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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.
2 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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
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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
4 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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
5 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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
6 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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.
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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.
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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.
9 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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,…’
10 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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;
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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;
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(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
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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
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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.
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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.
16 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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.
17 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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.
18 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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.
19 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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.
20 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Eskom NFI Required Information
(Generation, Transmission & Distribution)
21 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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
Information Required Purpose (NERSA use)
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
Identification Once off on application
N/A
Number of units in operation Identification Once off on application
N/A
Network connection voltage Identification Once off on application
N/A
22 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
10.2 Eskom Generation Facilities Dynamic NFI
10.2.1 Production NFI for Total Eskom Generation System
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Total Installed Capacity (MW)
Monitoring security of supply
Annually FY end + 4 months*
Capacity under Construction (MW) & expected COD
Monitoring security of supply
Annually FY end + 4 months*
Net capacity (MW) Monitoring security of supply
Annually FY end + 4 months*
Capacity of commissioned units per annum (MW)
Monitoring security of supply
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply
Annually FY end + 4 months*
EAF (%) Monitoring security of supply
Annually FY end + 4 months*
Load factor (%) Monitoring security of supply
Annually FY end + 4 months*
PLL (%) Monitoring security of supply
Annually FY end + 4 months*
Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months*
Total Energy sent out (GWh) Monitoring security of supply
Annually FY end + 4 months*
Total OCGTs energy sent out (MWh)
Monitoring security of supply
Annually FY end + 4 months*
*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
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Volume generated (gross) (GWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Auxiliary consumption (own use) (GWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Volume sent out (GWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Partial load losses (GWh) Monitoring security of supply & levies
Annually FY end + 4 months
Installed capacity (MW) at year end
Monitoring security of supply & levies
Annually FY end + 4 months*
Capacity under construction (MW) & expected COD
Monitoring security of supply & levies
Annually FY end + 4 months*
Net capacity (MW) at year end
Monitoring security of supply & levies
Annually FY end + 4 months*
23 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
UCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
EAF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PLL (%) Monitoring security of supply & levies
Annually FY end + 4 months*
Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months*
Thermal efficiency Efficiency Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
10.2.2.2 Eskom Production NFI for each Nuclear Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Volume generated (gross) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Auxiliary consumption (own use) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Volume sent out (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
Partial load losses (MWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Installed capacity (MW) as at year end
Monitoring security of supply & levies
Annually FY end + 4 months*
Capacity under construction (MW) & expected COD
Monitoring security of supply & levies
Annually FY end + 4 months*
Net capacity (MW) as at year end
Monitoring security of supply & levies
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
EAF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PLL (%) Monitoring security of supply & levies
Annually FY end + 4 months*
Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
24 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
10.2.2.3 Eskom Production NFI for each Hydro Power Station (include small Hydro)
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Volume generated (gross) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Auxiliary consumption (own use) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Volume sent out (MWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Partial load losses % Monitoring security of supply & levies
Annually FY end + 4 months*
Installed capacity (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
Capacity under construction (MW) & expected COD
Monitoring security of supply & levies
Annually FY end + 4 months*
Net capacity (MW) as at year end
Monitoring security of supply & levies
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
EAF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PLL (%) Monitoring security of supply & levies
Annually FY end + 4 months*
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
Volume generated (gross) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Consumption during pump mode (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Volume sent out (MWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Partial load losses (%) Monitoring security of supply & levies
Annually FY end + 4 months*
Installed capacity (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
Capacity under construction (MW) & expected COD
Monitoring security of supply & levies
Annually FY end + 4 months*
Net capacity (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
EAF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PLL (%) Monitoring security of supply & levies
Annually FY end + 4 months*
Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months*
*within (4) months of the licensee's financial year end
25 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
10.2.2.5 Eskom Production NFI for each Gas/Diesel Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Volume generated (gross) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Auxiliary consumption (own use) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Volume sent out (MWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Partial load losses (MWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Installed capacity (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
Capacity under construction (MW) & expected COD
Monitoring security of supply & levies
Annually FY end + 4 months*
Net capacity (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
EAF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PLL (%) Monitoring security of supply & levies
Annually FY end + 4 months*
Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months* Thermal efficiency Efficiency Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
10.2.2.6 Eskom Production NFI for each Renewable Energy Power Station
Information Required Purpose (NERSA use)
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
Auxiliary consumption (own use) (MWh)
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 under construction (MW) & expected COD
Capacity & efficiency Annually FY end + 4 months*
Net capacity (MW) as at year end
Capacity & efficiency Annually FY end + 4 months
UCLF (%) Capacity & efficiency Annually FY end + 4 months
26 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Information Required Purpose (NERSA use)
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
Unit trips (UAGS/7000) 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
Information Required Purpose (NERSA use)
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
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
No. of refuelling outages completed in past financial year.
Resource planning Annually FY end + 4 months*
Fuel volume purchased in past financial year (no. of fuel assemblies)
Resource planning Annually FY end + 4 months*
No. of fuel assemblies discharged during past financial year.
Resource planning Annually FY end + 4 months*
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)
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Water volume used (kL) Resource planning Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
27 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
10.2.3.4 Eskom Primary Energy NFI for each Pumped Storage Hydro Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Water volume used (kL) Resource planning Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
10.2.3.5 Eskom Primary Energy NFI for each Diesel Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Calorific value (kJ/mᶟ) Resource planning Annually FY end + 4 months*
Fuel volume purchased (kL)
Resource planning Annually FY end + 4 months*
Fuel volume used (kL) Resource planning Annually FY end + 4 months*
Water 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)
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
10.2.4 Eskom Primary Energy NFI for Renewable Energy Power Station (Wind, Solar PV, CSP)
Information Required Purpose
(NERSA use) Reporting Frequency
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
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Specific water usage (L/kWh)
Compliance & efficiency Annually FY end + 4 months*
Relative Particulate Emissions (kg/MWh)
Compliance & efficiency Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
28 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
11 Eskom Transmission Facilities NFI Required and Submission Timeframes
11.1 Eskom Transmission 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.
11.1.1 Eskom Transmission 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
11.1.2 Eskom Transmission Static NFI
Information Required Purpose (NERSA use)
Reporting Frequency Report Due Date
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
Identification Once off on application N/A
29 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
11.2 Eskom Transmission Facilities Dynamic NFI
11.2.1 Eskom Transmission Substation Information
Information Required Purpose (NERSA use)
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 Annually FY end + 4 months*
Number of Substations Input Voltage of 88kV
Identification & Regulatory Asset Base Annually FY end + 4 months*
Number of Substations Input Voltage of 132kV
Identification & Regulatory Asset Base Annually FY end + 4 months*
Number of Substations Input Voltage of 220kV
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Number of Substations Input Voltage of 275kV
Identification & Regulatory Asset Base Annually FY end + 4 months*
Number of Substations Input Voltage of 400kV
Identification & Regulatory Asset Base Annually FY end + 4 months*
Number of Substations Input Voltage of 765kV
Identification & Regulatory Asset Base Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
11.2.2 Eskom Transformer Installed Capacity Information
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Installed transformer capacity with input voltage of <66kV (MVA)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Installed transformer capacity with input voltage of 66kV (MVA)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Installed transformer capacity with input voltage of 88kV (MVA)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Installed transformer capacity with input voltage of 132kV (MVA)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Installed transformer capacity with input voltage of 220 kV (MVA)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Installed transformer capacity with input voltage of 275kV (MVA)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Installed transformer capacity with input voltage of 400kV (MVA)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Installed transformer capacity with input voltage of 765kV (MVA)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
30 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
11.2.3 Eskom Transmission Lines Information
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Length of transmission line <66kV (km)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Length of transmission line 66kV (km)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Length of transmission line 88kV (km)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Length of transmission line 132kV (km)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Length of transmission line 220kV (km)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Length of transmission line 275kV (km)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Length of transmission line 400kV (km)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
Length of transmission line 765kV (km)
Identification & Regulatory Asset Base
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
11.2.4 Eskom Transmission Volumes Information
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Power purchases from Eskom generators (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months*
Power purchases from non- Eskom generators (i.e. IPPs and others) (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months*
Imported volumes: Transmission imports (includes Transmission supply, wheel and withdraw volumes) (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months*
Exported volumes: Includes Transmission exports and demand wheel and withdraw volumes (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months
Total distribution purchases: includes Distribution losses, Local purchases and purchases for own use. (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months*
Volume sent out: Gx sent out, IPPs and Dx generation (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months*
Gx Pumping volumes (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months
Transmission technical losses (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months
31 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Annual Energy Wheel and Production Plan (GWh)
Capacity, efficiency and IRP
Annually FY end + 4 months*
Annual Transmission Developmental Plan
Capacity, efficiency and IRP
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
11.2.5 Ancillary Services
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Demand Market Participation (DMP) Instantaneous MW used
Monitoring Annually FY end + 4 months*
DMP Supplemental MW used
Monitoring Annually FY end + 4 months*
DMP Instantaneous MWh used
Monitoring Annually FY end + 4 months*
DMP Supplemental MWh used
Monitoring Annually FY end + 4 months*
Interruptible loads: MW interrupted, MW
Monitoring Annually FY end + 4 months*
Interruptible loads: energy interrupted, MWh
Monitoring Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
11.2.6 Eskom Transmission Service Quality Incentive
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
System Minutes <1 Service Quality Incentive (SQI)
Annually FY end + 4 months*
Major incidents Service Quality Incentive (SQI)
Annually FY end + 4 months*
Line Faults per 100km Service Quality Incentive (SQI)
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
11.2.7 Eskom Transmission Quality of Supply
Information Required Purpose (NERSA use)
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
32 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
11.2.8 System Operations
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Expected available reserve at evening peak
Monitoring security of supply
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
33 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
12 Eskom Distribution Facility NFI Required and Submission Timeframes
12.1 Eskom Distribution 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.
12.1.1 Eskom Distribution 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
12.1.2 Eskom Distribution Facility Static NFI
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
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
List of areas (Licensed supply areas) Identification Once off on application
N/A
Supply Area(s) Geographic Positioning System (GPS) Co- ordinates & relevant polygon
Identification Once off on application
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
Once off on application
N/A
34 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
12.2 Eskom Distribution Facility Dynamic NFI
12.2.1 Eskom Distribution Facility NFI
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Estimated length of distribution line, MV & HV (km)
Identification & asset base
Annually FY end + 4 months*
Estimated length of distribution line, LV (km)
Identification & asset base
Annually FY end + 4 months*
Number of transformers with input voltage of > 1 kV to <11kV
Identification & asset base
Annually FY end + 4 months*
Number of transformers with input voltage ≥ 11kV to ≤ 22kV
Identification & asset base
Annually FY end + 4 months*
Number of transformers with input voltage > 22 kV to < 44 kV
Identification & asset base
Annually FY end + 4 months*
Number of transformers with input voltage: ≥ 44 kV to ≤ 132kV
Identification & asset base
Annually FY end + 4 months*
Licensee installed transformers capacity of above categories (kVA)
Identification & asset base
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
12.2.2 Eskom Distribution Estimated System Losses
Information Required Purpose (NERSA use)
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)**
Compliance Annually FY end + 4 months*
*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)
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
INEP Report on electrification** Licensing, tariff & asset base
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end. **as reported to DoE
35 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
12.2.4 Eskom Energy Efficiency & Demand Side Management (EEDSM)
Information Required Purpose (NERSA use)
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
Monitoring Annually FY end + 4 months*
EEDSM Measurement & Verification (M&V) Report including the following: • Verified Annual Energy
savings per technology • Verified Demand savings per
technology
Monitoring Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
12.2.5 Eskom Distribution Quality of Service
Information Required Purpose (NERSA use)
Reporting Frequency Report Due Date
System Average Interruption Duration Index (SAIDI)
Monitoring Annually FY end + 4 months*
System Average Interruption Frequency Index (SAIFI)
Monitoring Annually FY end + 4 months*
Distribution Supply Loss Index (DSLI)2
Monitoring Annually FY end + 4 months*
Report on Quality of service including the following
Monitoring Annually FY end + 4 months*
• Providing Quotations to consumers
Monitoring Annually FY end + 4 months*
• Providing Supply to consumers
Monitoring Annually FY end + 4 months*
• Credit meter readings for residential and small business consumers of electricity
Monitoring Annually FY end + 4 months*
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.
36 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Information Required Purpose (NERSA use)
Reporting Frequency Report Due Date
• Credit meter readings for consumers consuming more than 50KVA
Monitoring Annually FY end + 4 months*
• Disconnections & reconnections (Credit meter consumers, Commercial / industrial consumers, Prepayment meter consumers)
Monitoring Annually FY end + 4 months*
• Prepayment Vending Stations & Meter accuracy queries
Monitoring Annually FY end + 4 months*
• Fault Reporting Centres per number within the licensee area
Monitoring Annually FY end + 4 months*
• Restoration of Supply after a forced interruption
Monitoring Annually FY end + 4 months*
• Planned Interruptions on Overhead & Underground Networks
Monitoring Annually FY end + 4 months*
• Type and number of Complaints
Monitoring Annually FY end + 4 months*
• Time to resolve Customer Complaints, Enquiries and Requests
Monitoring Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
12.2.6 Eskom Distribution Quality of Supply
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Quality of Supply Report including the following: • MV and HV Regulation
• Voltage unbalance
• Total Harmonics
Distortion (THD) • Voltage Dips
Compliance Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
37 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Independent Power Producers (IPP) NFI Required Information
(Generation & Distribution Connection Facilities)
38 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
13 IPP Facilities NFI Required and Submission Timeframes
13.1 IPP 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.
13.1.1 Licensee 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
13.1.2 IPP Facilities Static NFI
Information Required Purpose (NERSA use)
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 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
Identification Once off on application
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
39 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
13.2 IPP Facilities Dynamic NFI
13.2.1 Production NFI for an IPP Facility
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Installed Capacity (MW) Monitoring security of supply
Annually FY end + 4months*
Capacity under Construction (MW) & expected COD
Monitoring security of supply
Annually FY end + 4 months*
Net capacity (MW) Monitoring security of supply
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply
Annually FY end + 4 months*
EAF (%) Monitoring security of supply
Annually FY end + 4 months*
Load factor (%) Monitoring security of supply
Annually FY end + 4 months*
PLL (%) Monitoring security of supply
Annually FY end + 4 months*
Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months*
Thermal efficiency Efficiency Annually FY end + 4 months*
Energy sent out (MWh) Monitoring security of supply
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
13.2.2 IPP Production NFI per Power Station
13.2.2.1 IPP Production NFI for Coal Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Volume generated (gross) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Auxiliary consumption (own use) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Volume sent out (MWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Partial load losses (MWh) Monitoring security of supply & levies
Daily/Monthly Daily/Monthly
Installed capacity (MW) at year end
Monitoring security of supply & levies
Annually FY end + 4 months*
Capacity under construction (MW) & expected COD
Monitoring security of supply & levies
Annually FY end + 4 months*
Net capacity (MW) at year end
Monitoring security of supply & levies
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
40 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
EAF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PLL (%) Monitoring security of supply & levies
Annually FY end + 4 months*
Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months*
Thermal efficiency Efficiency Annually FY end + 4 months*
*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)
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Volume generated (gross) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Auxiliary consumption (own use) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Volume sent out (MWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Partial load losses (%) Monitoring security of supply & levies
Daily/Monthly Daily/Monthly
Installed capacity (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
Capacity under construction (MW) & expected COD
Monitoring security of supply & levies
Annually FY end + 4 months*
Net capacity (MW) as at year end
Monitoring security of supply & levies
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
EAF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PLL (%) Monitoring security of supply & levies
Annually FY end + 4 months*
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
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Volume generated (gross) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Auxiliary consumption (own use) (MWh)
Monitoring security of supply & levies
Annually FY end + 4 months*
Volume sent out (MWh) Monitoring security of supply & levies
Annually FY end + 4 months*
Partial load losses (MWh) Monitoring security of supply & levies
Daily/Monthly Daily/Monthly
Installed capacity (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
41 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Capacity under construction (MW) & expected COD
Monitoring security of supply & levies
Annually FY end + 4 months*
Net capacity (MW) Monitoring security of supply & levies
Annually FY end + 4 months*
UCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PCLF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
EAF (%) Monitoring security of supply & levies
Annually FY end + 4 months*
PLL (%) Monitoring security of supply & levies
Annually FY end + 4 months*
Unit trips (UAGS/7000) Capacity & efficiency Annually FY end + 4 months*
Thermal efficiency Efficiency Annually FY end + 4 months*
*within four (4) months respectively of the licensee's financial year end
13.2.2.4 IPP Production NFI for Renewable Energy Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Forecasted Volume generated (MWh)
Capacity & levies Monthly Monthly
Actual Volume generated (MWh)
Capacity & levies Monthly Monthly
Forecasted Availability** (MW)
Capacity & levies Monthly Monthly
Actual Availability** (MW) at year end
Capacity & levies Monthly Monthly
Auxiliary consumption (own use) (MWh)
Capacity & levies Monthly Monthly
Volumes sent out (MWh) Capacity & efficiency
Annually FY end + 4 months*
Installed (rated) capacity (MW) at year end
Capacity & efficiency
Annually FY end + 4 months*
Capacity under construction (MW) & expected COD
Capacity & efficiency
Annually FY end + 4 months*
Net capacity (MW) as 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
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
42 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
13.2.3 IPP Primary Energy NFI
13.2.3.1 IPP Primary Energy NFI for Coal Power Station
Information Required Purpose (NERSA use)
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
13.2.3.2 IPP Primary Energy NFI for Hydro Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Water volume used (kL) Resource planning Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
13.2.3.3 IPP Primary Energy NFI for Diesel Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Calorific value (kJ/ mᶟ) Resource planning Annually FY end + 4 months*
Fuel volume purchased (kL)
Resource planning Annually FY end + 4 months*
Fuel volume used (kL) Resource planning Annually FY end + 4 months*
Water 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)
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
13.2.3.4 IPP Primary Energy NFI for Natural Gas or LNG Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Calorific value (kJ/mᶟ) Resource planning Annually FY end + 4 months*
Fuel volume purchased (mᶟ)
Resource planning Annually FY end + 4 months*
43 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Fuel volume used (mᶟ) Resource planning Annually FY end + 4 months*
Water volume used (kL) Resource planning Annually FY end + 4 months*
Stock holding (mᶟ) ** Security of supply Annually FY end + 4 months*
Stock holding (per running days/hours)**
Security of supply Annually FY end + 4 months*
*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)
Information Required Purpose
(NERSA use) Reporting Frequency
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)
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Calorific value (kJ/mᶟ) Resource planning Annually FY end + 4 months*
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)
Resource planning Annually FY end + 4 months*
Water volume used (kL) Resource planning Annually FY end + 4 months*
Stock holding (mᶟ) ** Security of supply Annually FY end + 4 months*
Stock holding (per running days/hours)**
Security of supply Annually FY end + 4 months*
*within four (4) months of the licensee's financial year quarter end
13.2.6 IPP Environmental NFI for Generation Power Station
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Specific water usage (L/kWh) Compliance & efficiency Annually FY end + 4 months*
Relative Particulate Emissions (kg/MWh)
Compliance & efficiency Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
44 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
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
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
14.1.2 IPP Distribution Licensed Facilities Static NFI
Information Required Purpose (NERSA use)
Reporting Frequency Report Due Date
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)
Identification Once off on application N/A
IPP Connection facility COD Identification Once off on application N/A
Length in km of distribution connection line including kV (IPP Connection facilities)
Identification & asset base
Once off on application N/A
Delivery Point (point or substation name and owners name)
Identification Once off on application N/A
List of Third parties connected to the distribution line
Identification Once off on application N/A
45 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Municipalities & Private Distributors NFI Required Information
(Distribution Only)
46 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
15 Municipality or Private Distributor Distribution Facilities NFI Required and Submission Timeframes
15.1 Distribution 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.
15.1.1 Distribution Licensee 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
15.1.2 Distribution Licensed Facilities Static NFI
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
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
List of areas (Licensed supply areas) Identification Once off on application
N/A
Supply Area(s) Geographic Positioning System (GPS) Co- ordinates & relevant polygon
Identification Once off on application
N/A
Length of distribution line, MV & HV (km)
Identification, asset base & efficiency benchmarking
Once off on application
N/A
Length of distribution line, LV (km) Identification & asset base
Once off on application
N/A
47 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
15.2 Distribution Facilities Dynamic NFI
15.2.1 Distribution Facility NFI
Information Required Purpose (NERSA use)
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
Annually FY end + 4 months*
Estimated length of distribution line, MV & HV (km)
Identification & asset base
Annually FY end + 4 months*
Estimated length of distribution line, LV (km)
Identification & asset base
Annually FY end + 4 months*
Number of transformers with input voltage: > 1 kV to ˂ 11 kV
Number of transformers with input voltage: ≥ 11 kV to ≤ 22kV
Identification & asset base
Annually FY end + 4 months*
Number of transformers with input voltage > 22 kV to ≤ 44 kV
Identification & asset base
Annually FY end + 4 months*
Number of transformers with input voltage: ≥ 44 kV to ≤ 132kV
Identification & asset base
Annually FY end + 4 months*
Licensee installed transformers capacity of above categories (kVA)
Identification & asset base
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
15.2.2 Distribution System Losses
Information Required Purpose (NERSA use)
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)**
Compliance Annually FY end + 4 months*
*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)
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
INEP Report on electrification** Licensing, tariff & asset base
Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end **as reported to DoE
48 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
15.2.4 Energy Efficiency & Demand Side Management (EEDSM)
Information Required Purpose (NERSA use)
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
Monitoring Annually FY end + 4 months*
EEDSM Measurement & Verification (M&V) Report including the following: • Verified Annual Energy
saving per technology • Verified Demand savings per
technology
Monitoring Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
15.2.5 Quality of Service
Information Required Purpose (NERSA use)
Reporting Frequency Report Due Date
System Average Interruption Duration Index (SAIDI)
Monitoring Annually FY end + 4 months*
System Average Interruption Frequency Index (SAIFI)
Monitoring Annually FY end + 4 months*
Distribution Supply Loss Index (DSLI)
Monitoring Annually FY end + 4 months*
Report on licensee Quality of service including the following:
Monitoring Annually FY end + 4 months*
• Providing Quotations to consumers
Monitoring Annually FY end + 4 months*
• Providing Supply to consumers
Monitoring Annually FY end + 4 months*
• Credit meter readings for residential and small business consumers of electricity
Monitoring Annually FY end + 4 months*
49 Final Version: 16 March 2015 Approval Date: 26 March 2015 Effective Date: 01 April 2016
Information Required Purpose (NERSA use)
Reporting Frequency Report Due Date
• Credit meter readings for consumers consuming more than 50KVA
Monitoring Annually FY end + 4 months*
• Disconnections & reconnections (Credit meter consumers, Commercial / industrial consumers, Prepayment meter consumers)
Monitoring Annually FY end + 4 months*
• Prepayment Vending Stations & Meter accuracy queries
Monitoring Annually FY end + 4 months*
• Fault Reporting Centres per number within the licensee area
Monitoring Annually FY end + 4 months*
• Restoration of Supply after a forced interruption
Monitoring Annually FY end + 4 months*
• Planned Interruptions on Overhead Networks & Underground Networks
Monitoring Annually FY end + 4 months*
• Type and number of Complaints
Monitoring Annually FY end + 4 months*
• Time to resolve Customer Complaints, Enquiries and Requests
Monitoring Annually FY end + 4 months*
*within four (4) months of the licensee's financial year end
15.2.6 Distribution Quality of Supply
Information Required Purpose (NERSA use)
Reporting Frequency
Report Due Date
Quality of Supply Report* including the following: • MV and HV Regulation
• Voltage unbalance
• 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