-	6,170	(230)
Reversion in consortiums estimated losses	-	-	(111)	-
	(19,417)	(176,407)	97,187	164,967

.	Parent company			Consolidated
	07.01.2017 to 09.30.2017	07.01.2016 to 09.30.2016	07.01.2017 to 09.30.2017	07.01.2016 to 09.30.2016
Provision (reversal) for litigations	(22,456)	2,740	33,303	60,529
Impairment of assets	-	-	(158,080)	14,462
Allow ance for doubtful accounts (Client and Other credits)	-	-	21,876	33,736
Tax credits estimated losses	-	-	2,863	(576)
Reversion in consortiums estimated losses	-	-	-	-
	(22,456)	2,740	(100,038)	108,151

33.5 Construction cost

Consolidated
	09.30.2017	09.30.2016
Third party services	316,677	352,275
Materials and supplies	248,163	462,235
Personnel	107,749	93,164
Others	33,521	19,351
	706,110	927,025
Consolidated	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016
Third party services	83,860	149,891
Materials and supplies	66,236	182,707
Personnel	34,555	33,473
Others	4,360	7,450
	189,011	373,521

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33.6 Other operating costs and expenses, net

Consolidated
	09.30.2017	09.30.2016
Financial offset for the use of w ater resources	84,245	140,670
Taxes	69,538	23,132
Losses in the decommissioning and disposal of assets	36,754	25,443
Compensation	35,360	43,851
Leasing and rent (33.6.1)	27,149	27,261
Advertising and publicity	16,665	30,014
Other net costs and expenses	78,840	66,477
	348,551	356,848
	07.01.2017	07.01.2016
Consolidated	to 09.30.2017	to 09.30.2016
Financial offset for the use of w ater resources	29,428	46,470
Taxes	19,964	7,472
Losses in the decommissioning and disposal of assets	13,483	8,761
Compensation	12,257	21,945
Leasing and rent (33.6.1)	8,557	11,005
Advertising and publicity	6,447	10,957
Other net costs and expenses	72,259	3,976
	162,395	110,586

33.6.1Leases and rents

Consolidated
	09.30.2017	09.30.2016
Real estate	24,205	23,131
Others	4,037	5,173
(-) PIS and Cofins credits	(1,093)	(1,043)
	27,149	27,261
Consolidated	07.01.2017	07.01.2016
	to 09.30.2017	to 09.30.2016
Real estate	7,408	8,969
Others	1,457	2,496
(-) PIS and Cofins credits	(308)	(460)
	8,557	11,005

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34Financial Results

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35Operating Segments

Operating segments are business activities that generate revenues and incur expenses, whose operating results are regularly reviewed by the executive boards of the Parent Company and subsidiaries and by key strategic decision makers responsible for allocating funds and assessing performance.

35.1 Products and services from which we generate revenues from the reportable segments

The Company operates in reportable segments identified by management, through the chief officers of each business area, taking into consideration the regulatory environments, the strategic business units, and the different products and services. These segments are managed separately, since each business and each company requires different technologies and strategies.

In the first nine months of 2017, all sales have been to customers within Brazilian territory, as well as all non-current assets are located in national territory.

The Company and its subsidiaries did not identify any customer which individually accounts for more than 10% of total net revenues in the first nine months of 2017.

The Company evaluates the performance of each segment based on information derived from accounting records.

The accounting policies of the operating segments are the same as those described in Note 4 to the financial statements for the year ended December 31, 2016 and transactions between segments are recognized as transactions with third parties, i.e. at current market prices.

35.2 The Company’s reportable segments

The reportable segments of the Company, in accordance with CPC 22 / IFRS 8, are:

Power generation and transmission (GET) -this segment comprises the generation of electric energy from hydraulic, wind, and thermal projects (GER) and the transport and transformation of the power generated by the Company, and the construction, operation, and maintenance of all power transmission substations and lines (TRA). For managers, the assets and liabilities of the generation and transmission segments are shown on an aggregate basis while their result is shown separately;

Power distribution (DIS) -this segment comprises the distribution of electric energy, the operation and maintenance of the distribution infrastructure, and related services.

Telecommunications (TEL) -this segment comprises telecommunications and general communications services.

GAS -this segment comprises the public service of piped natural gas distribution.

Power sale (COM) – this segment comprises the sale of electric energy, and related services; and

Holding Company (HOL) -this segment comprises participation in other companies.

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35.3 Assets per reportable segment

35.4  �� Statement of income per reportable segment

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35.5 Additions to noncurrent assets by reportable segment

	Electric Energy		TEL	GAS	HOL	Consolidated
09.30.2017	GET	DIS
Property, plant and equipment
Additions	812,113	-	177,114	-	316	989,543
Intangible assets
Additions	2,850	524,841	1,409	10,607	616	540,323

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36Financial Instruments

36.1 Categories and determination of fair value of financial instruments

Determining fair values

a)Equivalent to their respective carrying values due to their nature and terms of realization.

b)Calculated according to information made available by the financial agents and to the market values of the bonds issued by the Brazilian government.

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c)Calculated based on the cost of the last issue by the Company, 126.0% of the CDI for discount of the expected payment flows.

d)The Company based its calculation on the comparison with a long-term and post-fixed National Treasury Bond (NTN-B) maturing on August 15, 2024, which yields approximately 4.47% p.y. plus the IPCA inflation index.

e)Criteria and assumptions disclosed on Note 4.4.9 to the financial statements for the year ended December 31, 2016, transmission concession.

f)Receivables related to the concession agreement for providing electricity generation services under quota arrangements at their fair value calculated by expected cash inflows discounted at the rate established in Aneel auction notice 12/2015 (9.04%), the best market benchmark in this case.

g)Criteria and assumptions disclosed on Note 4.4.9 to the financial statements for the year ended December 31, 2016, distribution concession. The changes in the first nine months of 2017 are shown in Note 10.1.

h)The fair values of generation assets approximate their book values, according to Note 4.4.10 to the financial statements for the year ended December 31, 2016.

i)Calculated according to the price quotations published in an active market, for assets classified as level 1, Assets classified as level 2 refer to Sanepar’s common shares that, due to the fact that these shares have low liquidity, the fair value was calculated using the quotation of the preferred shares with a deduction of 10%, considering that the dividends on the preferred shares are 10% higher than on common shares.

j)Calculated from the Unit Price quotation (PU) for September 29, 2017, obtained from the Brazilian Association of Financial and Capital Markets (Anbima), net of financial cost to amortize.

k)Real net discount rate of 8.11% p.a., in line with the Company’s estimated rate for long-term projects.

36.2 Financial risk management

The Company's business activities are exposed to the following risks arising from financial instruments:

36.2.1Credit risk

Credit risk is the risk of the Company and its subsidiaries incurring losses due to a customer or financial instrument counterparty, resulting from failure in complying with contract obligations.

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a)The Company's Management manages the credit risk of its assets in accordance with the Group's policy of investing virtually all of its funds in federal banking institutions. As a result of legal and/or regulatory requirements, in exceptional circumstances the Company may invest funds in prime private banks.

b)The risk arises from the possibility that the Company might incur in losses resulting from difficulties to receive its billings to customers. This risk is closely related to internal and external factors of Copel. To mitigate this type of risk the Company manages its accounts receivable, detecting customer groups that pose the greatest risk of default, cutting off energy supplies and implementing specific collection policies.

c)Management believes this credit risk is low because repayments are secured by funds from dividends.

d)Management believes this risk is very low because these contracts assure an unconditional right to be paid in cash by the concession Granting Authority at the end of the concession period for any infrastructure investments not recovered through tariffs by the end of the period, specifically for the transmission business, since RAP is guaranteed revenue that does not involve demand risk.

For investments made in infrastructure and that were not recovered through tariff until the end of the concession, the agreements assure the right to receive cash until the end of the concession to be paid by the Granting Authority.

For the amount relating to RBSE assets existing on May 31, 2000, Aneel published Normative Resolution 589/2013, which defines criteria for calculating the New Replacement Value (VNR). Given that on April 20, 2016, through MME Ordinance 120, the Granting Authority defined the means and period for receiving this asset regulated by. Aneel Normative Resolution 762/2017, Management considers the risk of this credit to be low, even considering the injunctions that temporarily reduced the RAP receivable, regarding the cost of equity determined in RSBE’s assets from January 2013 to June 2017, as described in Note 10.4.

e)Management considers the risk of this credit to be very low, as the contract for the sale of energy by quotas guarantees the receipt of an Annual Generation Revenue - RAG guaranteed which includes the annual amortization of this amount during the concession term.

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f)For the generation concession assets, Aneel published Normative Resolution 596/2013, which defines criteria for calculating the New Replacement Value (VNR), for indemnity purposes. Although the Granting Authority has not yet disclosed the means of remunerating these assets and there are uncertainties as to approval or ratification of investments made in this respect, Management believes that compensation for these assets indicates the recoverability of the recorded balance.

g)Management believes this credit risk is very low because these are specific programs together with the State Government to highlight the Luz Fraterna program (Note 37.a).

h)The risk arises from the possibility that the Company might incur losses resulting from the volatility on the stock market. This type of risk involves external factors and has been managed through periodic assessment of the variations occurred in the market.

36.2.2Liquidity risk

The Company's liquidity risk consists of the possibility of insufficient funds, cash or other financial asset to settle obligations on scheduled dates.

The Company manages liquidity risk relying on a set of methodologies, procedures and instruments applied for a permanent control over financial processes to ensure a proper management of risks.

Investments are financed by incurring medium and long-term debt with financial institutions and capital markets.

Short-, medium- and long-term business projections are made and submitted to management bodies for evaluation. The budget for the next fiscal year is annually approved.

Medium and long-term business projections cover monthly periods over the next five years. Short-term projections consider daily periods covering only the next 90 days.

The Company permanently monitors the volume of funds to be settled by controlling cash flows to reduce funding costs, the risk involved in the renewal of loan agreements and compliance with the financial investment policy, while at the same time keeping minimum cash levels.

The following table shows the expected undiscounted settlement amounts in each time range. Projections were based on financial indicators linked to the related financial instruments and forecast according to average market expectations as disclosed on the Central Bank of Brazil's Focus Report, which provides the average expectations of market analysts for these indicators for the current year and the following year. From 2021, 2020 indicators are repeated through the forecast period.

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Consolidated	Interest (a)	Less than 1 month	1 to 3 months	3 months to 1 year	1 to 5 years	Over 5 years	Total liabilities
09.30.2017
Loans and financing	Note 23	32,399	713,244	857,663	2,507,719	859,058	4,970,083
Debentures	Note 24	611,579	53,391	1,491,989	3,464,085	511,908	6,132,952
Payable related to concession	Rate of return +
use of public property	IGP-M and IPCA	5,422	10,846	48,967	290,152	1,510,738	1,866,125
Eletrobras - Itaipu	Dollar	-	178,575	873,736	4,875,819	1,556,978	7,485,108
Other suppliers	-	1,844,701	125,942	195,207	45,853	37	2,211,740
Purchase obligations	IGP-M and IPCA	-	2,559,451	3,889,519	21,074,623	149,254,387	176,777,980
Ordinary financing of taxes
w ith the federal tax authorities	Selic	5,462	11,000	50,677	107,093	-	174,232
Pert	Selic	34,155	68,920	34,554	212,390	512,306	862,325
Sectorial financial liabilities	Selic	24,575	49,587	230,194	99,025	-	403,381
		2,558,293	3,770,956	7,672,506	32,676,759	154,205,412	200,883,926
12.31.2016
Loans and financing	Note 23	90,265	164,214	1,588,764	1,873,952	1,556,703	5,273,898
Debentures	Note 24	8,725	19,929	1,545,694	4,147,064	583,869	6,305,281
Payable related to concession	Rate of return +
use of public property	IGP-M and IPCA	5,494	10,988	50,331	300,343	1,850,518	2,217,674
Eletrobras - Itaipu	Dollar	-	193,346	893,025	5,104,889	2,698,195	8,889,455
Other suppliers	-	1,106,430	21,619	124,060	40,239	2	1,292,350
Purchase obligations	IGP-M and IPCA	-	1,497,009	3,129,899	17,686,276	94,007,720	116,320,904
Ordinary financing of taxes
w ith the federal tax authorities	Selic	5,133	10,392	48,578	161,534	-	225,637
Sectorial financial liabilities	Selic	13,071	26,537	125,315	144,590	-	309,513
		1,229,118	1,944,034	7,505,666	29,458,887	100,697,007	140,834,712
(a) Effective interest rate - w eighted average.

At September 30, 2017, Copel recorded a negative net working capital of R$132,532 and R$1,651,271in the Consolidated. The Company's Management has been monitoring thee liquidity and taking actions to balance the short-term financial capacity, preserving the Company's investment programs, as well as seeking debt extension, as described in Note 36.3.

As disclosed in Notes 23.5 and 24.3, the Company and its subsidiaries have loans and financing agreements and debentures with covenants that if breached may have their payment accelerated.

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36.2.3Market risk

Market risk it is the risk that fair value or the future cash flows of a financial instrument shall oscillate due to changes in market prices, such as currency rates, interest rates and stock price. The purpose of managing this risk is to control exposures within acceptable limits, while optimizing return.

a)Foreign currency risk (US Dollar)

This risk comprises the possibility of losses due to fluctuations in exchange rates, which may reduce assets or increase liabilities denominated in foreign currencies.

The Company’s foreign currency indebtedness is not significant and it is not exposed to foreign exchange derivatives. The Company monitors all relevant exchange rates.

The effect of the exchange rate variation resulting from the power purchase agreement with Eletrobras (Itaipu) is passed on to customers in Copel DIS's next tariff adjustment.

The exchange rate risk posed by the purchase of gas arises from the possibility of Compagas reporting losses on the fluctuations in exchange rates, increasing the amount in Reais of the accounts payable related to the gas acquired from Petrobras. This risk is mitigated by the monitoring and transfer of the price fluctuation through tariff, when possible. Compagas monitors these fluctuations on an ongoing basis.

Sensitivity analysis of foreign currency risk

The Company has developed a sensitivity analysis in order to measure the impact of the devaluation of the U.S. dollar on its loans and financing subject to exchange risk.

The baseline takes into account the existing balances in each account as of September 30, 2017 and the probable scenario assumes a variation in the exchange rate - end of period (R$/US$3.16) based on the median market expectation for 2017 reported in the Central Bank’s Focus report of October 20, 2017. For the adverse and remote scenarios, deteriorations of 25% and 50%, respectively, were considered for the main risk factor for the financial instrument compared to the rate used in the probable scenario.

. Foreign exchange risk	Risk	Baseline 09.30.2017	Projected scenarios - Dec.2017
			Probable	Adverse	Remote
Financial assets
Collaterals and escrow accounts - STN	USD depreciation	72,765	(184)	(18,329)	(36,475)
.		72,765	(184)	(18,329)	(36,475)
Financial liabilities
Loans and financing - STN	USD appreciation	(86,590)	219	(21,374)	(42,967)
Suppliers
Eletrobras (Itaipu)	USD appreciation	(221,419)	559	(54,656)	(109,871)
Petrobras (acquisition of gas by Compagás)	USD appreciation	(200,448)	506	(49,479)	(99,465)
		(508,457)	1,284	(125,509)	(252,303)

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In addition to the sensitivity analysis required by CVM Resolution No. 475/2008, the Company evaluates its financial instruments considering the possible effects on profit and loss and equity of the risks evaluated by Company management on the reporting date for the financial instruments, as recommended by CPC 40 (R1) Financial Instruments. Disclosure. Based on the equity position and the notional value of the financial instruments held as of September 30, 2017, it is estimated that these effects would approximate the amounts stated in the above table in the column for the forecast probable scenario, since the assumptions used by the Company are similar to those previously described.

b)Interest rate and monetary variation risk

This risk comprises the possibility of losses due to fluctuations in interest rates or other indicators, which may reduce financial income or financial expenses or increase the financial expenses related to the assets and liabilities raised in the market.

The Company has not engaged in transactions with derivatives to cover this risk, but it has continually monitored interest rates and market indicators, in order to assess the potential need for such transactions.

Sensitivity analysis of interest rate and monetary variation risk

The Company has developed a sensitivity analysis in order to measure the impact of variable interest rates and monetary variations on its financial assets and liabilities subject to these risks.

The baseline scenario takes into account the existing balances in each account as of September 30, 2017 while the ‘probable’ scenario assumes balances reflecting varying indicators as follows: CDI/Selic - 7.00%, IPCA - 3.06%, IGP DI - (0.97)%, IGP-M - (0.87)% and TJLP – 7.00%, estimated as market average projections for 2017 according to the Focus Report issued by the Central Bank of Brazil as of October 20, 2017, except TJLP that considers the rate set by the National Monetary Council for the fourth quarter of 2017.

For the adverse and remote scenarios, deteriorations of 25% and 50%, respectively, were considered for the main risk factor for the financial instrument compared to the rate used in the probable scenario.

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In addition to the sensitivity analysis required by CVM Resolution No. 475/2008, the Company evaluates its financial instruments considering the possible effects on profit and loss and equity of the risks evaluated by Company management on the reporting date for the financial instruments, as recommended by CPC 40 (1). Based on the equity position and the notional value of the financial instruments held as of September 30, 2017, it is estimated that these effects will approximate the amounts stated in the above table in the column for the forecast probable scenario, since the assumptions used by the Company are similar to those previously described.

36.2.4Electricity shortage risk

Approximately 64% of installed capacity in the country currently comes from hydroelectric generation, which makes Brazil and the geographic region in which we operate subject to hydrological conditions that are unpredictable, due to non-cyclical deviations of mean precipitation. Unsatisfactory hydrological conditions may cause, among other things, the implementation of comprehensive programs of electricity savings, such as rationalization or even a mandatory reduction of consumption, which is the case of rationing.

From 2014, the reservoirs of the Southeast/Midwest, North and Northeast regions have been subject to adverse climate situations, leading agencies responsible for this industry to adopt water resources optimization measures to guarantee full compliance with load.

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The economic crisis that the country is going through has had a significant impact on the consumption of electricity, practically stagnating its growth in the last 3 years, being decisive to avoid a greater difficulty in the full service of the market.

Regarding short-term risk, the Electric Power Industry Monitoring Committee - CMSE has been reporting a balance between energy supply and demand, and indices have been kept within safety margins. The same position is adopted by ONS regarding the risk of deficit in the medium term, as stated in the 2016-2020 Energy Operation Plan.

Although dam storage levels are not ideal, from the standpoint of regulatory agencies, when combined with other variables they are sufficient to keep the risk of deficit within the safety margin established by the National Energy Policy Council - CNPE (maximum risk of 5%) in all subsystems.

36.2.5Risk of GSF impacts

The Energy Reallocation Mechanism (MRE) is a system of redistribution of electric power generated, characteristic of the Brazilian electric sector, which has its existence by the understanding, at the time, of the need for a centralized operation associated with a centrally calculated optimum price known as PLD. Since generators have no control over their production, each plant receives a certain amount of virtual energy which can be compromised through contracts. This value, which enables the registration of bilateral contracts, is known as Physical Guarantee - GF and, like the PLD, is also calculated centrally.  PLD is calculated on a weekly basis. However, the GT, as required by Law, is recalculated every five years, with a limit, of increase or decrease, restricted to 5% by revision or 10% in the concession period.

The contracts need to be backed. This is done, basically, through the allocation of power generated received from the MRE or purchase. The GSF is the ratio of the entire hydroelectric generation of the MRE participants to the GF sum of all the MRE plants. Basically, the GSF is used to calculate how much each plant will receive from generation to back up its GF. Thus, knowing the GSF of a given month the company will be able to know if it will need to back up its contracts through purchases.

Whenever GF multiplied by GF is less than the sum of contracts, the company will need to buy the difference in the spot market. However, whenever GSF multiplied by GF is greater than the total contracts, the company will receive the difference to the PLD.

The low inflows recorded since 2014 as well as problems with delays in the expansion of the transmission system have resulted in low GSF values, resulting in heavy losses for the companies holding MRE participating hydroelectric projects.

For plants with contracts in the Free Contracting Environment - ACL, the main way to manage the low GSF risk is not to compromise the entire GF with contracts, approach currently adopted by Copel.

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For the contracts in the ACR, Law 13,203/2015, allowed the generators to contract insurance against the load, by means of payment of a Risk Premium. Copel adopted this approach to protect contracts related to energy produced by Mauá, Foz do Areia, Santa Clara, Fundão, Colider, Baixo Iguaçu and Cavernoso II Thermoelectric Plants.

For the distribution segment, the effects of the GSF are perceived in the costs of the contracts for availability, as well as in the costs associated with quotas of Itaipu, Angra and the plants whose concessions were renewed in accordance with Law 12,783/2013. This is a financial risk, however, since it guarantees the neutrality of energy purchase expenses through a tariff transfer.

36.2.6Risk of non-renewal of concessions - generation and transmission

Currently, the extension of generation, transmission and distribution concessions covered by Articles 17, 19 and 22 of Law No. 9,074/1995 is governed by Law 12,783/2013. However, extension is permitted after express acceptance of conditions of that Law, such as: i) distribution and transmission revenue determined according to criteria established by Aneel; ii) submission to service quality standards defined by Aneel; (iii) change from price remuneration to tariff calculated by Aneel for each plant; and (v) allocation of plant energy and capacity physical guarantee shares to concessionaires and permittees of distribution public utilities.

Concessions of hydroelectric power generation, electric power transmission and distribution may be extended at the discretion of the Concession Grantor, one single time, for a period of up to 30 years. However, for concessions of thermoelectric power generation, extension period is limited to 20 years. The Ministry of Mines and Energy, together with the Ministry of Planning, Development and Management, submitted to the Civil House of the Presidency of the Republic a draft decree, not yet promulgated, to regulate art. 5 of Law 12,783/2013, which deals with the extension of thermoelectric energy generation concessions.

Current regulation also defined that the concessionaire has a period to request extension of concession of up to 60 months before final contract date or after granting of concessions to hydroelectric power generation and electric power transmission and distribution plants, and of up to 24 months for thermoelectric plants.

It is also defined that, if the concessionaire opts to extend its concession, the Concession Grantor may advance effects of extension by up to 60 months counted as of contract or grant date, and may also define initial tariff or revenue.

On March 24, 2017 Copel GeT filed with Aneel its intention to extend the granting of the Figueira Hydroelectric Plant generation concession, emphasizing, however, that it will sign the necessary contracts and / or amendments only after knowing and accepting the contractual terms and the rules that will govern any process related to the extension of the grant. For the other plants of Copel GeT with concessions ending within a term of ten years, the deadlines for the Company to inform about the extension or not of the generation concessions are shown below:

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Plant	Deadline for manifestation
HPP Gov. Bento Munhoz da Rocha Neto (Foz do Areia)	09.17.2018
HPP Apucaraninha	10.12.2020
HPP Chaminé	08.16.2021
HPP Guaricana	08.16.2021

These five plants represent a Physical Guarantee of an average 620.69 MW.

The Company will make analyses in the future to decide on whether or not concessions should be extended in view of conditions imposed by the Concession Grantor, aiming at preserving its profitability levels.

In case extension is not brought forward, the Concession Grantor will open a tender bid process for concessions of the auction or competition type, for up to 30 years, considering, for tender bid judgment, the lowest tariff value and the highest offer to pay grant bonus.

Copel GeT does not have any transmission concession ending in the next ten years.

36.2.7Risk of non-renewal of concessions - distribution

Recently, pursuant to the terms of Concession Agreement amendment No. 46/1999 of Copel DIS, concession was extended, provided that quality and efficiency parameters for provision of distribution services are met, measured by indicators that consider duration and frequency of service interruptions (DECi and FECi) and efficiency in the Company’s economic and financial management.

The Fifth Amendment to the Concession Agreement imposes indexes of economic and financial efficiency and quality. Failure to comply with the indexes for two consecutive years or any limits at the end of the period of the first five years will result in the termination of the concession (clause 18, subclause 1). From the sixth year following the signing of the agreement, the breach of quality criteria for three consecutive years or of economic and financial management criteria for two consecutive years will result in the opening of an expiration process (clause 12, subclause 14). In addition, non-compliance with the electricity supply quality indicators (DEC and FEC) for two consecutive years or three times in five years, depending on Aneel’s regulation, may limit dividends or interest on equity (clause 2, subclause 8) payments to shareholders, while the breach of the economic and financial sustainability indicators may require a capital contribution from the controlling shareholders (clause 13, subclause 4).

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The following table sets out the targets set for Copel DIS in the first five years of the renewal:

		Quality (Limit Established) (a)		Quality (Performed)
Year	Economic and Financial Management	DECi (b)	FECi (b)	DECi (b)	FECi (b)
2016		13.61	9.24	10.80	7.14
2017	EBITDA=0	12.54	8.74	-	-
2018	EBITDA (-) QRR=0 (c)	11.23	8.24	-	-
2019	{Net Debt / [EBITDA (-) QRR]}=1 / (0.8 * SELIC) (c) (d)	10.12	7.74	-	-
2020	{Net Debt / [EBITDA (-) QRR]}=1 / (1.11 * SELIC) (c) (d)	9.83	7.24	-	-

(a) According to Aneel’s Technical Note No. 0335/2015.

(b) DECi - Equivalent Time of Interruption Caused by Internal Source per Consumer Unit; and FECi - Equivalent Frequency of Interruption Caused by Internal Source per Consumer Unit.

(c) QRR: Regulatory Reintegration Quota or Regulatory Depreciation Expense. This is the value defined in the most recent Periodical Tariff Review (RTP), plus the General Market Price Index (IGP-M) betw een the month preceding the RTP and the month preceding the tw elve-month period of the economic and financial sustainability measurement.

(d) Selic: limited to 12.87% p.y.

36.2.8Risk of overcontracting and undercontracting of electricity

The agreement for purchase of electric power by distributors is regulated by Law No. 10,484/2014 and Decree No. 5,163/2004, which determine that distributors must purchase the volume required to serve 100% of their market through auctions on the Regulated Contacting Environment – ACR.

The contracting of the total output available in the market is verified by observing the period comprising the calendar year, and the difference between the costs remunerated by the tariff and those actually incurred on the power purchase are fully passed on to captive consumers as long as: (i) presents a contracting level between 100% and 105% of its market; (ii) presents a level lower than 100% - being, therefore, exposed to the risk of power purchase subject to the allowance for doubtful accounts, if the condition of involuntary undercontracting is recognized; and (iii) the distributor presents a level higher than 105% - being, therefore, exposed to the risk of power sale subject to the allowance for doubtful accounts, if the condition of involuntary overcontracting is recognized.

That is, even if distributors determine contracting levels lower or higher than the regulatory limits, there is the assurance of neutrality if it is identified that such violation derives from extraordinary and unforeseen events that are not manageable.

On the other hand, if the violation of the contracting limits derives from voluntary actions, these will be subject to the risk of spot market exposure, which can be advantageous or disadvantageous according to the amount of the difference settlement price (PLD).

Until July 2017, the contracting balance projection indicated the occurrence of overcontracting. However, when succeeding in the temporary reduction of the contracted amounts between July and December 2017, through the New Energy and Decrease Clearing Facility (“Mecanismo de Compensação de Sobras e Déficits - MCSD de Energia Nova”), the projection is that Copel Distribution  will reach a contracting level within the regulatory limits, thus eliminating the risk for 2017.

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36.2.9Gas shortage risk

This risk involves potential periods of shortage of natural gas supply to meet the Company’s gas distribution and thermal generation business requirements.

Long periods of gas shortage could result in losses due to lower revenues by subsidiaries Compagas and UEG Araucária.

The natural gas supply contract between Brazil and Bolivia is effective for twenty years, ending in 2019. In the event of non-renewal of this contract, currently centralized at Petrobras, the direct consumers or state distributors shall negotiate directly with Transportadora Brasileira Gasoduto Bolívia-Brasil (TBG).

On the other hand, the volume of natural gas produced in the pre-salt has increased. The Brazilian’s current net output is 67 million m³/day and with growing trend.

In addition to the gas from Bolivia and from the pre-salt, there is the alternative of importing the Liquified Natural Gas (LNG).  Currently Petrobras has tree regasification stations with total capacity of 41 million m³/day.

There are still projects of new regasification stations in all Brazilian regions, and the stations located in the South have capacity to meet the consumption of this region of the country.

In the international market, the natural gas price has remained stable, indicating a balance between supply and demand.

In this scenario, the natural gas shortage risk can be considered low.

36.3 Capital management

The Company seeks to maintain a strong capital base to maintain the trust of investors, creditors and market and ensure the future development of the business. Management strives to maintain a balance between the highest possible returns with more adequate levels of loans and the advantages and the assurance afforded by a healthy capital position. Thus, it maximizes the return for all interested parties in its operations, optimizing the balance of debts and equity.

For this, we have the example of utilization of third-party capital in the Company's activities and, at the same time, search for the extension of the debt profile and improvement of the Net Working Capital - CCL, in the two funding operations carried out recently, described in Note 40.3.

The Company monitors capital by using an index represented by adjusted consolidated net debt divided by adjusted consolidated EBITDA (Earnings before interest, taxes, depreciation and amortization), for the last twelve months. Corporate goal established in strategic planning provides for maintenance of index below 3.5 while any expectation of failing to meet this target will prompt Management to take steps to correct its course by the end of each reporting period.

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36.3.1The equity indebtedness is shown below:

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37Related Party Transactions

Consolidated		Assets		Liabilities		Revenue	Cost / Expense
Related parties / Nature of operation	09.30.2017	12.31.2016	09.30.2017	12.31.2016	09.30.2017	09.30.2016	09.30.2017	09.30.2016
Controlling shareholder
State of Paraná -dividends payable	-	-	141,141	83,786	-	-	-	-
CRC Transfer (Note 8)	1,491,773	1,522,735	-	-	41,966	142,801	-	-
"Luz Fraterna" Program (a)	168,550	167,674	-	-	-	-	-	-
2014 World Cup construction w ork (Note 15.1.2)	14,266	14,266	-	-	-	-	-	-
Morar Bem Paraná Program (Note 15.1.3)	12,492	24,985	-	-	-	-	-	-
Remuneration and employ social security charges assigned (b)	46	302	-	-	-	-	-	-
Telecommunication services (c)	26,378	48,794	-	-	30,363	22,052	-	-
Sistema Meteorológico do Paraná - Simepar (d)	-	-	326	164	-	-	(1,419)	(1,323)
Entities with significant influence
BNDES and BNDESPAR -dividends payable (e)	-	-	53,289	57,218	-	-	-	-
Financing (Note 23)	-	-	1,604,789	1,692,775	-	-	(106,425)	(117,943)
Debentures - Compagás (Note 24)	-	-	48,864	61,786	-	-	(4,190)	(2,883)
Debentures - w ind farms (f)	-	-	284,562	295,188	-	-	(22,747)	(6,449)
State of Paraná investee
Sanepar(c) (g)	25	32	2	-	2,728	2,335	(1,291)	(1,076)
Dividends	12,095	16,817	-	-	-	-	-	-
Joint ventures
Dominó Holdings- dividends	-	5,123	-	-	-	-	-	-
Voltalia São Miguel do Gostoso- mutual (Note 15.4)	37,268	28,968	-	-	2,778	2,606	-	-
Dividends	1,032	1,032	-	-	-	-	-	-
Costa Oeste Transmissora de Energia(h) (i) (j)	151	72	60	73	677	634	(1,753)	(2,475)
Dividends	-	1,751	-	-	-	-	-	-
Marumbi Transmissora de Energia(h) (j)	591	285	39	55	2,559	3,107	(663)	(662)
Dividends	-	3,845	-	-	-	-	-	-
Caiuá Transmissora de Energia(h) (i) (j)	320	308	272	356	2,830	1,450	(11,892)	(11,398)
Dividends	1,991	1,991	-	-	-	-	-	-
Integração Maranhense Transmissora(h) (j)	-	-	43	76	-	-	(1,276)	(1,383)
Dividends	4,012	4,012	-	-	-	-	-	-
Matrinchã Transmissora de Energia(h) (j)	-	-	219	326	-	-	(5,739)	(2,422)
Dividends	23,213	23,213	-	-	-	-	-	-
Transmissora Sul Brasileira(h) (j)	-	-	75	149	-	-	(2,270)	(2,386)
Guaraciaba Transmissora de Energia(h) (j)	-	-	91	173	-	-	(2,836)	-
Dividends	5,512	5,512	-	-	-	-	-	-
Paranaíba Transmissora de Energia(j)	-	-	161	-	-	-	(1,323)	(283)
Dividends	3,051	3,051	-	-	-	-	-	-
Cantareira Transmissora de Energia -dividends	1,224	1,224	-	-	-	-	-	-
Associates
Dona Francisca Energética S.A.(k)	-	-	1,389	1,436	-	-	(12,773)	(12,691)
Foz do Chopim Energética Ltda.(c) (h)	326	161	-	-	1,642	1,401	-	-
Sercomtel S.A. Telecomunicações(c) (l)	3,936	3,430	-	-	6,255	6,512	-	-
Key management staff
Fees and social security charges (Note 33.2)	-	-	-	-	-	-	(20,538)	(17,789)
Pension and healthcare plans (Note 25)	-	-	-	-	-	-	(1,138)	(944)
Other related parties
Fundação Copel(c)	52	52	-	-	239	222	-	-
Administrative property rental	-	-	349	340	-	-	(13,675)	(11,423)
Pension and healthcare plans (Note 25)	-	-	806,189	769,865	-	-	-	-
Lactec (m)	-	-	1,390	1,743	-	-	(12,346)	(10,078)

a)The Luz Fraterna Program, created under Law No. 491/ 2013 and No. 17,639/2013, allows the State Government to pay for the electricity bills of low income families in Paraná – which have duly applied for the program – provided their consumption does not exceed 120 kWh a month. This benefit is available to residential customers with single-phase connections, rural customers with single-phase connections or two-phase connections with circuit breakers of up to 50 amperes. Applicants must not have more than one electricity bill under their names and must not have any pending debts to the Company.

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In the balance at September 30, 2017, the amount of R$115,890 is recognized in the Parent Company, in line item Related Parties, as described in Note 15.1.1. The remaining balance has been paid on a monthly basis since August 2016.

b)Reimbursement of wages and social charges for employees transferred to the Paraná State Government. The balances shown are net of allowance for loan losses in the amount of R$1,376 as of September 30, 2017 (R$1,749 as of December 31, 2016).

c)Revenue from telecommunications services provided by Copel TEL.

d)The Meteorological System of Paraná - Simepar is a supplementary unit of the Independent Social Service Paraná Technology, linked to the State Department of Science, Technology and Higher Education. Simepar has contracts with Copel DIS, effective until November 6, 2017, for services of weather forecast, meteorological reports, ampacity analysis, mapping and analyses of winds and atmospheric discharges.

e)BNDES is the parent company of BNDES Participações S.A. - BNDESPAR, which has significant influence over Copel (Note 31.1).

f)BNDES and BNDESPAR acquired all the debentures issued by the subsidiaries Nova Asa Branca I, Nova Asa Branca II, Nova Asa Branca III, Nova Eurus IV and Ventos de Santo Uriel (Note 24).

g)Basic sanitation provided by Sanepar.

h)Charges for the use of the Transmission System and revenue from operating and maintenance contracts and rendering of engineering services with Copel GeT.

i)Copel DIS has transmission system connection contracts (CCT) with two companies - Costa Oeste Transmissora de Energia and Caiuá Transmissora de Energia – expiring upon the termination of the distribution or transmission concession, whichever occurs first.

j)Copel DIS maintains a Contract for the Use of Transmission System (Cust) with ONS and power transmission concessionaires whose object is the contracting of Transmission System Use Amount (Must). Contracting is permanent and is regulated by Aneel Normative Resolution No. 666/2015. Amounts are defined for four subsequent years, with annual reviews.

k)Power purchase and sale agreement signed by Dona Francisca Energética and Copel GeT, expiring on March 31, 2025.

l)Light pole sharing agreement, signed between Sercomtel S.A. Telecomunicações and Copel DIS, expiring on December 28, 2018.

m)The Institute of Technology for Development (Lactec) is a Public Interest Civil Society Organization (OSCIP), in which Copel is an associated. Lactec has service and R&D contracts with Copel GeT and Copel DIS, which are subject to prior or later control and approval by Aneel. The asset balances refer to Energy Efficiency and R&D programs, recorded under current assets, in service in progress, until the respective projects are concluded, pursuant to Aneel.

The values resulting from operating activities of Copel DIS with related parties are billed at the rates approved by Aneel.

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37.1 Guarantees and endorsements awarded to related parties

Sureties and guarantees granted by Copel to its subsidiaries for financing and debentures are informed in Notes 23 and 24.

Copel provided financial guarantees, in the form of corporate bond, for power purchase agreements made by Copel GeT in May 2015, in the total amount of R$3,052, and made by Copel Energia in November 2016 and August 2017, in the total amount of R$49,529.

Sureties and guarantees granted by Copel and Copel GeT for financing, debentures and insurance contracts of joint ventures are shown below:

	Company	Operation	Date issued	Final maturity	Amount approved	Balance 09.30.2017	Interest%	Amount endorsement/  security
(1)	Caiuá Transmissora	Financing	12.23.2013	02.15.2029	84,600	73,149	49.0	35,843
(2)	Guaraciaba Transmissora	Debentures	09.28.2016	01.15.2031	440,000	390,068	49.0	191,133
(3)	Integração Maranhense	Financing	12.30.2013	02.15.2029	142,150	119,993	49.0	58,797
(4)	Mata de Santa Genebra	Debentures	09.12.2014	06.30.2017	469,000	544,447	50.1	272,768
(5)	Matrinchã Transmissora	Financing	12.27.2013	05.15.2029	691,440	579,665	49.0	284,036
(6)	Matrinchã Transmissora	Debentures	05.15.2016	06.15.2029	180,000	199,470	49.0	97,740
(7)	Transmissora Sul Brasileira	Financing	12.12.2013	07.15.2028	266,572	212,936	20.0	42,587
(8)	Transmissora Sul Brasileira	Debentures	09.15.2014	09.15.2028	77,550	107,775	20.0	21,555
(9)	Paranaíba Transmissora	Financing	10.21.2015	10.15.2030	606,241	587,450	24.5	143,925
(10)	Paranaíba Transmissora	Debentures	01.15.2017	03.15.2028	120,000	106,291	24.5	26,041
(11)	Voltalia São Miguel do Gostoso Part. S.A. (a) Debentures		01.15.2016	12.15.2028	57,000	54,222	49.0	26,569
(12)	Usina de Energia Eólica Carnaúba S.A. (a)	Financing	08.24.2015	11.15.2031	74,000	54,753	49.0	26,829
(13)	Usina de Energia Eólica Reduto S.A. (a)	Financing	08.24.2015	11.15.2031	70,000	54,748	49.0	26,827
(14)	Usina de Energia Eólica Santo Cristo S.A. (a) Financing		08.24.2015	11.15.2031	74,000	51,469	49.0	25,220
(15)	Usina de Energia Eólica São João S.A. (a)	Financing	08.24.2015	11.15.2031	68,000	52,181	49.0	25,569
(16)	Cantareira Transmissora de Energia	Financing	12.28.2016	09.15.2032	426,834	424,695	49.0	208,101
								1,513,540
(a) Subsidiaries of Voltália São Miguel do Gostoso I Participações S.A.

Financial institution (fund provider):

BNDES: (1) (2) (3) (5) (7) (9) (12) (13) (14) (15) (16)

Allocation:

Investment Program and/or Working capital.

Endorsement/Security:

Provided by Copel Geração e Transmissão: (1) (3);

Provided by Copel: (2) (4) (5) (6) (7) (8) (9) (10) (11) (12) (13) (14) (15) (16)

Securities offered for the transaction:

Pledge of shares of Copel Geração e Transmissão proportional to the interest in projects.

Performance bond Company	Final maturity	Amount Insured	% endorsement Copel GeT	Amount endorsement
Matrinchã Transmissora	12.31.2017	90,000	49.0	44,100
Guaraciaba Transmissora	12.31.2017	47,000	49.0	23,030
Paranaíba Transmissora	07.26.2018	48,000	24.5	11,760
Mata de Santa Genebra	05.26.2018	78,300	50.1	39,228
Cantareira Transmissora	11.30.2018	31,200	49.0	15,288
				133,406

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38Insurance

Details by risk type and effectiveness date of the main policies can be seen below.

Consolidado Apólice	Término da vigência	Importância segurada
Nominated Risks	08.24.2018	2,172,441
Operational risks - HPP Mauá - Consórcio Energético Cruzeiro do Sul	11.23.2017	799,290
Operational risks - UEG Araucária (a)	05.31.2018	694,590
Operational risks - Brisa Potiguar	12.29.2017	674,673
Fire - Company - ow ned and rented facilities	08.24.2018	597,716
Operational risks - São Bento	12.29.2017	449,928
Legal guarantee - Office of the General Counsel to the National Treasury	05.11.2018	291,396
Multi-risk - Elejor	03.11.2018	197,800
D&O Insurance (a)	03.28.2018	79,200
Aviation insurance (hull and civil liability) (a)	01.30.2018	77,500
(a) The values of the insured of operating risks - UEG Araucária and Seguro Aeronáutico have been translated from USD into BRL,
into BRL, w ith the current rate R$3.1680, as of 09.30.2017.

In addition to the related insurance, the Company and its subsidiaries contract other insurance policies with lower values, such as: general civil liability, payment guarantee, several risks, national and international transportation and life insurance.

The guarantee insurance contracted by the subsidiaries and joint ventures have Copel as a guarantor, within the limits of their participation in each project.

39Additional Information to the Statement of Cash Flows

39.1 Non-cash transactions

As presented in Note 19.2, the additions to property, plant and equipment reached R$888,487. Of this amount, R$170,008 represent the portion of instalment purchases not settled through the end of the period. These transactions did not involve cash and, for this reason, they are not presented in the statement of cash flows.

In turn, as mentioned in Note 18.4, the common shares of Sanepar, held by Copel Energia, assessed at R$73,361, were transferred from the line item of investments - joint ventures to the line item of other temporary investments. As this transaction did not involve cash, this amount equally is not included in the statement of cash flows.

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40Subsequent Events

40.1  Loans and financing

The main loans and financing raised and paid are shown below:

40.2  Debentures

The main issues and repayments of debentures are presented below:

40.3  Law No. 13,496, from October 25, 2017

On August 28, 2017, Copel DIS joined the Pert in accordance with the prevailing rules provided in Provisional Measure No. 783 of May 31, 2017 and Normative Instruction No. 1,711 of June 16, 2017.

On October 25, 2017, with the conversion of MP No. 783/2017 into Law No. 13,496, the percentage of reduction in fine was changed from 40% to 50%. When applying the effects of law, Copel DIS was entitled to a reduction of R$8,918 in the amount of its consolidated debt, which was recorded in October 2017.

40.4  Joining the Sanepar’s Units Program and public offering of Units

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On November 17, 2017, Copel requested the conversion of shares and for joining Sanepar’s Units Program, which occurred on November 21, 2017. The Units are assets comprised of more than one class of securities and the units held by Copel and Copel Energia one common share and four preferred shares issued by Sanepar.

Copel, holder of 36,343,267 preferred shares issued by Sanepar, requested the conversion of 7,268,655 into common shares and the formation of 7,268,653 Units. Copel Energia, holder of 7,956,306 common shares issued by Sanepar, requested the conversion of 6,365,044 into preferred shares and the formation of 1,591,261 Units.

On December 12, 2017, the bookbuilding of the secondary public offering with restricted placement efforts of Units issued by Sanepar was concluded, setting the price to R$55.20 per Unit. Copel and Copel Energia participated as sellers and sold all their Units, consequently receiving cash proceeds of R$484,608.

40.5     Operation of ventures

40.5.1Cantareira Transmissora de Energia - start of operations

On February 3, 2018, the transmission line Estreito - Fernão Dias (500 kV) entered into commercial operation one month in advance of the expected go-live. This project is owned by SPE Cantareira (49% Copel GeT).

The line, initially expected to become operational in March 2018, is 342 kilometers long and runs through the states of São Paulo and Minas Gerais, and more than 29 cities. The project will allow a further exchange of power, contributing to the operating security and reliability of the national electric system.

40.5.2     UHE Colíder - change in schedule

The expected start of operations of Hydropower Plant Colider was revised, where the first generating unit is expected for June 2018, while the third and last for November 2018. On April 12, 2018, the installation of the third and last Kaplan rotor was completed. In the powerhouse, the last assembly phase of the three generator groups and turbines is in fast pace, while the transmission line that will connect UHE Colider to the Substation Cláudia into voltage 500 kV is in final installation phase, with wiring in progress.

40.6     Surety provided to related parties

On November 30, 2017 and January 9, 2018, Copel provided sureties for the following transactions:

40.7     UEG Araucária Ltda. - Execution of gas agreement

On January 31, 2018 a fuel supply agreement was entered into by and between Petróleo Brasileiro S.A. - - Petrobras and UEG Araucária Ltda. The agreement will be effective until December 31, 2018 and provides for supply of up to 2,190,000 cubic meters of natural gas a day, with no take-or-pay requirement. Therefore, UTE Araucária is again available to the National Interlinked System - SIN and can be delivered at ONS discretion. Gas will be distributed by Compagás.

40.8     Revision of physical guarantee

The Concession Grantor revised the Physical Guarantee of the following power plants through MME Ordinance 178 of May 3, 2017 with effects from January 1, 2018:

40.9     Recognition of tax credit

On February 14, 2018 the Brazilian Federal Revenue Office recognized tax credit for the restated amount of R$80,226 in favor of Copel regarding the discussion of tax levy on Pasep from July 1988 to July 1995, in connection with the effects of Federal Senate Resolution 49, of October 9, 1995, which suspended the effects of Decree-Laws 2,445/1988 and 2,449/1988, deemed to be unconstitutional by the Federal Supreme Court.

40.10     Credit received related to the Luz Fraterna program

The transfer of the receivables from the Luz Fraterna account of Copel DIS to Copel was suspended from the second half of 2015, considering Decree No. 2,789/2015, which created the possibility of using presumed ICMS (VAT tax) credits for the settlement of invoices referring to this program. In addition, State Law No. 18,875, dated 09.27.2016 authorized the State of Paraná to pay in installments the debts due and unpaid to Copel relating to services rendered up to the date of publication of said Law. On March 23, 2018, the State of Paraná settled the balance of R$115,890.

40.11     Loan agreements

40.11.1Wind power plants

On January 24, 2018, loan agreements were signed between Copel (lender) and the wind farms (borrowers), whose details are disclosed in Notes 15.4 to 15.8, changing the effectiveness for September 28, 2018 and the approved limit to R$408,000, as shown below:

40.11.2Voltalia São Miguel do Gostoso Participações

The loan agreement between Copel (lender) and Voltalia São Miguel do Gostoso (borrower) was settled on February 6, 2018, whose details are disclosed in Note 15.4.

40.12     Concession agreement - Compagás

Compagás is a party to a concession agreement entered into with the Concession Grantor, the State of Paraná, setting July 6, 2024 as the expiry date of the concession. Such date has always been disclosed and considered for assessment of the balances of the financial statements.

On December 7, 2017, the State of Paraná published Supplementary Law 205, introducing a new interpretation of the expiry of the concession, understanding that expiry will be on January 20, 2019.

The management board of Compagás, its Parent company and other shareholders are assessing and challenging the effects of the aforesaid law, understanding that they conflict with the provisions of the concession agreement currently in force. While such discussion is not ended and this law continues to be effective, the effects from the change in the maturity of the concession are being considered as from the financial statements as at December 31, 2017.

40.13     Statement of registration of power plant - UHE Marumbi

On April 17, 2018, ANEEL issued the statement of registration of power plant CGH.PH.PR.001501-6.02 for CGH Marumbi, located in the City of Morretes (State of Paraná - PR), with power of 4.8 MW and physical guarantee of average 2.4 MW.

40.14     Lawsuits

The main lawsuits were recognized and disclosed in December 2017 and are as follows:

i) provision for lawsuit related to discussion by arbitration and under secrecy and confidentiality, in the discovery phase, without no decision being handed down. Moreover, the amount considered as possible loss for this lawsuit was included in note for civil contingent liabilities;

ii) provision for lawsuit in the amount of R$98,000 for compensation of supposed loss to the plaintiff due to work and implementation of the hydroelectric project, with low court judgment declaring the lawsuit has no grounds and being appealed by the grounded claim of the plaintiff, and the amount of damages should be determined subsequently.

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COMMENTS ON PERFORMANCE

For the nine-month period ended September 30, 2017

All amounts expressed in thousands of Brazilian reais, unless otherwise stated

1Distribution Lines

Compact-Design Distribution Lines -Copel Distribuição S.A. has implemented compact-design distribution lines in urban areas with a high concentration of trees surrounding distribution grids. This technology reduces the number of trees cut down or trimmed, and improves the quality of power supply by reducing the number of unplanned outages. The total length of compact-design distribution lines installed at the end of September 2017 was 9,393 km (against 8,657 km in September 2016), up by 736 km year-over-year, a variation of 8.5%.

Secondary Isolated Lines –Copel Distribuição is also investing in low-voltage (127/220V) secondary isolated lines, which offer substantial advantages over regular overhead lines, including: improvement in DEC - Equivalent Time of Interruption per Consumer Unit and FEC - Equivalent Frequency of Interruption per Consumer Unit distribution performance indicators; defense against illegal connections; improved environmental conditions; reduced areas subject to tree trimming; improved safety; reduced voltage drops throughout the grid; and increased transformer useful life due to the reduction of short-circuits, among other advantages. The total length of secondary isolated lines as of the end of September 2017 was 17,076 km (against 15,890 km in September 2016), up by 1,186 year-over-year, a variation of 7.5%.

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2Power Market

Market behavior -Power generation by Copel Geração e Transmissão S.A. and wind farms totaled 15,406 GWh in the first nine months of 2017 (against 20,864 GWh in the same period in 2016). The volume of energy purchased by Copel Distribuição by means of CCEARs (auctions) was 7,936 GWh (against 10,104 GWh in the same period in 2016), while the volume purchased from Itaipu was 4,441 GWh (against 4,461 GWh in the same period in 2016), as described below:

(a) Including energy volumes traded among Copel’s subsidiaries.

(b) Figures subject to change after closing by CCEE.

CCEAR = Energy Purchase Agreements in the Regulated Market

CER: Reserve Energy Agreements

CCEE (MCP) = Electric Pow er Trade Chamber (Short-Term Market)

MRE = Energy Reallocation Mechanism

CG = Center of gravity of the Submarket (difference betw een billed and energy received from CG) – as per the agreement Not considering the energy produced by TPP Araucária w hich w as sold in the short-term market (MCP).

¹Other: Energy purchased by Copel Comercialização

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Energy sale - down by Copel Distribuição, Copel Geração e Transmissão, Copel Comercialização and wind farms:

Segment			GWh
	Jan - Sep 2017	Jan - Sep 2016	Var.
Copel Distribuição
Captive Market	14,878	17,124	-13.1%
Residential	5,342	5,208	2.6%
Industrial	2,498	4,604	-45.7%
Commercial	3,508	3,862	-9.2%
Rural	1,701	1,654	2.8%
Other	1,829	1,796	1.8%
Concessionaries and Licensees	391	484	-19.2%
CCEE (MCP)(a)	2,013	2,252	-10.6%
Total Copel Distribuição	17,282	19,860	-13.0%
Copel Geração e Transmissão
CCEAR (Copel Distribuição) (b)	63	116	-45.7%
CCEAR (other concessionaries) (b)	620	2,676	-76.8%
Free Customers	3,632	2,778	30.7%
Bilateral Agreements	5,483	5,796	-5.4%
CCEE (MCP)	3,348	1,395	140.0%
Total Copel Geração e Transmissão	13,146	12,761	3.0%
Wind Farms Complex
CCEAR (other concessionaries) (b)	627	630	-0.5%
CER (c)	267	268	-0.4%
Total Wind Farms Complex	894	898	-0.4%
Copel Comercialização
Free Customers	516	-	-
Bilateral Agreements	962	-	-
CCEE (MCP) (a)	10	-	-
Total Copel Comercialização	1,488	-	-
Total	32,810	33,519	-2.1%
Note:Not considering the energy from MRE (Energy Relocation Mechanism).
(a) CCEE: Electric Pow er Trade Chamber / MCP: Short Term
(b) CCEAR: Energy Purchase Agreements in the Regulated Market
(c) CER: Agreements Reserve Energy.

Captive Market - Copel Distribuição -Copel Distribuição’s energy sales to the captive market totaled 14,878 GWh in the first nine months of 2017, down by 13.1% against the same period in 2016.

The residential segment consumed 5,342 GWh from January through September 2017, up by 2.6%, due to an increase of 2.3% in the number of customers. The residential segment consumption in the first nine months of 2017 represented 35.9% of the captive market, totaling 3,661,917 consumers.

Consumption by the industrial segment decreased by 45.7% until September 2017, to 2,498 GWh, mainly caused by the migration of captive clients to the free market. The intensive migration of captive clients to the free market (mostly in the second half of 2016) caused a strong decrease in the client database and the energy volume consumed in the industrial segment. Between October 2016 and September 2017, 268 clients left Copel Distribuição’s industrial captive market (30 clients in the third quarter of 2017). Until September 2017, the industrial segment represented 16.8% of the captive market’s consumption and had 76,717 consumers.

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The commercial segment consumed 3,508 GWh until September 2017, down 9.2%. The decrease in the consumption was influenced by the migration of 224 captive clients to the free market between October 2016 and September 2017 (38 clients only in the third quarter of 2017). Until September 2017, this segment accounted for 23.6% of the captive market, totaling 387,686 consumers.

The rural segment recorded an increase of 2.8% in consumption in the first nine months of 2017, totaling 1,701 GWh. By the end of September 2017, this segment accounted for 11.4% of the Copel’s captive market, totaling 355,748 consumers.

Consumption from other segments (public bodies, public lighting, public services and own consumption) totaled 1,829 GWh from January to September 2017, up by 1.8%. Jointly, these segments accounted for 12.3% of the captive market, totaling 57,338 consumers at the end of September 2017.

Number of consumers -The number of end users (captive of Copel Distribution and free consumers of Copel GeT, Copel Comercialização and other suppliers within the concession area of Copel Distribuição) billed in September 2017 was 4,540,359, up by 1.7% against the same month in 2016.

Segment	Sep 2017	Sep 2016	Var.
Residential	3,661,917	3,580,622	2.3%
Industrial	76,717	83,683	-8.3%
Commercial	387,686	380,354	1.9%
Rural	355,748	361,982	-1.7%
Others	57,338	57,364	0.0%
Total Captive Market	4,539,406	4,464,005	1.7%
Concessionaries and Licensees	6	6	-
Free Customers¹	947	447	111.9%
Total geral	4,540,359	4,464,458	1.7%
¹ All free customers served by Copel GeT, Copel Comercialização and other suppliers at the Copel Distribuição concession area.

3Management

Headcount

Employees	Sep 2017	Sep 2016
Copel and subsidiaries
Copel	80	69
Copel Geração e Transmissão	1,769	1,681
Copel Distribuição	5,869	6,097
Copel Telecomunicações	660	640
Copel Comercialização	40	20
Copel Renováveis	-	56
	8,418	8,563
Affiliated Company
Compagás	163	162
Elejor	7	7
UEG Araucária	17	16
	187	185

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4Market Relations

From January to September 2017, Copel’s common (ON — ticker CPLE3) and class B preferred registered shares (PNB - ticker CPLE6) were traded in 100% of trading sessions of B3 S.A. - Brasil, Bolsa, Balcão.

The shares outstanding totaled 44.96% of the Company’s capital stock. At the end of September 2017, Copel’s market value was R$7,004,760, based on quotations of all markets.

Out of the 59 stocks that make up Ibovespa’s theoretical portfolio, Copel’s PNB shares was 0.233%, with a 1.2592 Beta index.

Copel’s share in the portfolio of the Electric Power Sector Index - IEE was 5.3510%.

COPEL PNB’s share in B3 - Corporate Sustainability Index (ISE) was 0.7870%.

In B3, ON shares closed the period traded at R$23.30, while PNB shares closed at R$28.23, with negative variations of 22.12% and 3.18%, respectively. In the same period, the IBOVESPA index recorded a positive variation of 23.36%.

On the New York Stock Exchange (NYSE), PNB shares are traded at “Level 3”, in the form of ADSs, under ticker ELP, and were traded in 100% of the trading sessions, closing the period at US$8.86, with a positive variation of 4.48%. Also in this period, the Dow Jones Index recorded a positive variation of 13.37%.

On the Latibex (the Euro market for Latin American Securities), which is connected to the Madrid Stock Exchange), the Company’s PNB shares were traded under the ticker XCOP in 54% of trading sessions, closing the period at € 7.75, with a negative variation of 4.08%. In the same period, the Latibex All Shares index recorded a negative variation of 11.65%.

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The table below is a summary of Copel’s share trading between January and September 2017:

	ON		PNB
Stock Performance (Jan - Jun/2017)	Total	Daily average	Total	Daily average
B3
Number of Trades	40,036	214	654,620	3,501
Volume Traded	12,564,100	67,188	121,557,800	650,042
Trading Value (R$ thousand)	280,218	1,498	3,695,182	19,760
Presence in Trading Sessions	187	100%	187	100%
Nyse
Volume Traded	202,847	1,610	95,937,693	510,307
Trading Value (US$ thousand)	1,393	11	870,369	4,630
Presence in Trading Sessions	126	67%	188	100%
Latibex
Volume Traded	-	-	1,467,880	14,114
Trading Value (€ thousand)	-	-	489	5
Presence in Trading Sessions	-	-	104	54%

5Tariffs

Power distribution tariffs

Retail distribution average rate (a) - R$/MWh	Seo 2017	Sep 2016	Var.
Residential	440.54	421.41	4.5%
Industrial (b)	408.44	366.98	11.3%
Commercial	440.25	408.88	7.7%
Rural	298.48	285.90	4.4%
Other	324.98	306.14	6.2%
	404.99	379.04	6.8%
(a) W ithout ICM S. Does not consider tariff flags.
(b) Free customers not included.

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Power purchase tariffs

Tariff Supply* - R$/MWh	Sep 2017	Sep 2016	Var.
Itaipu (a)	205.83	190.35	15.5%
Auction 2008 - 2015	-	-	-
Auction 2010 - H30	218.27	210.41	8.2%
Auction 2010 - T15 (b)	273.46	187.03	-24.3%
Auction 2011 - H30	225.62	217.82	7.9%
Auction 2011 - T15 (b)	356.45	225.77	-6.1%
Auction 2012 - T15 (b)	304.55	205.01	6.8%
Auction 2016 - T20 (b)	161.91	149.15	11.9%
Auction CCEAR 2014 - 2019 (c)	365.41	138.18	4.3%
Auction CCEAR 2014 - 2019 (d)	333.18	320.12	4.1%
Auction 2014 - 18M	-	-	-
Auction 2014 - 36M	-	176.64	-100.0%
Bilaterais	240.53	232.69	3.4%
Angra	229.71	204.39	12.4%
CCGF (e)	64.39	69.27	-0.5%
Santo Antonio	139.84	134.99	7.9%
Jirau	123.00	118.73	7.9%
Other auctions (f)	245.75	191.75	-17.4%
Tariff Average Supply	183.46	161.11	-2.3%

(a) Furnas transport charge not included.

(b) Average auction price restated according t o the IPCA inflation index. The price comprises in fact three components: a fixed (c) Energy Agreements.

(d) Capacity Agreements.

(e) Contract of quotas of assured pow er of those HPPs w hich concessions w ere extended pursuant the new rules of Law 12783/1 (f) Products average price.

*The table has been updated for all periods as new calculation methodology for average prices, a result of the 4th phase of the Public Hearing 78/2011 Aneel approved on 03.28.2016.

Products average price

Tariff Weighted Average Supply - R$/MWh	Sep 2017	Sep 2016	Var.
Auction - CCEAR 2011-2040	209.78	201.05	4.3%
Auction - CCEAR 2013-2042	225.81	215.44	4.8%
Auction - CCEAR 2015 - 2045	160.08	151.69	5.5%
Concession holders in the State of Paraná	236.16	217.14	8.8%

6Economic and Financial Results

Revenues (Note 32)

Until September 2017, net operating revenues was R$10,113,909, or 3.2% down against R$9,804,701 recorded in the same period in 2016.

This variation was mainly explained by:

a)17.1% reduction in Revenues from Supply, mainly caused by:

·17.9% average reduction in the tariff effective from June 2016; and

·a 13.1% retraction in the captive market compared to the same period in 2016, basically due to the migration of captive clients to the free market;

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b)a 15.1% increase in Revenues from Supply, mainly caused by the increase in CCEE Revenues due to a greater average PLD in the period, R$291.51/MWh in the third quarter of 2017 against R$68.93/MWh in the third quarter of 2016;

c)a 12.3% decrease in Revenues from the Availability of the Power Grid, mainly caused by the cash flow remeasurement as a result of the appraisal report related to RBSE assets;

d)a 36.7% decrease in Construction Revenue, mainly caused by the revision of the implementation schedule of certain projects;

e)a 21.2% increase in Revenues from Telecommunication, largely due to the increase in the number of clients, particularly in the retail market, with the Copel Fibra product; and

f)a 128.4% increase in Sectorial financial assets and liabilities result, mainly caused by the constitution of sectorial assets relating to electricity costs and the amortization of sectorial liabilities

Operating Costs and Expenses (Note 33)

Until September 2017, operating costs and expenses totaled R$8,366,807, up by 6.1% compared to R$7,833,223 recorded in the same period in 2016. The main highlights were as follows:

a)a 27.6% increase in electricity purchased for resale, especially given the price variation;

b)a 29.2% decrease in the account Charges for use of the power grid, mainly due to the lower costs of System services charges - ESS and the Reserve energy charges - EER, offset by the increase in costs of basic grid and energy transmission, due to the effects of the indemnities to energy transmission companies.

c)a 8.7% increase compared to the same period in 2016 in the balance of the Personnel and Management account, mainly due to salary adjustments, as per the collective bargaining agreement in effect as from October 2016;

d)a 6.2% reduction in natural gas and inputs used in gas operations, due to the decrease in consumption; and

e)a 41.1% decrease in Estimated losses, provisions and reversals, mainly due to the reversal of estimated losses on impairment of assets and decrease in allowance for doubtful accounts, offset by the increase in provision for legal claims.

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Financial Result (Note 34)

The variation of R$113,520 in financial result is mainly due to a 21.6% decrease in financial income, due to lower late payment charges on electricity bills and the deflation of the financial indexes used to restate the financial income, compared to the same period of 2016.

Ebitda

Ebitda (earnings before interest, taxes, depreciation and amortization) is as follows:

The EBITDA is a non-accounting measure prepared by the Company, reconciled with its financial statements, pursuant to the provisions of Circular Letter/CVM/SNC/SEP No. 01/2007 and CVM Instruction No. 527/2012. It is not a measure recognized by accounting practices adopted in Brazil or international accounting standards, does not have a standard meaning and cannot be comparable to measures with similar titles provided by other companies. The Company discloses it because it is used to measure its performance.

The EBITDA cannot be considered separately or as a substitute of net income or operating income, as an indicator of operating performance or cash flow, or to measure the liquidity or the ability to pay debt.

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COMPOSITION OF GROUPS RESPONSIBLE FOR GOVERNANCE
BOARD OF DIRECTORS
Chairman	MAURICIO SCHULMAN
Members	ANTONIO SERGIO DE SOUZA GUETTER
	GEORGE HERMANN RODOLFO TORMIN
	ROGÉRIO PERNA
	OPEN VACANCY
	ADRIANA ANGELA ANTONIOLLI
	LEILA ABRAHAM LORIA
	OLGA STANKEVICIUS COLPO
	SÉRGIO ABU JAMRA MISAEL
STATUTORY AUDIT COMITEE
Chairman	MAURICIO SCHULMAN
Financial Expert	ROGÉRIO PERNA
Members	OPEN VACANCY
	LEILA ABRAHAM LORIA
	OLGA STANKEVICIUS COLPO
SUPERVISORY BOARD
Sitting members	NORBERTO ANACLETO ORTIGARA
	MAURO RICARDO MACHADO COSTA
	NELSON LEAL JUNIOR
	ROBERTO LAMB
	LETÍCIA PEDERCINI ISSA MAIA
Alternate members	OSNI RISTOW
	ROBERTO BRUNNER
	GILMAR MENDES LOURENÇO
	KURT JANOS TOTH
	ALEXANDRE PEDERCINI ISSA
EXECUTIVE BOARD
CEO	ANTONIO SERGIO DE SOUZA GUETTER
Enterprise Management Officer	GILBERTO MENDES FERNANDES
Chief Financial and Investor Relations Officer	ADRIANO RUDEK DE <OURA
Chief Business Development Officer	HARRY FRANÇÓIA JÚNIOR
Chief Legal and Institutional Relations Officer	CRISTIANO HOTZ
Chief Governance, Risk and Compliance Officer	FABIO MALINA LOSSO
Assistant Officer	PAULO CESAR KRAUSS
ACCOUNTANT
CRC-PR-045809/O-2	ADRIANO FEDALTO
Information about this report
Investor Relations	Phone: +55 (41) 3222-2027
	ri@copel.com

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S T A T E M E N T

By this document, the Chief Executive Officer and the other Officers of Companhia Paranaense de Energia - Copel, publicly-held mixed capital company, with its headquarters at Rua Coronel Dulcídio nº 800, Curitiba - PR, enrolled with the National Registry of Legal Entities (CNPJ) under No. 76.483.817/0001-20, for the purposes of the provisions in item II, paragraph 1 of article 29 of CVM Instruction 480/2009, state that:

 (I)        they have reviewed and discussed and agree with the opinions expressed in the audit report of Deloitte Touche Tohmatsu Auditores Independentes related to the interim financial information of Copel included in the Quarterly Information Form - ITR as of September 30, 2017; and

 (II)       they have reviewed and discussed and agree with the interim financial information of Copel included in the Quarterly Information Form - ITR as of September 30, 2017.

Curitiba, November 29, 2017

/s/ GILBERTO MENDES FERNANDES Acting Chief Executive Officer and Chief Enterprise Management Officer	/s/ HARRY FRANÇÓIA JÚNIOR Chief Business Development Officer
/s/ ADRIANO RUDEK DE MOURA Chief Financial and Investor Relations Officer	/s/ FABIO MALINA LOSSO Chief Governance, Risk and Compliance Officer
/s/ CRISTIANO HOTZ Chief Legal and Institutional Relations Officer

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REVIEW REPORT ON QUARTERLY INFORMATION

REVIEW REPORT ON QUARTERLY INFORMATION

To the Shareholders and Management of

Companhia Paranaense de Energia - Copel

Curitiba – State of Paraná

Introduction

We have reviewed the accompanying individual and consolidated quarterly information of Companhia Paranaense de Energia - COPEL (the “Company”), included in the Quarterly Information Form - ITR, for the quarter ended September 30, 2017, which comprises the statement of financial position as at September 30, 2017 and the related statements of income, comprehensive income, changes in equity and cash flows for the three and nine-month periods then ended, including the explanatory notes.

The Company’s Management is responsible for the preparation of this individual and consolidated quarterly information in accordance with technical pronouncement CPC 21 (R1) – Interim Financial Reporting and with international standard IAS 34– Interim Financial Reporting issued by the International Accounting Standards Board – IASB, as well as for the presentation of such information in accordance with the standards issued by the Brazilian Securities and Exchange Commission - CVM, applicable to the preparation of Quarterly Information Form - ITR.Our responsibility is to express a conclusion on this quarterly information based on our review.

Scope of Review

We conducted our review in accordance with Brazilian and international standards on review of interim financial information (NBC TR 2410 and ISRE 2410 - Review of Interim Financial Information Performed by the Independent Auditor of the Entity, respectively).A review of interim financial information consists of making inquiries, primarily of persons responsible for financial and accounting matters, and applying analytical and other review procedures.A review is substantially less in scope than an audit conducted in accordance with the standards on auditing and, consequently, does not enable us to obtain assurance that we would become aware of all significant matters that might be identified in an audit.Accordingly, we do not express an audit opinion.

Conclusion on the Quarterly Information

Based on our review, nothing has come to our attention that causes us to believe that the accompanying individual and consolidated quarterly information included in the quarterly information referred to above has not been prepared, in all material respects, in accordance with technical pronouncement CPC 21 (R1) and international standard IAS 34 applicable to the preparation of Quarterly Information - ITR and presented in accordance with the standards issued by the Brazilian Securities and Exchange Commission - CVM.

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Emphasis of Matter

Restatement of quarterly information

On November 29, 2017, we issued an unqualified report on review of the Company’s individual and consolidated quarterly information for the quarter ended September 30, 2017, which is currently being restated.As mentioned in note 4.1 to the quarterly information, this quarterly information has been changed and is being restated to reflect:(a) (i) the accounting adjustments of the investment in exclusive investment fund of the indirect subsidiary UEG Araucária Ltda., in the amount of R$ 150,357 thousand, as provided for in international standard IAS 8/ technical pronouncement CPC 32 - Accounting Policies, Change in Accounting Estimates and Errors; (ii) the adjustments from prior periods related to the taxation regime of the Offsetting and Variation of Tranche A account - CVA, in the amount of R$ 31,995 thousand, as provided for in international standard IAS 8 / technical pronouncement CPC 23 - Accounting Policies, Change in Accounting Estimates and Errors; and (b) events after the reporting period between the base date of this quarterly information and the date of approval for restatement of this quarterly financial information.Our conclusion is not modified in respect of this matter.

Restatement of comparative balances

As mentioned in note 4.1 to the quarterly information, due to the change in accounting policy adopted by the Company, related to the classification of the adjustment of the expected cash flows of the concession financial asset, and the effects of prior years of item (a) described in the previous paragraph, the corresponding amounts of the quarterly information related to the statement of financial position as at December 31, 2016, the statements of income, comprehensive income, changes in equity and cash flows for the three and nine-month periods ended September 30, 2016, and the statement of value added for the nine-month period then ended (supplementary information), presented for comparison purposes, have been adjusted  and are being restated as provided for in international standard IAS 8 / technical pronouncement CPC 23. Our opinion is not modified in respect of this matter.

Other Matters

Statements of added value

We have also reviewed the individual and consolidated statements of added value (“DVA”) for the nine-month period ended September 30, 2017, prepared under the responsibility of the Company’s Management, the presentation of which in the quarterly information is required by the standards issued by CVM applicable to the preparation of Quarterly Information - ITR, and considered supplemental information by International Financial Reporting Standards - IFRS, which do not require the presentation of a DVA.These statements were subject to the same review procedures described above and, based on our review, nothing has come to our attention that causes us to believe that they have not been prepared, in all material respects, in relation to the quarterly information taken as a whole.

Curitiba, June 13, 2018

DELOITTE TOUCHE TOHMATSU Auditores Independentes   Fernando de Souza Leite Engagement Partner  

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(CONVENIENCE TRANSLATION INTO ENGLISH FROM THE ORIGINAL PREVIOUSLY ISSUED IN PORTUGUESE)

SUPERVISORY BOARD’S OPINION

ON THE RESTATED INTERIM FINANCIAL INFORMATION FOR THE THIRD QUARTER OF 2017

The members of the Supervisory Board of Companhia Paranaense de Energia - Copel, undersigned, in accordance with their legal and statutory duties and responsibilities, have examined the Interim Financial Information for the 3rd quarter of 2017 approved by the Company’s Board of Directors at the meeting held on this date. The minutes were received and assessed individually by the members prior to the meeting and were previously discussed with the Management, the independent auditors and the Supervisory Board. Based on the work performed in the quarter, the analyses performed, the monitoring of discussions on internal controls and the clarifications provided by Management and the independent auditors and also considering the Limited Review Report of the Independent Auditors Deloitte Touche Tohmatsu Auditores Independentes, issued without qualifications, the members of the Supervisory Board declare that they are not aware of any facts or evidences that are not reflected in the Interim Financial Information for the quarter ended September 30, 2017 and conclude that this information may be disclosed.

Curitiba, June 13, 2018

                        /s/                                                                                                 /s/

GILMAR MENDES LOURENÇO                                                       LETÍCIA PEDERCINI ISSA MAIA

     /s/                                                                               /s/

MAURO RICARDO MACHADO COSTA                                            ROBERTO LAMB

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(CONVENIENCE TRANSLATION INTO ENGLISH FROM THE ORIGINAL PREVIOUSLY ISSUED IN PORTUGUESE)

S T A T E M E N T

By this document, as Officers of Companhia Paranaense de Energia - Copel, publicly-held mixed capital company, with its headquarters at Rua Coronel  Dulcídio nº 800, Curitiba - PR, enrolled with the National Registry of Legal Entities (CNPJ) under No. 76.483.817/0001-20, for the purposes of the provisions in item II, paragraph 1 of article 29 of CVM Instruction 480/2009, state that:

(I)        we have reviewed and discussed and agree with the opinions expressed in the audit report of Deloitte Touche Tohmatsu Auditores Independentes related to the interim financial information of Copel included in the Quarterly Information Form - ITR as of September 30, 2017, restated on June 13, 2018; and

 (II)      we have reviewed and discussed and agree with the interim financial information of Copel included in the Quarterly Information Form - ITR as of September 30, 2017, restated on June 13, 2018.

In witness whereof, we sign this document.

Curitiba, June 13, 2018

/s/

Jonel Nazareno Iurk

Chief Executive Officer

           /s/

Ana Letícia Feller

Enterprise Management Officer

     /s/

Adriano Rudek de Moura

Chief Financial and Investor Relations Officer

/s/

José Marques Filho

Business Development Officer

   /s/

Harry Françóia Júnior

Chief Legal and Institutional Relations Officer

             /s/

Vicente Loiácono Neto

Governance, Risk and Compliance Officer

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SIGNATURE

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

Date July 11, 2018

COMPANHIA PARANAENSE DE ENERGIA – COPEL
By:	/S/  Antonio Sergio de Souza Guetter
	Antonio Sergio de Souza Guetter Chief Executive Officer

FORWARD-LOOKING STATEMENTS

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