Regulatory Reporting Manual Volume 5 Electricity … · Regulatory Reporting Manual Volume 5 Electricity Supply Industry. Non-Financial Information ... 13.2.3 IPP Primary Energy NFI

1 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016

ANNEXURE A

Regulatory Reporting Manual Volume 5 Electricity Supply Industry

Non-Financial Information (NFI) Purpose: To prescribe and guide the regulated

entities in the Electricity Supply Industry on non- financial information (NFI) required by the Energy

Regulator, in order to achieve uniformity in content,

measurement, preparation format and submission of

this NFI to the Energy Regulator to perform its

functions.


TABLE OF CONTENTS

ANNEXURE A .......................................................................................................................................................... 1 TABLE OF CONTENTS............................................................................................................................................ 2 Introduction 4 1.1 List of Acronyms/Abbreviations ........................................................................................................ 4 1.2 General Glossary of Terminology and Definitions ............................................................................ 5 1.3 Electricity Supply Industry Terminology and Definitions ................................................................. 6 1.4 Preamble ............................................................................................................................................ 9 1.5 NERSA Legislative Mandate to Prescribe Reporting Requirements ................................................ 9 1.5.1 Electricity Regulation Act, 2006 (Act No. 4 of 2006) (‘the Act’) ......................................................... 9 1.5.2 Information Required for Collection of Levies ................................................................................ 11 1.5.3 Regulations issued by the Minister in terms of the Act .................................................................. 11 1.5.4 NERSA Rules and Codes Issued in terms of the Act .................................................................... 11 1.5.5 The National Energy Regulator Act on the Functions of the Regulator ......................................... 11 1.5.6 Licence issued to Generators (Eskom) ........................................................................................... 12 1.5.7 Licence issued to Generators (IPPs) ............................................................................................... 12 1.5.8 Licence issued to Transmitters ....................................................................................................... 12 1.5.9 Licence issued to Distributors ......................................................................................................... 12 1.5.10 Summary Table of Some of the Legislative Provisions .................................................................. 13 1.6 Purpose of the Non-Financial Information (NFI) Manual ................................................................. 14 1.7 Applicability of NFI Manual .............................................................................................................. 14 1.8 Disclaimer ........................................................................................................................................ 14 2 NFI Categories ................................................................................................................................. 15 2.1 Static information ............................................................................................................................. 15 2.2 Dynamic information ........................................................................................................................ 15 3 Measurements/Calculations ............................................................................................................ 15 3.1 Units of measurement ...................................................................................................................... 15 3.2 Measurements and calculations ...................................................................................................... 15 4 Responsibility for NFI Submission and Solemn Declaration ......................................................... 17 5 Records Keeping ............................................................................................................................. 17 6 Audit of NFI ...................................................................................................................................... 17 7 Publication and Confidentiality ....................................................................................................... 18 8 Effective Date and Implementation Costs of the NFI Manual ......................................................... 18 9 Review and Modification of the NFI Manual ................................................................................... 19

Eskom NFI Required Information (Generation, Transmission & Distribution) ................... 20 10 Eskom Generation Facilities NFI Required and Submission Timeframes ..................................... 21 10.1 Eskom Generation Facilities Static NFI ........................................................................................... 21 10.1.1 Eskom Static NFI .............................................................................................................................. 21 10.1.2 Eskom Generation Facilities Static NFI ........................................................................................... 21 10.2 Eskom Generation Facilities Dynamic NFI ...................................................................................... 22 10.2.1 Production NFI for Total Eskom Generation System ...................................................................... 22 10.2.2 Eskom Production NFI per Power Station....................................................................................... 22 10.2.2.1 Eskom Production NFI for each Coal Power Station ...................................................................... 22 10.2.2.2 Eskom Production NFI for each Nuclear Power Station ................................................................. 23 10.2.2.3 Eskom Production NFI for each Hydro Power Station (include small Hydro) ............................... 24 10.2.2.4 Eskom Production NFI for each Pumped Storage Hydro Power Station ....................................... 24 10.2.2.5 Eskom Production NFI for each Gas/Diesel Power Station ............................................................ 25 10.2.2.6 Eskom Production NFI for each Renewable Energy Power Station ............................................... 25 10.2.3 Eskom Primary Energy NFI ............................................................................................................. 26 10.2.3.1 Eskom Primary Energy NFI for each Coal Power Station .............................................................. 26 10.2.3.2 Eskom Primary Energy NFI for Nuclear Power Station .................................................................. 26 10.2.3.3 Eskom Primary Energy NFI for Hydro Power Station (including small Hydro) .............................. 26 10.2.3.4 Eskom Primary Energy NFI for each Pumped Storage Hydro Power Station ................................ 27 10.2.3.5 Eskom Primary Energy NFI for each Diesel Power Station ............................................................ 27 10.2.4 Eskom Primary Energy NFI for Renewable Energy Power Station (Wind, Solar PV, CSP) ........... 27 10.2.5 Eskom Environmental NFI for each Coal Generation Power Station ............................................. 27 11 Eskom Transmission Facilities NFI Required and Submission Timeframes ................................. 28 11.1 Eskom Transmission Facilities Static NFI....................................................................................... 28 11.1.1 Eskom Transmission Static NFI ...................................................................................................... 28 11.1.2 Eskom Transmission Static NFI ...................................................................................................... 28 11.2 Eskom Transmission Facilities Dynamic NFI.................................................................................. 29 11.2.1 Eskom Transmission Substation Information ................................................................................. 29 11.2.2 Eskom Transformer Installed Capacity Information ....................................................................... 29 11.2.3 Eskom Transmission Lines Information ......................................................................................... 30 11.2.4 Eskom Transmission Volumes Information .................................................................................... 30 11.2.5 Ancillary Services ............................................................................................................................ 31 11.2.6 Eskom Transmission Service Quality Incentive ............................................................................. 31 11.2.7 Eskom Transmission Quality of Supply .......................................................................................... 31 11.2.8 System Operations........................................................................................................................... 32 12.1 Eskom Distribution Static NFI ......................................................................................................... 33


12.1.1 Eskom Distribution Static NFI ......................................................................................................... 33 12.1.2 Eskom Distribution Facility Static NFI ............................................................................................. 33 12.2.1 Eskom Distribution Facility NFI ....................................................................................................... 34 12.2.2 Eskom Distribution Estimated System Losses ............................................................................... 34 12.2.3 Eskom Electrification Information (INEP Funded) .......................................................................... 34 12.2.4 Eskom Energy Efficiency & Demand Side Management (EEDSM)................................................ 35 12.2.5 Eskom Distribution Quality of Service ............................................................................................ 35 12.2.6 Eskom Distribution Quality of Supply ............................................................................................. 36

Independent Power Producers (IPP) NFI Required Information .......................................... 37 13 IPP Facilities NFI Required and Submission Timeframes ............................................................. 38 13.1 IPP Facilities Static NFI .................................................................................................................... 38 13.1.1 Licensee Static NFI .......................................................................................................................... 38 13.1.2 IPP Facilities Static NFI .................................................................................................................... 38 13.2 IPP Facilities Dynamic NFI ............................................................................................................... 39 13.2.1 Production NFI for an IPP Facility ................................................................................................... 39 13.2.2 IPP Production NFI per Power Station ............................................................................................ 39 13.2.2.1 IPP Production NFI for Coal Power Station ..................................................................................... 39 13.2.2.2 IPP Production NFI for Hydro Power Station (including small Hydro) ........................................... 40 13.2.2.3 IPP Production NFI for Gas/Diesel Power Station .......................................................................... 40 13.2.2.4 IPP Production NFI for Renewable Energy Power Station ............................................................. 41 13.2.3 IPP Primary Energy NFI ................................................................................................................... 42 13.2.3.1 IPP Primary Energy NFI for Coal Power Station ............................................................................. 42 13.2.3.2 IPP Primary Energy NFI for Hydro Power Station ........................................................................... 42 13.2.3.3 IPP Primary Energy NFI for Diesel Power Station........................................................................... 42 13.2.3.4 IPP Primary Energy NFI for Natural Gas or LNG Power Station .................................................... 42 13.2.4 IPP Primary Energy NFI for Renewable Energy Power Station (Wind, Solar PV, Solar CSP) 43 13.2.5 IPP Primary Energy NFI for Renewable Energy Power Station (Biomass or Biogas) ..................... 43 13.2.6 IPP Environmental NFI for Generation Power Station .................................................................... 43 14 IPP Distribution Connection Facilities NFI Required and Submission Timeframes ............... 44 14.1 IPP Distribution Connection Facilities Static NFI............................................................................ 44 14.1.1 IPP Distribution Connection Facility Licensee Static NFI ............................................................... 44 14.1.2 IPP Distribution Licensed Facilities Static NFI ................................................................................ 44 15.1 Distribution Facilities Static NFI ...................................................................................................... 46 15.1.1 Distribution Licensee Static NFI ...................................................................................................... 46 15.1.2 Distribution Licensed Facilities Static NFI ...................................................................................... 46 15.2.1 Distribution Facility NFI ................................................................................................................... 47 15.2.2 Distribution System Losses............................................................................................................. 47 15.2.3 Electrification Information (INEP Funded) ...................................................................................... 47 15.2.4 Energy Efficiency & Demand Side Management (EEDSM)............................................................ 48 15.2.5 Quality of Service ............................................................................................................................. 48 15.2.6 Distribution Quality of Supply ......................................................................................................... 49


Introduction

1.1 List of Acronyms/Abbreviations

1. BOO Build Own and Operate

2. COD Commercial Operation Date

3. DSLI Distribution Supply Loss Index

4. DoE Department of Energy

5. DMP Demand Market Participation

6. Dx Distribution

7. EAF Energy availability factor

8. ESI Electricity Supply Industry

9. FBE Free Basic Electricity

10. FII Forced interruption index

11. GPS Global positioning system

12. GIS Geographic information system

13. GW Gigawatt

14. GWh Gigawatt- hour

15. Gx Generation

16. HV High Voltage

17. INEP Integrated National Electrification Programme

18. IPP Independent Power Producer

19. IRP Integrated Resource Plan

20. km Kilometre

21. kV Kilovolt

22. kVA Kilovolt-amperes

23. kW Kilowatt

24. kWh Kilowatt hour

25. kVar Kilovolt-amperes reactive

26. LV Low voltage

27. MV Medium Voltage

28. MVA Megavolt amperes

29. MVar Megavolt amperes-reactive

30. MW Megawatt

31. MWh Megawatt hour

32. NPR Network Performance Related

33. NERSA National Energy Regulator of South Africa

34. NFI Non-Financial Information

35. OCGT Open Cycle Gas Turbine

36. O/HL Overhead lines


37. OH&SA Occupational Health and Safety Act, 1993 (Act No. 85 of 1993)

38. PCLF Planned capability loss factor

39. PLL Partial Load Losses

40. PQ Power Quality

41. PS Power station

42. QOS Quality of supply

43. RAB Regulatory Asset Base

44. RE Renewable Energy

45. REIPPP Renewable Energy Independent Power Producers

Programme

Procurement

46. RRM Regulatory Reporting Manual

47. RRS Regulatory Reporting System

48. SAIDI System Average Interruption Duration Index

49. SAIFI System Average Interruption Frequency Index

50. SLI Supply Loss Index

51. SQI Service Quality Incentive

52. TRFR Transformer

53. TS Transmission system

54. UAGS Unplanned automatic grid separations

55. UCLF Unplanned capability loss factor

56. Um, Umax Maximum rated voltage

57. Un Nominal voltage

58. VOM Variable Operating and Maintenance (cost)

59. VT Voltage transformer

1.2 General Glossary of Terminology and Definitions

1. Department – Department of Energy of the Republic of South Africa.

2. Energy Regulator – National Energy Regulator of South Africa (NERSA) established

in terms of Section 3 of the National Energy Regulator Act, 2004 (Act No. 40 of 2004).

3. Electricity Regulation Act – Electricity Regulation Act, 2006 (Act No. 4 of 2006).

4. Electricity Resellers - means entities that purchase electricity from licensed distributors

and resells it to end-user customers.

5. Government – Government of the Republic in South Africa.

6. Licensee – a holder of a licence granted or deemed to have been granted by the

Energy Regulator under the Electricity Regulation Act, 2006 (Act No. 4 of 2006).

Licensee and Regulated Entity shall be used interchangeably.

7. Independent Power Producer (IPP) – Any person in which the Government or any

organ of state does not hold a controlling ownership interest (whether direct or


indirect), which undertakes or intends to undertake the development of new generation

capacity pursuant to a determination made by the Minister in terms of the Act.

8. Integrated Resource Plan (IRP) – A national electricity plan issued by the Department

of Energy that directs the expansion of the electricity supply in South Africa over the

given period.

9. Manual – Non-Financial Information (NFI) Manual.

10. Minister – Minister of Energy.

11. National Transmission Company (NTC) – The person licensed to execute the national

transmission responsibility, in its capacity as such, including the transmission network

service provider which maintains and develops the transmission network, but

excluding the system operator.

12. Plant (or utility plant) – All equipment used for the generation, transmission, distribution

of electricity.

13. Regulations – Electricity Regulations on Electricity Supply Industry (ESI) issued in

terms of Electricity Regulation Act, 2006 (Act No. 4 of 2006), Government Gazette

Notice No. 34262 of 04 May 2011.

14. Regulated Business – Any licensee, service or activity that is subject to regulation by

NERSA in terms of the National Energy Regulator Act, 2004 (Act No. 40 of 2004), the

Electricity Regulation Act, 2006 (Act No. 4 of 2006) and any regulation or rule made

or issued.

15. Regulated Entity – Regulated Business.

16. Regulated facility – Any licensee, service or activity that is subject to regulation by

NERSA in terms of the National Energy Regulator, 2004 (Act No. 40 of 2004), the

Electricity Regulation Act, 2006 (Act No. 4 of 2006).

17. System operator – an entity responsible for the short-term reliability of the

interconnected power system, which is in charge of controlling and operating the

transmission power system and dispatching generation facilities (or balancing the

supply and demand of electricity) in real time, in its capacity as such.

18. Unregulated Business – Entity, service or activity that is not subject to regulation by

the Energy Regulator.

1.3 Electricity Supply Industry Terminology and Definitions

1. Availability – the capability of a unit / generating fleet to generate energy irrespective

of the actual energy produced.

2. Capacity Factor – the averaged unrestricted output divided by the installed capacity.

3. Demand Side Management (DSM) – Technology or programme that encourages

customers to modify patterns of electricity usage including timing and level of

consumption. This includes conservation, interruptability and load shifting.


4. Energy efficiency – Achieving the same or improved output with reduced input of

energy.

5. Generating station/plant or power plant – A plant or building that contains the

necessary equipment for generating electrical energy.

6. High voltage (HV) - nominal voltage levels that equal to greater than 44kV up to and

including 132 kV

7. Household - a household is a person, or a group of persons, who occupy a common

dwelling (or a part of it) for domestic purposes.

8. Installed Capacity – Also referred to as “gross capacity”. It is the maximum capacity

obtainable under continuous operation, which is usually determined by the

manufacturer’s specification and appears on the nameplate of the equipment. It needs

not to relate to any operational reality. It is the gross capacity, which does not

necessarily refer to the unit’s maximum rating, but the output under specified installed

conditions. It is essentially different from maximum electrical capacity or actual

available capacity, which relate to the functioning of the equipment in conjunction with

other plant on which that equipment depends under specified conditions, which may

be either assumed or real. For generators this capacity is measured in MW or MVA at

the generator output terminals and therefore includes the unit auxiliary and transformer

loss capacity..

9. Load Factor – is the instantaneous output divided by its nominal capacity.

10. Low-voltage (LV) - nominal voltage levels up to and including 1 kV

11. Medium voltage (MV) - nominal voltage levels greater than 1 kV and less than 44 kV.

12. Non-Technical Losses – losses due to theft of electrical energy and errors due to

inaccuracy of meters and administrative losses.

13. Primary Energy –designates an energy source that is extracted from a stock of natural

resources or captured from a flow of resources and that has not undergone any

transformation or conversion other than separation and cleaning. Examples include

coal, crude oil, natural gas, solar power, nuclear power, etc. Fuel for other purposes

is excluded.

14. Quality of Supply (QoS) - technical parameters that describe the electricity supplied to

customers according to NRS 048 standard and any other NERSA prescribed

requirements.

15. Rated Capacity (Generation) – The maximum capacity that an electricity generation

facility is capable to generate based on the design criteria.

16. Rural - all areas not proclaimed as urban, including commercial farms, small

settlements, rural villages and all other areas, which are not part of proclaimed towns

and cities.

17. Technical Losses –losses intrinsic in transporting electrical energy (that is heating and

no-load losses etc.


18. Urban - an area, which has been legally proclaimed as urban. These include towns,

cities and metropolitan areas.

19. Other terminologies used herein, unless defined otherwise in the NFI Manual, will take the same meaning as that used in the Electricity Supply Industry Grid Code (Transmission and Distribution) and the Electricity Regulation Act.


1.4 Preamble

The National Energy Regulator of South Africa (NERSA) requires sufficient and accurate

information from regulated entities in order to make well-informed decisions on issues of market

supply and demand, competition development, and service quality, and service availability,

financial health of the regulated entities and setting/approval of fair and reasonable tariffs

aligned with the public interest.

To gather that information, the Energy Regulator is issuing this Non-Financial Information (NFI)

Manual, in addition to the already issued Regulatory Reporting Manuals (RRM), to guide the

licensees in recording and regularly submitting to the Energy Regulator its non-financial

information, both in a systematic and consistent way.

The goal is to have regular, systematic, consistent, and sufficient non-financial information

relevant to economic regulation, to enhance efficiency and transparency of the regulatory

process.

1.5 NERSA Legislative Mandate to Prescribe Reporting Requirements

The legal basis on which NERSA requires NFI is in terms of the following:

a) The Electricity Regulation Act, 2006 (Act No. 4 of 2006), as amended;

b) The Regulations issued by the Minister of Energy in terms of the Electricity Regulation

Act, 2006 (Act No. 4 of 2006);

c) The Promotion of Administrative Justice Act, 2000 (No. 3 of 2000)

d) Promotion of Access to Information Act, 2000 (No. 2 of 2000)

e) National Archives of South Africa Act,1996 (Act No. 43 of 1996); and

f) The Rules and Codes issued by the Energy Regulator in terms of the relevant sections

of the Electricity Regulation Act, 2006 (Act No. 4 of 2006).

1.5.1 Electricity Regulation Act, 2006 (Act No. 4 of 2006) (‘the Act’)

In terms of section 4(a)(v) of the Act, the Energy Regulator must establish and manage

monitoring and information systems and a national information system, and coordinate the

integration thereof with other relevant information systems.

In terms of Section 9(4)(b), ‘the Regulator may make registration [made in terms of Section

9(1)] be subject to conditions relating to the supply of information to the Regulator, the

dissemination of information to customers or end users,…’


In terms of Section 14(1) of the Act:

the Regulator may make any licence subject to conditions relating to:

(b) the furnishing of information, documents and details that the Regulator may

require for the purposes of this Act;

(i) the setting, approving and meeting of performance improvement targets, including

the monitoring thereof through certificates of performance;

(j) the quality of electricity supply and service;

(s) compliance with health, safety and environmental standards and requirements;

(u) compliance with energy efficiency standards and requirements, including demand-

side management

It is implied by Section 14(1) that the licensee must provide the specified information to the

Energy Regulator in order to for the Energy Regulator to monitor compliance.

In terms of Section 33 (1) of the Act: for the purposes of this Act, any person authorised thereto in writing by the Regulator

may:

(a) at all reasonable times enter any property on which any activity relating to the

supply of electricity is taking place to inspect any facility, equipment, machinery,

book, account or other document relating to electricity found thereat; and

(b) require any person to furnish to the Regulator such information, returns or other

particulars as may be necessary for the proper application of this Act.”

In terms of Section 33 (2), of the Act ‘the Regulator may require that the accuracy of any

information, return or particular furnished under subsection 33 (1) be verified on oath or by way

of solemn declaration’.

In terms of Section 35 (3) of the Act, the Regulator may, after consultation, issue rules that may

relate to:

(a) the keeping of information, the rendering of returns and the period for and format in

which information must be kept, as well as the persons or institutions it must be

rendered to;

(b) standards of quality of supply and service;

(c) the operation, use and maintenance of transmission and distribution power systems;


1.5.2 Information Required for Collection of Levies

In terms of Section 5B of the Electricity Act of 1987, the Minister may

‘… by notice in the Gazette prescribe licence fees that are payable by licensed generators of

electricity,… payable in respect of the electricity, calculated in kilowatt hours, generated for

supply by any licensee concerned during the previous calendar year ’.

1.5.3 Regulations issued by the Minister in terms of the Act

In terms of Regulation 4 (3), the Regulator shall, after consultation with the Minister, the system

operator and the National Transmission Company (NTC), make rules relating to the keeping of

relevant information, the submission of such information and the rendering of returns by

licensees, as required in order to facilitate integrated resource planning.

1.5.4 NERSA Rules and Codes Issued in terms of the Act

NERSA has over time issued various documents, in terms of the relevant sections of the Act,

specifying some of the information requirements to be submitted by the licensees. These

documents include:

a) The Multi Year Price Determination (MYPD) Methodology;

b) The Cost Recovery Mechanism; and

c) Transmission and Distribution Grid Code.

1.5.5 The National Energy Regulator Act on the Functions of the Regulator

In terms of Section 4 (b) of National Energy Regulator Act, 2004 (Act No. 40 of 2004), the

Energy Regulator must ‘undertake the functions set out in section 4 of the Act’.

In terms of Sections 4 of the Act, (on the powers and duties of the Energy Regulator) the

Regulator-

(a) must-

(i) consider applications for licenses and may issue licences for-

(aa) the operation of generation, transmission or distribution facilities;

(bb) the import and export of electricity;

(cc) trading;

(ii) regulate prices and tariffs;

(iii) register persons who are required to register with the Regulator where they are

not required to hold a licence;

(iv)issue rules designed to implement the national government's electricity policy

framework, the integrated resource plan and this Act;


(v) establish and manage monitoring and information systems and a national

information system, and co-ordinate the integration thereof with other relevant

information systems;

(vii) enforce performance and compliance, and take appropriate steps in the case of

non-performance;

(b) may-

(i) mediate disputes between generators, transmitters, distributors, customers or end

users;

(ii) undertake investigations and inquiries into the activities of licensees;

(iii) perform any other act incidental to its functions.

1.5.6 Licence issued to Generators (Eskom)

In terms of condition 7 of the issued electricity generation licence, - Collection and exchange of

information-

The NER shall be entitled to collect such information from the licensee or its customers,

as it deems necessary.

1.5.7 Licence issued to Generators (IPPs)

In terms of condition 10.1 of the issued electricity generation licence, - Provision of information-

The licensee shall maintain records of the operation of the Generation Facility and

provide, in the manner and form prescribed by NERSA, such information and

documents as NERSA may require from time to time for the purpose of performing

functions assigned or transferred to it under the law. Records shall include but not

limited to Regulatory Reporting Manuals (RRMs) and generation performance reports.

1.5.8 Licence issued to Transmitters

In terms of condition 7 of the issued electricity transmission licence, - Collection and exchange

of information-

The NER shall be entitled to collect such information from the licensee or its customers,

as it deems necessary.

1.5.9 Licence issued to Distributors

In terms of condition 5.4.1 of the issued electricity distribution licence, - General conditions- The National Electricity Regulator shall be entitled to collect such information from the

licensee or its customers as it deems necessary

1.5.10 Summary Table of Some of the Legislative Provisions

to


Section of ERA or Regulations Gx Tx Dx 4(a)

In terms of section 4(a)(v) of the Act, the Energy Regulator must establish and manage monitoring and information systems and a national information system, and coordinate the integration thereof with other relevant information systems

Yes

Yes Yes

9(4)(b)

9((1) Relates to persons required to be registered - the Minister may, in consultation with the Regulator, determine by notice in the Gazette that any person involved in an activity relating to trading or the generation, transmission or distribution 9(4) relates to information to be supplied by those registered in terms of 9(1)

N/A

N/A N/A

14(1)

The Regulator may make any licence subject to conditions relating to: (b) the furnishing of information, documents and details that the Regulator may require for the purposes of this Act.

Yes

Yes Yes

(i) the setting, approving and meeting of performance improvement targets, including the monitoring thereof through certificates of performance Yes Yes Yes

(j) the quality of electricity supply and service Yes Yes Yes (s) compliance with health, safety and environmental standards and requirements; Yes Yes Yes (u) compliance with energy efficiency standards and requirements, including demand-side management Yes Yes Yes 33(1)/2 Inspection/Audit Requirement Yes Yes Yes

35(3)

The Regulator may, after consultation, issue rules that may relate to: (a) the keeping of information, the rendering of returns and the period for and format in which information must be kept, as well as the persons or institutions it must be rendered to;

Yes

Yes Yes

(b) standards of quality of supply and service; N/A Yes Yes (c) the operation, use and maintenance of transmission and distribution power systems; N/A Yes Yes 5B of EA1987

The Minister may…by notice in the Gazette prescribe licence fees that are payable by licensed generators of electricity,…payable in respect of the electricity, calculated in kilowatt hours, generated for supply by any licensee concerned during the previous calendar year

Yes

N/A N/A

Reg 4(3)

The Regulator shall, after consultation with the Minister, the system operator and the National Transmission Company (NTC), makes rules relating to the keeping of relevant information, the submission of such information and the rendering of returns by licensees, as required in order to facilitate integrated resource planning

Yes

N/A N/A


1.6 Purpose of the Non-Financial Information (NFI) Manual

The purpose of this NFI Manual is to prescribe and provide guidance to licensees in order to

achieve uniformity in collection, recording and calculation, consistent and regular in preparing

and reporting of non-financial information required by the Energy Regulator to perform its

functions that are stated in Section 1.5.5 above.

Application of this NFI Manual will assist in bringing certainty to non-financial information

regulatory reporting requirements, provide an adequate information base required by the Energy

Regulator, improve transparency in the regulatory process and enhance regulatory efficiency.

It is important to note that this NFI Manual does not replace current collection tools e.g. D-Forms.

The two are complementary. This NFI Manual explains the information to be collected whereas

the D-Forms is the collection tool of that non-financial information prescribed in the NFI Manual.

The D-Forms will be amended to only collect information prescribed in this NFI Manual. Hence

financial information will be removed from the NFI D-Forms because the financial information is

collected as prescribed by RRM Volume 2 for Regulatory Financial Reporting.

1.7 Applicability of NFI Manual

NFI Manual applies to all Electricity Supply Industry entities regulated by NERSA. In this regard,

the NFI is designed for use by:

a) each electricity regulated entity1;

b) any person appointed by the Energy Regulator to conduct the verifications/inspections

envisaged by the Act; and

c) NERSA regulatory staff.

1.8 Disclaimer

Submission of information prescribed in the NFI Manual does not necessarily imply the adequacy

of such information to enable the Energy Regulator to take a decision.

Although the use of this NFI Manual is expected to lead to more complete/comprehensive

submissions of the required NFI, there will still be certain well-justified circumstances when

additional information would be required in order to fully clarify a specific aspect of a matter

under consideration by the Energy Regulator.

1 Electricity Regulated Entities include Electricity Resellers. Currently there is no approved framework of regulating Electricity Resellers. After the approval of the said framework, the Electricity Resellers will be required to comply with the NFI Manual.


2 NFI Categories

The required information has been grouped into two categories, namely static (initial) data and

dynamic data.

2.1 Static information

Static information is the NFI that has already been collected by NERSA (once off) from the

licensees at the time of licence application.

Licensees should therefore note that, after licensing, static information will not be collected again

while it remains unchanged from what was originally submitted.

The static information section is included in this Manual in order to amalgamate all NFI

required/used or in the possession of NERSA into one point of reference. This amalgamation

makes the Manual a complete single source of reference of NFI in order to engender regulatory

efficiency for all the users of the NFI Manual identified in section 1.7 of this Manual.

2.2 Dynamic information

Dynamic information is the NFI that changes more regularly while the licensee is in operation

Dynamic information will be collected from the licensees periodically such as; daily, weekly,

monthly, quarterly, annually or on the licence anniversary date, as the case may be. The dynamic

information is the core of the NFI Manual.

The NFI dynamic information submitted by the licensees will form the basis from which the

Energy Regulator will derive the performance and compliance monitoring metrics illustrated by

way of examples in the later parts of this NFI Manual.

3 Measurements/Calculations

3.1 Units of measurement

The units of measurement shall be metric.

3.2 Measurements and calculations

This section defines the information or items which are subject to different interpretations of

measurement approaches to enable NERSA and the regulated industries to adopt a standard

measure.


The items whose manner of measurement is defined here are drawn from those required to be

reported as per Sections 9 to 14 of this Manual.

The items and the standard measurement approach to be adopted are as follows:

1 Electricity consumption (Energy use) = The total amount of electricity consumed over a

period of time. Consumption determines demand and demand is the rate at which electricity

is being used at any one given time or for a time period. Consumption is usually measured

in kilowatt-hours (kWh = Kilowatts X hours of use), while electricity demand is measured in

kilowatt hours.

2 Performance/utilisation, utility plant:

2.1 Unplanned capability load factor (UCLF) Unplanned capability loss factor (UCLF) is

defined as the ratio of the unplanned energy losses during a given period of time, to the

nominal energy for the same period, expressed as a percentage. Unplanned unavailable

energy effectively is energy that was not produced during the period due to unplanned

plant unavailability (unplanned shutdowns, outage extensions, or load reductions due to

causes under plant management control). Causes of energy losses are considered to be

unplanned if they are not scheduled at least four weeks (28 days) in advance.

The unplanned capability loss factor is determined for each period as follows:

UCLF (%) = UEL x 100 NE

Where:

• UEL = Total unplanned energy losses (MWh) for the period

• NE = Nominal energy (MWh) for the period

Also:

Where:

Unplanned Energy Loss (UEL) = (UPL x HRU)

• UPL = Unplanned capacity loss or capacity decrease in megawatts due to an

unplanned event

• HRU = Hours operated at reduced power (or shutdown) due to the unplanned event

2.2 Energy Availability Factor (EAF) = 1 - Planned Capability Load Factor (PCLF) – Un-

planned Capability Load Factor (UCLF) - Other Capability Load Factor (OCLF)

2.3 Partial Load Loss (PLL) % = PLL energy / Nominal energy x 100

3 Expected Available Reserves at Evening Peak(MW) = “Available Generation (including

OCGT’s)” – “Evening peak forecast” + “MW Returning” – “MW going off” as determined at

6am on weekday excluding public holidays.


4 Energy Losses within the system:

4.1 Energy Input (kWh) = Total Energy Sales (kWh) + Total Energy Losses (kWh).

4.2 Total Energy Loss (kWh) = Non-Technical losses (kWh) + Technical losses (kWh).

4.3 Technical Losses (kWh) = Energy Input (Technical Loss factor −1)

4.4 Technical Loss factor = factor which links energy sales, energy input and Technical

Losses

4 Responsibility for NFI Submission and Solemn Declaration

The NFI must be submitted to the Energy Regulator by a responsible official appointed from time

to time and duly authorised by the licensee to submit this information to the Energy Regulator.

The Energy Regulator may require that this duly authorised responsible official verify the

accuracy of the NFI being submitted by way of oath/solemn declaration.

The NFI must be submitted electronically or any other format agreed upon between the Energy

Regulator and the licensee.

5 Records Keeping

Each regulated entity must keep records supported by detailed information as will permit ready

identification, examination, analysis and verification of all facts thereto.

The records shall be kept in such a manner as to be readily accessible for examination by

authorised representatives of the Energy Regulator.

These records must be retained by the licensee for at least five years or as per National Archives

of South Africa Act,1996 (Act No. 43 of 1996).

6 Audit of NFI

Section 33 of the Electricity Regulation Act, 2006 (Act No. 4 of 2006) grants any person

authorised by the Energy Regulator in writing right of entry to inspect, among others, books,

account or other document relating to the regulated entity found thereat. Furthermore, the

Energy Regulator may require any person to furnish to the Regulator such information, returns

or other particulars as may be necessary for the proper application of this Act.

The Energy Regulator may audit the NFI submitted by the licensee for its accuracy.


7 Publication and Confidentiality

The Energy Regulator will publish the non-financial information submitted by the licensees on

the its website, but such publication will exclude information determined to be confidential as

contemplated in Sections 10 (2) of the National Energy Regulator Act, 2004 (Act No. 40 of 2004).

It is the responsibility of the regulated entity to promptly notify the Energy Regulator of

information that should not be in the public domain by clearly marking the relevant information

as such.

Regulated entities are also encouraged to publish the non-confidential NFI on their respective

websites.

The Energy Regulator shall only share the publicly available NFI with any person as defined in

the Promotion of Access to Information Act, 2000 (Act No. 2 of 2000)

8 Effective Date and Implementation Costs of the NFI Manual

The implementation phase will be for a period of at least three years starting from 01 April 2016.

This 3 (three) year period is to enable the licensees to prepare, transition and start reporting

according to this NFI Manual for all non-financial information submitted to NERSA.

The Energy Regulator may also approve a phased implementation to provide for any other

justifiable circumstances that may warrant such an approach. Licensees are required to make

appropriate arrangements to comply with the prescript and guidance contained in this NFI Manual.

Costs related to reporting in accordance with this NFI Manual should be treated in a similar manner

and recovered in similar way as the licensee’s other operating and maintenance expenses for the

licensed activity.

Licensees are allowed to report on the NFI using Ms Excel spreadsheet for a period of at least 3

years (implementation phase) and thereafter the ER may consider using an automated system.


9 Review and Modification of the NFI Manual

The Energy Regulator will conduct an initial review of the NFI Manual after 3 years from the

effective date (1 April 2016).

Subsequent reviews will be done every five years to ensure that the contents of the NFI Manual

reflect the legislative and regulatory circumstances existing at the time of the review.

The Energy Regulator also recognises that special circumstances may arise that may

necessitate ongoing changes, perhaps more frequently than the envisaged five years formal

review cycle. This provision would therefore not preclude on-going incorporation by the Energy

Regulator of justifiable changes that are considered necessary to immediately capture clarity,

transparency and regulatory efficiency benefits.

The Energy Regulator will give decisions on the interpretation of the various clauses of NFI, but

any party will be entitled at any stage to take decisions of the Energy Regulator on review or

appeal as contemplated in the enabling legislations.


Eskom NFI Required Information

(Generation, Transmission & Distribution)


10 Eskom Generation Facilities NFI Required and Submission Timeframes

10.1 Eskom Generation Facilities Static NFI

Note: As already stated above, all static information is only to be collected at the time of a licence

application, meaning that it will not be collected by NERSA again, unless there are changes.

10.1.1 Eskom Static NFI

Information Required Purpose (NERSA use)

Reporting Frequency

Report Due Date

Licensee name Identification Whenever changed N/A

Contact person Identification Whenever changed N/A

Designation Identification Whenever changed N/A

Tel no. Identification Whenever changed N/A

Fax no. Identification Whenever changed N/A

Email address Identification Whenever changed N/A

Postal address Identification Whenever changed N/A

Physical address Identification Whenever changed N/A

10.1.2 Eskom Generation Facilities Static NFI


Reporting Frequency

Report Due Date

Power station name Identification Once off on application

N/A

Licence no. Identification Once off on application

N/A

Date licensed Identification Once off on application

N/A

NERSA licence decision ref. no. Identification Once off on application

N/A

Plant model (single line diagram) Identification Once off on application

N/A

Facility geographic location (GPS)

Identification Once off on application

N/A

Area (Town and Province) Identification Once off on application

N/A

Licensed facility capacity Identification Once off on application

N/A

Technology Identification Once off on application

N/A

Date of each unit coming into commercial operation


N/A

Number of units in operation Identification Once off on application

N/A

Network connection voltage Identification Once off on application

N/A


10.2 Eskom Generation Facilities Dynamic NFI

10.2.1 Production NFI for Total Eskom Generation System


Reporting Frequency

Report Due Date

Total Installed Capacity (MW)

Monitoring security of supply

Annually FY end + 4 months*

Capacity under Construction (MW) & expected COD



Net capacity (MW) Monitoring security of supply


Capacity of commissioned units per annum (MW)



UCLF (%) Monitoring security of supply


PCLF (%) Monitoring security of supply


EAF (%) Monitoring security of supply


Load factor (%) Monitoring security of supply


PLL (%) Monitoring security of supply


Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months*

Total Energy sent out (GWh) Monitoring security of supply


Total OCGTs energy sent out (MWh)



*within four (4) months of the licensee's financial year end

10.2.2 Eskom Production NFI per Power Station

10.2.2.1 Eskom Production NFI for each Coal Power Station


Reporting Frequency

Report Due Date

Volume generated (gross) (GWh)

Monitoring security of supply & levies


Auxiliary consumption (own use) (GWh)



Volume sent out (GWh) Monitoring security of supply & levies


Partial load losses (GWh) Monitoring security of supply & levies

Annually FY end + 4 months

Installed capacity (MW) at year end



Capacity under construction (MW) & expected COD



Net capacity (MW) at year end





Reporting Frequency

Report Due Date

UCLF (%) Monitoring security of supply & levies


PCLF (%) Monitoring security of supply & levies


EAF (%) Monitoring security of supply & levies


PLL (%) Monitoring security of supply & levies



Thermal efficiency Efficiency Annually FY end + 4 months*


10.2.2.2 Eskom Production NFI for each Nuclear Power Station


Reporting Frequency

Report Due Date

Volume generated (gross) (MWh)



Auxiliary consumption (own use) (MWh)



Volume sent out (MW) Monitoring security of supply & levies


Partial load losses (MWh) Monitoring security of supply & levies


Installed capacity (MW) as at year end






Net capacity (MW) as at year end














10.2.2.3 Eskom Production NFI for each Hydro Power Station (include small Hydro)


Reporting Frequency

Report Due Date







Volume sent out (MWh) Monitoring security of supply & levies


Partial load losses % Monitoring security of supply & levies


Installed capacity (MW) Monitoring security of supply & levies
















Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months* *within (4) months of the licensee's financial year end

10.2.2.4 Eskom Production NFI for each Pumped Storage Hydro Power Station

Information Required Purpose

(NERSA use) Reporting Frequency

Report Due Date




Consumption during pump mode (MWh)





Partial load losses (%) Monitoring security of supply & levies







Net capacity (MW) Monitoring security of supply & levies











*within (4) months of the licensee's financial year end


10.2.2.5 Eskom Production NFI for each Gas/Diesel Power Station


Reporting Frequency

Report Due Date


























Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months* Thermal efficiency Efficiency Annually FY end + 4 months*


10.2.2.6 Eskom Production NFI for each Renewable Energy Power Station


Reporting Frequency

Report Due Date

Forecasted Volume generated (MWh)

Capacity Annually FY end + 4 months

Actual Volume generated (MWh)

Capacity & levies Annually FY end + 4 months

Forecasted Availability** (MW)

Capacity & efficiency Annually FY end + 4 months

Actual Availability **(MW) at year end

Capacity & levies Annually FY end + 4 months


Capacity Annually FY end + 4 months

Volume sent out (MWh) Capacity Annually FY end + 4 months* Installed (rated) capacity (MW) at year end

Capacity & efficiency Annually FY end + 4 months*


Capacity & efficiency Annually FY end + 4 months*


Capacity & efficiency Annually FY end + 4 months

UCLF (%) Capacity & efficiency Annually FY end + 4 months



Reporting Frequency

Report Due Date

PCLF (%) Capacity & efficiency Annually FY end + 4 months

EAF (%) Capacity & efficiency Annually FY end + 4 months

Capacity factor (%) Capacity & efficiency Annually FY end + 4 months


* within four (4) months of the licensee's financial year end ** The “Availability” is defined as the capacity available to operate at the facility at any given time. The parameters for energy production should be measured hourly.

10.2.3 Eskom Primary Energy NFI

10.2.3.1 Eskom Primary Energy NFI for each Coal Power Station


Reporting Frequency

Report Due Date

Calorific value (kJ/kg) Resource planning Annually FY end + 4 months*

Fuel volume purchased (ton)

Resource planning Annually FY end + 4 months*

Fuel volume used (ton) Resource planning Annually FY end + 4 months*

Water volume used (kL) Resource planning Annually FY end + 4 months*

Stock holding (ton) ** Security of supply Annually FY end + 4 months*

Stock holding (per running days)**

Security of supply Annually FY end + 4 months*

*within four (4) months of the licensee's financial year end **Stock of primary fuel type in terms of volume used per annual relevant to running times

10.2.3.2 Eskom Primary Energy NFI for Nuclear Power Station


Reporting Frequency

Report Due Date

No. of refuelling outages completed in past financial year.


Fuel volume purchased in past financial year (no. of fuel assemblies)


No. of fuel assemblies discharged during past financial year.


Water volume used (kL) Resource planning Annually FY end + 4 months* *within four (4) months of the licensee's financial year end

10.2.3.3 Eskom Primary Energy NFI for Hydro Power Station (including small Hydro)


Reporting Frequency

Report Due Date




10.2.3.4 Eskom Primary Energy NFI for each Pumped Storage Hydro Power Station


Reporting Frequency

Report Due Date



10.2.3.5 Eskom Primary Energy NFI for each Diesel Power Station


Reporting Frequency

Report Due Date

Calorific value (kJ/mᶟ) Resource planning Annually FY end + 4 months*

Fuel volume purchased (kL)


Fuel volume used (kL) Resource planning Annually FY end + 4 months*


Stock holding (kL) Security of supply Annually FY end + 4 months*

Stock holding (per running hours)



10.2.4 Eskom Primary Energy NFI for Renewable Energy Power Station (Wind, Solar PV, CSP)



Report Due Date

Resource data measured** Resource planning Annually FY end + 4 moths* *within one (1) month after end of the licensee's quarter end within financial year **Resource data must be comma-delimited text or MS Excel format and must include measured weather parameters affecting energy yield

10.2.5 Eskom Environmental NFI for each Coal Generation Power Station


Reporting Frequency

Report Due Date

Specific water usage (L/kWh)

Compliance & efficiency Annually FY end + 4 months*

Relative Particulate Emissions (kg/MWh)




11 Eskom Transmission Facilities NFI Required and Submission Timeframes

11.1 Eskom Transmission Facilities Static NFI



11.1.1 Eskom Transmission Static NFI


Reporting Frequency Report Due Date









11.1.2 Eskom Transmission Static NFI



Licensed facility name Identification Once off on application N/A

Licence no. Identification Once off on application N/A

Date licensed Identification Once off on application N/A

NERSA licence decision ref. no. Identification Once off on application N/A

Facility diagram (single line diagram) depicted on a map

Identification Once off on application N/A

Off-take and end (or delivery) points of licenced facility



11.2 Eskom Transmission Facilities Dynamic NFI

11.2.1 Eskom Transmission Substation Information


Reporting Frequency

Report Due Date

Number of Substations Input Voltage of <66kV

Identification & Regulatory Asset Base Annually FY end + 4 months*

Number of Substations Input Voltage of 66kV







Identification & Regulatory Asset Base









11.2.2 Eskom Transformer Installed Capacity Information


Reporting Frequency

Report Due Date

Installed transformer capacity with input voltage of <66kV (MVA)



Installed transformer capacity with input voltage of 66kV (MVA)









Installed transformer capacity with input voltage of 220 kV (MVA)














11.2.3 Eskom Transmission Lines Information


Reporting Frequency

Report Due Date

Length of transmission line <66kV (km)



Length of transmission line 66kV (km)






















11.2.4 Eskom Transmission Volumes Information


Reporting Frequency

Report Due Date

Power purchases from Eskom generators (GWh)

Capacity, efficiency and IRP


Power purchases from non- Eskom generators (i.e. IPPs and others) (GWh)



Imported volumes: Transmission imports (includes Transmission supply, wheel and withdraw volumes) (GWh)



Exported volumes: Includes Transmission exports and demand wheel and withdraw volumes (GWh)



Total distribution purchases: includes Distribution losses, Local purchases and purchases for own use. (GWh)



Volume sent out: Gx sent out, IPPs and Dx generation (GWh)



Gx Pumping volumes (GWh)



Transmission technical losses (GWh)





Reporting Frequency

Report Due Date

Annual Energy Wheel and Production Plan (GWh)



Annual Transmission Developmental Plan




11.2.5 Ancillary Services


Reporting Frequency

Report Due Date

Demand Market Participation (DMP) Instantaneous MW used

Monitoring Annually FY end + 4 months*

DMP Supplemental MW used


DMP Instantaneous MWh used


DMP Supplemental MWh used


Interruptible loads: MW interrupted, MW


Interruptible loads: energy interrupted, MWh



11.2.6 Eskom Transmission Service Quality Incentive


Reporting Frequency

Report Due Date

System Minutes <1 Service Quality Incentive (SQI)


Major incidents Service Quality Incentive (SQI)


Line Faults per 100km Service Quality Incentive (SQI)



11.2.7 Eskom Transmission Quality of Supply


Reporting Frequency

Report Due Date

Quality of Supply Report* including the following: • Voltage Regulation

• Voltage unbalance

• Total Harmonic Distortion

(THD) • Voltage Dips

Security of supply Annually FY end + 4 months**

*The Quality of Supply Report will take the format prescribed by the Power Quality Directive **within four (4) months of the licensee's financial year end


11.2.8 System Operations


Reporting Frequency

Report Due Date

Expected available reserve at evening peak


Daily Daily

System Morning Report Monitoring security of supply

Daily Daily (week days excluding public holidays)

System Status Report Monitoring security of supply

Twice a day Twice a day on week days excluding public holidays


12 Eskom Distribution Facility NFI Required and Submission Timeframes

12.1 Eskom Distribution Static NFI



12.1.1 Eskom Distribution Static NFI


Reporting Frequency

Report Due Date









12.1.2 Eskom Distribution Facility Static NFI


Reporting Frequency

Report Due Date

Licensee/Licensed facility name Identification Once off on application

N/A


N/A


N/A


N/A

List of areas (Licensed supply areas) Identification Once off on application

N/A

Supply Area(s) Geographic Positioning System (GPS) Co- ordinates & relevant polygon


N/A

Length of distribution line, MV & HV (km)

Identification, asset base

Once off on application

N/A

Length of distribution line, LV (km) Identification & asset base


N/A


12.2 Eskom Distribution Facility Dynamic NFI

12.2.1 Eskom Distribution Facility NFI


Reporting Frequency

Report Due Date

Estimated length of distribution line, MV & HV (km)

Identification & asset base


Estimated length of distribution line, LV (km)



Number of transformers with input voltage of > 1 kV to <11kV



Number of transformers with input voltage ≥ 11kV to ≤ 22kV



Number of transformers with input voltage > 22 kV to < 44 kV



Number of transformers with input voltage: ≥ 44 kV to ≤ 132kV



Licensee installed transformers capacity of above categories (kVA)




12.2.2 Eskom Distribution Estimated System Losses


Reporting Frequency

Report Due Date

Estimated Technical losses (as percentage of Energy Input)**

Compliance Annually FY end + 4 months*

Estimated Non-Technical losses (as percentage of Energy Input)**


*within four (4) months of the licensee's financial year end ** Using appropriate equation, the technical losses shall be estimated using the Loss Factors

Classification Table, unless the utility is able to justify the use of alternative Loss Factors. Or alternatively, Loss Factors may be determined by carrying out load flow studies on sample networks. There are a number of load flow study tools in the market. licensee can use the tool accessible to them. ** Energy Input (kWh) = Total Energy Sales (kWh) + Total Energy Losses (kWh). ** Total Energy Loss (kWh) = Non-Technical Losses (kWh) + Technical Losses (kWh). **Licensee must also explain its methodology in estimating or deriving the Technical and Non- Technical Losses.

12.2.3 Eskom Electrification Information (INEP Funded)


Reporting Frequency

Report Due Date

INEP Report on electrification** Licensing, tariff & asset base


*within four (4) months of the licensee's financial year end. **as reported to DoE


12.2.4 Eskom Energy Efficiency & Demand Side Management (EEDSM)


Reporting Frequency

Report Due Date

EEDSM Annual Report including the following: • Verified Annual Energy

savings per technology • Verified Demand savings per

technology • Load Factor per technology

• Avoided system cost per

technology


EEDSM Measurement & Verification (M&V) Report including the following: • Verified Annual Energy


technology



12.2.5 Eskom Distribution Quality of Service



System Average Interruption Duration Index (SAIDI)


System Average Interruption Frequency Index (SAIFI)


Distribution Supply Loss Index (DSLI)2


Report on Quality of service including the following


• Providing Quotations to consumers


• Providing Supply to consumers


• Credit meter readings for residential and small business consumers of electricity


2 SAIDI, SAIFI and DSLI performance report will include performance with and without load shedding. The Service Quality Incentive (SQI) information will continue to be treated separately according to the rules of the SQI Scheme.




• Credit meter readings for consumers consuming more than 50KVA


• Disconnections & reconnections (Credit meter consumers, Commercial / industrial consumers, Prepayment meter consumers)


• Prepayment Vending Stations & Meter accuracy queries


• Fault Reporting Centres per number within the licensee area


• Restoration of Supply after a forced interruption


• Planned Interruptions on Overhead & Underground Networks


• Type and number of Complaints


• Time to resolve Customer Complaints, Enquiries and Requests



12.2.6 Eskom Distribution Quality of Supply


Reporting Frequency

Report Due Date

Quality of Supply Report including the following: • MV and HV Regulation


• Total Harmonics

Distortion (THD) • Voltage Dips




Independent Power Producers (IPP) NFI Required Information

(Generation & Distribution Connection Facilities)


13 IPP Facilities NFI Required and Submission Timeframes

13.1 IPP Facilities Static NFI



13.1.1 Licensee Static NFI


Reporting Frequency

Report Due Date









13.1.2 IPP Facilities Static NFI


Reporting Frequency

Report Due Date

Power station name Identification Once off on application

N/A


N/A


N/A


N/A

Plant model (single line diagram) Identification Once off on application

N/A

Facility geographic location (GPS)


N/A

Area (Town or Province) Identification Once off on application

N/A

Licensed facility capacity Identification Once off on application

N/A

Technology Identification Once off on application

N/A

Date of each unit coming into commercial operation


N/A

Number of units in operation Identification Once off on application

N/A

Network connection voltage (kV) Identification Once off on application

N/A


13.2 IPP Facilities Dynamic NFI

13.2.1 Production NFI for an IPP Facility


Reporting Frequency

Report Due Date

Installed Capacity (MW) Monitoring security of supply

Annually FY end + 4months*

Capacity under Construction (MW) & expected COD



Net capacity (MW) Monitoring security of supply


UCLF (%) Monitoring security of supply


PCLF (%) Monitoring security of supply


EAF (%) Monitoring security of supply


Load factor (%) Monitoring security of supply


PLL (%) Monitoring security of supply




Energy sent out (MWh) Monitoring security of supply



13.2.2 IPP Production NFI per Power Station

13.2.2.1 IPP Production NFI for Coal Power Station


Reporting Frequency

Report Due Date










Daily/Monthly Daily/Monthly

Installed capacity (MW) at year end






Net capacity (MW) at year end









Reporting Frequency

Report Due Date







*within four (4) months respectively of the licensee's financial year end

13.2.2.2 IPP Production NFI for Hydro Power Station (including small Hydro)


Reporting Frequency

Report Due Date









Partial load losses (%) Monitoring security of supply & levies


















Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months* *within four (4) months respectively of the licensee's financial year end

13.2.2.3 IPP Production NFI for Gas/Diesel Power Station


Reporting Frequency

Report Due Date















Reporting Frequency

Report Due Date
















*within four (4) months respectively of the licensee's financial year end

13.2.2.4 IPP Production NFI for Renewable Energy Power Station


Reporting Frequency

Report Due Date

Forecasted Volume generated (MWh)

Capacity & levies Monthly Monthly

Actual Volume generated (MWh)


Forecasted Availability** (MW)


Actual Availability** (MW) at year end




Volumes sent out (MWh) Capacity & efficiency


Installed (rated) capacity (MW) at year end

Capacity & efficiency







Quarterly Quarterly

UCLF (%) Capacity & efficiency

Quarterly Quarterly

PCLF (%) Capacity & efficiency

Quarterly Quarterly

EAF (%) Capacity & efficiency

Quarterly Quarterly

Capacity factor (%) Capacity & efficiency

Quarterly Quarterly

Unit trips (UAGS/7000) Capacity & efficiency




13.2.3 IPP Primary Energy NFI

13.2.3.1 IPP Primary Energy NFI for Coal Power Station


Reporting Frequency

Report Due Date

Calorific value (kJ/kg) Resource planning Annually FY end + 4 months*

Fuel volume purchased (ton)


Fuel volume used (ton) Resource planning Annually FY end + 4 months*


Stock holding (ton)** Security of supply Annually FY end + 4 months*

Stock holding (per running days)**



13.2.3.2 IPP Primary Energy NFI for Hydro Power Station


Reporting Frequency

Report Due Date



13.2.3.3 IPP Primary Energy NFI for Diesel Power Station


Reporting Frequency

Report Due Date

Calorific value (kJ/ mᶟ) Resource planning Annually FY end + 4 months*

Fuel volume purchased (kL)


Fuel volume used (kL) Resource planning Annually FY end + 4 months*


Stock holding** (kL) Security of supply Annually FY end + 4 months*

Stock holding (per running hours)



13.2.3.4 IPP Primary Energy NFI for Natural Gas or LNG Power Station


Reporting Frequency

Report Due Date


Fuel volume purchased (mᶟ)




Reporting Frequency

Report Due Date

Fuel volume used (mᶟ) Resource planning Annually FY end + 4 months*


Stock holding (mᶟ) ** Security of supply Annually FY end + 4 months*

Stock holding (per running days/hours)**


*within four (4) months of the licensee's financial year end **Stockpile of primary fuel type in terms of volume used per annual relevant to running times. The volumes should be at standard temperature (15 degrees Celsius)

13.2.4 IPP Primary Energy NFI for Renewable Energy Power Station (Wind, Solar PV, Solar CSP)



Report Due Date

Resource data measured** Resource planning Quarterly FY end +4 months* *within four (4) months of the licensee's financial year quarter end **Resource data must be comma-delimited text or MS Excel format and must include measured weather parameters affecting energy yield

13.2.5 IPP Primary Energy NFI for Renewable Energy Power Station (Biomass or Biogas)


Reporting Frequency

Report Due Date


Fuel volume used (mᶟ) Resource planning Annually FY end + 4 months*

Auxiliary fuel type (mᶟ) Resource planning Annually FY end + 4 months*

Auxiliary fuel volume used (mᶟ)



Stock holding (mᶟ) ** Security of supply Annually FY end + 4 months*

Stock holding (per running days/hours)**


*within four (4) months of the licensee's financial year quarter end

13.2.6 IPP Environmental NFI for Generation Power Station


Reporting Frequency

Report Due Date

Specific water usage (L/kWh) Compliance & efficiency Annually FY end + 4 months*

Relative Particulate Emissions (kg/MWh)




14 IPP Distribution Connection Facilities NFI Required and Submission Timeframes

14.1 IPP Distribution Connection Facilities Static NFI

Note: The collection of this NFI is for licensed Distribution Connection Facilities build under

Build Own and Operate (BOO) option. As already stated, all static information is only to be

collected at the time of a licence application, meaning that it will not be collected by NERSA

again, unless there are changes.

14.1.1 IPP Distribution Connection Facility Licensee Static NFI











14.1.2 IPP Distribution Licensed Facilities Static NFI



Licensee/Licensed facility name Identification Once off on application N/A Licence no. Identification Once off on application N/A

Date licensed Identification Once off on application N/A

NERSA licence decision ref. no. Identification Once off on application N/A

Plant model (single line diagram) Identification Once off on application N/A

Generation Facility geographic location (GPS Co-ordinates)


IPP Connection facility COD Identification Once off on application N/A

Length in km of distribution connection line including kV (IPP Connection facilities)


Once off on application N/A

Delivery Point (point or substation name and owners name)


List of Third parties connected to the distribution line



Municipalities & Private Distributors NFI Required Information

(Distribution Only)


15 Municipality or Private Distributor Distribution Facilities NFI Required and Submission Timeframes

15.1 Distribution Facilities Static NFI



15.1.1 Distribution Licensee Static NFI











15.1.2 Distribution Licensed Facilities Static NFI


Reporting Frequency

Report Due Date

Licensee/Licensed facility name Identification Once off on application

N/A


N/A


N/A


N/A

List of areas (Licensed supply areas) Identification Once off on application

N/A

Supply Area(s) Geographic Positioning System (GPS) Co- ordinates & relevant polygon


N/A

Length of distribution line, MV & HV (km)

Identification, asset base & efficiency benchmarking


N/A

Length of distribution line, LV (km) Identification & asset base


N/A


15.2 Distribution Facilities Dynamic NFI

15.2.1 Distribution Facility NFI


Reporting Frequency

Report Due Date

Notified Maximum Demand (NMD) per area of supply (MVA)

IRP Annually FY end + 4 months*

Number of substations by kV (≥11kV) Identification & asset base


Estimated length of distribution line, MV & HV (km)



Estimated length of distribution line, LV (km)



Number of transformers with input voltage: > 1 kV to ˂ 11 kV




Number of transformers with input voltage > 22 kV to ≤ 44 kV






Licensee installed transformers capacity of above categories (kVA)




15.2.2 Distribution System Losses


Reporting Frequency

Report Due Date

Estimated Technical losses (as percentage of Energy Input)**


Estimated Non-Technical losses (as percentage of Energy Input)**


*within four (4) months of the licensee's financial year end ** Using appropriate equation, the technical losses shall be estimated using the Loss Factors Classification Table, unless the utility is able to justify the use of alternative Loss Factors. Or alternatively, Loss Factors may be determined by carrying out load flow studies on sample networks. There are a number of load flow study tools in the market. Licensee can use the tool accessible to them. ** Energy Input (kWh) = Total Energy Sales (kWh) + Total Energy Losses (kWh). ** Total Energy Loss (kWh) = Non-Technical Losses (kWh) + Technical Losses (kWh).

15.2.3 Electrification Information (INEP Funded)


Reporting Frequency

Report Due Date

INEP Report on electrification** Licensing, tariff & asset base


*within four (4) months of the licensee's financial year end **as reported to DoE


15.2.4 Energy Efficiency & Demand Side Management (EEDSM)


Reporting Frequency

Report Due Date

EEDSM Annual Report including the following: • Verified Annual Energy


technology • Load Factor per technology

• Avoided system cost per

technology


EEDSM Measurement & Verification (M&V) Report including the following: • Verified Annual Energy

saving per technology • Verified Demand savings per

technology



15.2.5 Quality of Service



System Average Interruption Duration Index (SAIDI)


System Average Interruption Frequency Index (SAIFI)


Distribution Supply Loss Index (DSLI)


Report on licensee Quality of service including the following:


• Providing Quotations to consumers


• Providing Supply to consumers


• Credit meter readings for residential and small business consumers of electricity





• Credit meter readings for consumers consuming more than 50KVA


• Disconnections & reconnections (Credit meter consumers, Commercial / industrial consumers, Prepayment meter consumers)


• Prepayment Vending Stations & Meter accuracy queries


• Fault Reporting Centres per number within the licensee area


• Restoration of Supply after a forced interruption


• Planned Interruptions on Overhead Networks & Underground Networks


• Type and number of Complaints


• Time to resolve Customer Complaints, Enquiries and Requests



15.2.6 Distribution Quality of Supply


Reporting Frequency

Report Due Date

Quality of Supply Report* including the following: • MV and HV Regulation


• Total Harmonics Distortion

(THD) • Voltage Dips

Security of supply Annually FY end + 4 months**

*The Quality of Supply Report will take the format prescribed by the Power Quality Directive **within four (4) months of the licensee's financial year end

Documents

Regulatory Reporting Manual Volume 5 Electricity … · Regulatory Reporting Manual Volume 5 Electricity Supply Industry. Non-Financial Information ... 13.2.3 IPP Primary Energy NFI