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1
Eskom Distribution(An Integrated Development Approach)
Presentation to the Portfolio Committee on Public Services and Administration
5 June 2006
2
Contents
1. Brief Introduction/Background
2. Eskom’s Electrification programme
3. Alignment of Projects with IDP Process
4. Electricity Universal Access Approach [2012]
5. National RED – Conceptual Design
6. Progress on Billing Systems [Revenue Enhancement]
7. Electricity Power Challenges in the Western Cape
3
Eskom Holdings : Divisional Mandates
Generation
Transmission
EnterprisesDivision
Corporate
Distribution
To design, build & refurbish Eskom’s assets, act as a catalyst for globalisation for the group and to be the custodian of Eskom’s non-regulated businesses. Eskom Enterprises will also offer strategic and commercial lifecycle services to the line divisions
To optimally operate and maintain the plant lifecycle of Eskom’s South African generation capacity assets.
To assure regulatory compliance, ensure effective group wide governance, develop policies for compliance assurance and to provide strategic services.
To optimally operate and maintain the lifecycle of the South African transmission network.
To manage the retail business and optimally operate and maintain, the SA Distribution network, while playing an active role in the restructuring of the EDI.
Key Customers
Key Customer
Division
To proactively manage contestable client relationships and to trade energy from Generation and international sources to contestable clients in SA (consumers of >100GWh) and customers abroad
4
Distribution Division : Business Model
Customer CategoriesWires Business (Engineering/Network)
Retail Business(Customer Service)
Overall management of network infrastructure in
delivery of electricity to end user
Functional Areas:
• Construction of network infrastructure;
• Installation of meters;
• Inspection, testing, upgrade & maintenance of equipment
• Technical customer connections & disconnections
Purchase electricity from the wholesale market and sell to
end user/ Redistributors
Residential
Traction
Agriculture
Commercial
Redistributors
Prepaid
Mining & Industrial
Functional Areas:
• Sales & Marketing
• Energy Trading
• Customer Service
• Pricing & Tariff Planning
• Call Centre
• Billing
5
Contents
1. Brief Introduction/Background
2. Electrification programme
3. Alignment of Projects with IDP Process
4. Electricity Universal Access Approach [2012]
5. National RED – Conceptual Design
6. Progress on Billing Systems [Revenue Enhancement]
7. Electricity Power Challenges in the Western Cape
6
Electrification - Energy White Paper
Mentions the following key issues:
Electrification Planning Unit [INEP BPU] National Electrification Fund [NEF] Economic Development Infrastructure creation Economic Nodal Areas identified/priorotised Integrated National Electrification Programme
[INEP]
7
Eskom’s Electrification Programme
3,3m households have been electrified since 1994 Approx. R9b capital expenditure – average cost
R3900 per connection National Government subsidised INEP since 2001 R873m allocated for 2006/7 programme 120 000 connections to be realised in 2006/7 [after
adjustments (target was 160 000 connections] Connections mainly in rural areas Capacity building programmes achieved through
ESDEF Rural Development initiatives in Nodal areas
8
Challenges
Different challenges for current and proposed
programme compared to the 1994 programme Limited Infrastructure [mostly in rural areas] Integration with Government prioritiess
A phased process for step-up programme Step-up of programme – 18 months lead time required Average lead time for bulk infrastructure – 27 months Availability of resources, funding, material, suppliers etc.
Ensure availability of adequate capacity Electrical infrastructure in former TBVC states and self
governing territories requires major upgrading and strengthening
9
Challenges
Harmonisation of electrification and housing programmes Balancing cost against social economic requirements e.g. job
creation Ensure availability of data and structural information Cater for household growth as part of step-up programme Development of policies regarding implementation issues
such as un-proclaimed areas, land usages etc. Ensure political support in ensuring the speeding-up of housing
allocation/tender processes etc. Integration of supply technologies Finalisation of the EDI restructuring Availability of funding up front [R2,5 billion per annum]
10
CONTRIBUTION TO INTEGRATED SUSTAINABLE RURAL DEVELOPMENT (ISRDP)
MANDATE AND STRATEGY
The programme was established in 2001 to support the Integrated Sustainable Rural Development Programme in the 15 identified rural nodes.
Eskom will continue with other development initiatives as per their mandates.
The programme will be reviewed in 2010. MANDATE AND STRATEGY
11
Spread of Projects [In Nodal Areas]
Region/Area Amount (R)
Eastern Cape [8 Projects] 17 145 282
Northern Cape [5 Projects] 8 278 350
Central Karoo [2 Projects] 2 400 000
Free State [1 Project] 1 200 000
Limpopo [8 Projects] 8 762 355
KwaZulu Natal [11 Projects] 21 690 000
TOTAL CONTRIBUTION 59 475 987
12
Type of Projects Funded
Rural Development Projects include the following:
Upgrading of Classrooms Contributing towards infrastructure for water projects Food security programmes Multi-Purpose Centres – Electricity Provision Agricultural Development
13
Additional Eskom’s Programmes For Social Upliftment Eskom Development Foundation Training and Development Expo for Young Scientists Proudly South African Selected environmental initiatives Chairman and Chief Executive Funds HIV / AIDS / SAAVI, Health Care training / immune
boosters Business Against Crime Scholarship Programme Assets donations / BUs donations
14
Contents
1. Brief Introduction/Background
2. Electrification programme
3. Alignment of Projects with IDP Process
4. Electricity Universal Access Approach [2012]
5. National RED – Conceptual Design
6. Progress on Billing Systems [Revenue Enhancement]
7. Electricity Power Challenges in the Western Cape
15
The (INEP BPU) makes recommendations for the approval of the Integrated National Electrification Plan [INEP] to the National Electrification Advisory Committee (NEAC) comprising of inter alia DME, National Treasury, SALGA, AMEU, DWAF, IDT, DPLG and Eskom based on the following criteria:
Focus on backlog and apply a rural bias
Prioritise based on Integrated Sustainable Rural Development
Strategy (ISRDS) Nodal Zones
Maximise on available infrastructure
Past performance taken into account
Government priorities and initiatives such as Integrated
Infrastructure Development considered
Regional capacity e.g. resources
National Electrification Fund Allocation Principles
16
NEF Process for Allocation of Funding to Provinces
Use same criteria as in NEAC Adjust programme as per DME requirements and in line
with the change process Provincial consultation done through:
Provincial IDP/MIG Forums chaired by Provincial Local Govt officials
Provincial Energy Forums [where applicable]
Final funding allocations to Municipalities are based on the approved budget by DME and are consistent with IDP agreements signed between Eskom and Municipalities
Project Life Cycle principles observed
17
Contents
1. Brief Introduction/Background
2. Electrification programme
3. Alignment of Projects with IDP Process
4. Electricity Universal Access Approach [2012]
5. National RED – Conceptual Design
6. Progress on Billing Systems [Revenue Enhancement]
7. Electricity Power Challenges in the Western Cape
18
19
National Backlog to date
A current backlog of electrification connections of 3.4 million households.
An estimated requirement of 5 million connections by 2012.
If electrification continues at the current rate: 43% of current backlog (excluding growth) will be electrified by
2012. 29% of backlog (including growth) will be electrified by 2012.
20
Universal Access Consideration Step-up programme planning to be phased in (+/- 18 Months) Master plan needs to be in place Cost per connection (Based on existing Eskom trends)
R4,970 from 2006/7 R5,522 from 2008 to 2010 R6,075 for 2011 to 2012
High cost per connection to be influenced by : Less infrastructure available Catering for higher supply technology e.g. 10A, integrated
development programmes Low density/long line length
21
Universal Access Considerations
Cost for social economic developments e.g. job creation,
BEE should be made available separately (Community
based construction -Department of Labour)
Eskom needs to identify risks and consequences of step-up programme
Focus Universal Access as follows [shifting target]
Western Cape - 2007/8 Northern Cape, Free State - 2008/9 North West and Mpumalanga - 2009/10 Universal Access for the rest – target 2012
Once universal access is reached – business as usual
22
Context ……….
Farm worker houses included as part of connections The following were not factored in
Non grid concessions/connections Local economic development planning Land restitution issues Emerging farmers [electrification, support and
development] Impact of Municipal Infrastructure Grants (MIG) Schools and clinics electrification
Planning Targets should be negotiated with Municipalities to ensure alignment
23
Journey to Universal Access
Eskom identified 3 phases for development of the Universal Access Planning approach:
Phase 1 - (Short term): High level planning proposal to achieve universal access in line with Government objectives;
Phase 2 - (Medium term): Detailed planning proposal per municipality for the current Medium Term Expenditure Framework 3 year cycle (with refined Phase 1 planning proposal); and
Phase 3 - (Long term): Long Term approach on the development of the Universal Access Plan (UAP).
24
Project Charter for Phase 3 (2 Stages)
Project charter on how the plan might be prepared, based on 2 stages: Stage 1: UAP Business Case
Review the 3 year rolling electrification plan and related available data, for the 3 year MTEF cycle as per NT process and to be gazetted by February 2007; and
Develop DME Business Plan (Case Study). Agree upfront on what the DME requirements are for a BP. The minimum requirements are:
Scope and definition of what is required. Resource requirements with a 2012 view broken
down per year. Scenario sketching and sensitivity studies. Risk identification and mitigation The biggest risk is
that Eskom must do more than 350 000 connections within any year.
25
Project Charter for Phase 3 (2 Stages)
Stage 2: National requirement for Universal Access
Compile the Connection Master Plan & Network Development Plan, noting needs of low density areas & small scale farming, & constraints of the 2012 target;
Assess impact on Eskom Generation & Transmission, other operational issues, financial viability, recommended subsidies, tariffs, & refurbishment;
Assess application of technologies (including non-grid), appropriate execution strategies, resource availability & timeframes;
Align to Electricity Supply Industry & Electricity Distribution Industry restructuring, development plans, other planning processes & government initiatives; and
Compile “next phase” detailed projects & timelines after Government decisions.
26
Stage 2 Project Approach
28
Contents
1. Brief Introduction/Background
2. Electrification programme
3. Alignment of Projects with IDP Process
4. Electricity Universal Access Approach [2012]
5. National RED – Conceptual Design
6. Progress on Billing Systems [Revenue Enhamcement]
7. Electricity Power Challenges in the Western Cape
29
Background
Cabinet decision of 14 September 2005:
“… six metro REDs needed to be set up as soon as possible after the local government elections, and that other areas would be covered under separate local REDs or a national distributor. Eskom will continue to play a critical role particularly in the national RED”
Meeting of the economic cluster ministers (DPE, DME, dplg, National Treasury) on 29 November 2005:
• 6 Metro REDs confined (for the 1st phase) to metro boundaries - to be confirmed by March 2006
• Business model for national RED in place by June 2006, subject to realistic timeframes
January 2006: Minister of Public Enterprises requested Eskom to conceptualise the national RED with concrete proposals on management & governance
February-May 2006: Financial Viability analysis.
Awaiting Cabinet approval.
30
Key Features of the National RED
Use the Eskom national footprint as the basis of the National RED
- enhanced economies of scale through proven technology, business processes & scaleable IT solutions
- improved service delivery through customer focused value chains
- sustained industry skills in various centres of excellence
- national planning and infrastructure development
- earlier progress - limited dependence on RED creation
- a base for equitable national tariffs
Staff Benefits
- stability for industry employees
Credible consolidation vehicle for municipal electricity undertakings
- immediately address weak rural distribution- leverage on Eskom experience of TBVC and
SGT take-overs- equalise the financial impact of restructuring
through inclusion in the national rate base
Support free basic electricity & universal access to electricity by 2012
- proven Eskom track record particularly in rural electrification
- economies of scale with respect to planning, project management & national infrastructure development
- delivery of national electrification infrastructure
- government interaction on electrification funding and reporting limited to a single service provider (national RED) as opposed to multiple municipalities
31
Benefits to Municipalities
MUNICIPAL REQUIREMENT
NATIONAL RED OFFERING
Financial Position not adversely affected
Secure cash flow through asset compensation (sale or lease)
Effective and efficient electricity service provision
Effective service provision based on regulatory standards
Delivery on Electrification and FBE targets based on contractual agreements
Effective and Efficient non-electricity service provision
Opportunity for focused attention to non-electricity services
Eskom support for non-electricity municipal services e.g. billing, cash collection & contact centres
Equitable electricity tariffs Low equitable tariffs in the long term due to enhanced business efficiencies through consolidation and economies of scale
National RED a base for equitable national tariffs
32
Non-Electricity Municipal Service Provision [Conceptual Design]
3rd Party cash
collection
CustomerWater Meter
Elect. Meter
Finance
Water / SewageOperations
Municipality
Finance
ContactCentre Billing &
Account Ops
Electricity Dispatching
Copy Billing &Account Ops
DispatchingWater / SewageTrouble
Calls
ElectricityAccountAll
trouble calls&
bill queries
Refer to municipal account
Copy Billing &Account OpsCopy Billing &
Account Ops
Electricity WiresElectricity
Trouble Calls
Refer to Electricit
yaccount
Shared Service
KSACS
MeterRead
s
MeterRead
s
Rates &ServicesAccount
Municipal Services Revenue
3rd Party water credit
Management
National Distributor
ESKOM
Single Customer Data BaseInformation &
Cost for service
Electricity Revenue
Information
33
Summary
The proposed conceptual design of the national RED fully supports the national objectives
The national RED will be an effective consolidation vehicle for non-metro municipalities
Initially, minimal restructuring effort is required to immediately address the problems of rural distribution
The national RED will significantly contribute to meeting the target of universal access to electricity by 2012
Eskom’s national footprint will provide the base for significant benefits through economies of scale and skill
34
Summary
Municipalities will benefit from the process through:
secure cash flows from asset compensation enhanced non-electricity service provision through a service
provided by the National RED The financial implications of the national RED divesting of its
business in the Metro boundaries as well as transferring in municipalities are manageable
35
Contents
1. Brief Introduction/Background
2. Electrification programme
3. Alignment of Projects with IDP Process
4. Electricity Universal Access Approach [2012]
5. National RED – Conceptual Design
6. Progress on Billing Systems [Revenue Enhancement]
7. Electricity Power Challenges in the Western Cape
36
Strategy
Target 6 Munics from the list of 12 as a pilot Liaise with DPLG Service Delivery Facilitators
locally
Customised offering per Munic from: Electricity provision Contact Centre Account Operations Water, rates, sewerage, refuse billing Systems
37
List of 12 Munics with Service Delivery Facilitators
Proposed Municipalities Population # of Households
Other services 1st phase
suggestion
Eskom Region
1 Mafikeng Local Municipality (NW) 259,478 64,674 64,674 C
2 Makhuduthamaga Local Municipality (LP) 262,903 53,156 53,156 N
3 Matjhabeng Local Municipality (FS) 408,170 120,288 30,000 NW
4 City of Johannesburg (GP) 3,225,812 1,006,931
5 Tsantsabane Local Municipality (NC) 31,013 7,227
6 Greater Kokstad Local Municipality (KZN) 56,528 19,625
7 UMngeni Local Municipality (KZN) 73,896 20,488 20,488 E
8 Dr. J S Moroka Local Municipality (MP) 243,313 53,582
9 Cederberg Local Municipality (WC) 39,326 10,366 10,366 W
10 Nelson Mandela Metropolitan Municipality (EC) 1,005,778 260,799
11 Buffalo City Local Municipality (EC) 701,890 191,046 50,000S
12 Moretele Local Municipality (NW) 177,905 43,008
TOTAL 6, 486, 012 1,851,190228,684
38
High Level Assessment and Recommendations
There appears to be no major technical obstacles We can use Eskom’s Billing and Contact Centre Systems Staff and systems are scalable
Municipal customer impacts One municipal bill for all services separate from any
Eskom bill No change to current municipal bill layout and logo New account id will be allocated to the customer Need to convert sufficient history to enable accurate
estimates
Time Frames At least 10 months to set up systems
39
Contents
1. Brief Introduction/Background
2. Electrification programme
3. Alignment of Projects with IDP Process
4. Electricity Universal Access Approach [2012]
5. National RED – Conceptual Design
6. Progress on Billing Systems [Revenue Enhamcement]
7. Electricity Power Challenges in the Western Cape
40
Eskom Peaking Generation400 MW Palmiet
Western Cape Network
Note: The above excludes The City of Cape Town’sgeneration
LoadWinter Max : 4250 MW
Summer Max : 3900 MW
Transmission Capacity2400 - 2800 MW
Koeberg Generation1800 MW
41
What happened?
Date Incident Resulting Impact on Supply
11 November 2005 Switchgear failed Transmission lines and transformers tripped
Loss of supply
16 November 2005 Fire under the lineKoeberg Unit 2 shutdown
Loss of supply
23 November 2005 Controlled shutdown of Koeberg Unit 2
Load shedding due to network limitations
25 December 2005 Controlled shutdown of Koeberg Unit 1, foreign object detected
Loss of supply
18 to 19 February 2006 High pollution levels and misty conditions
Kendal Unit 6 and Koeberg Unit 2 shutdown
Loss of supplyFull black-outSubsequent load shedding
28 February 2006 Multiple line faults Shutdown of Koeberg Unit 2Subsequent load shedding
42
What does this mean? – Supply Capacity
End July27 M
arch 2006
24 April
2006
19 June 2006
22 May 2
006
25 Sept 2
006
28 Aug 2006
Both Koeberg units operational
Limited electricity supply Sufficient electricity supply
Koeberg Unit 2
Koeberg Unit 1
One Koeberg unit operational at a time
Koeberg Unit 1
Koeberg Unit 2
Shut down Koeberg Unit 2 for refuelling at end of May
Complete repairs to Koeberg Unit 1 before end of May
Shutdown
Generating electricity
Key:
Transmission System Intact
Palmiet Pumped Storage
43
What does this mean? – Supply Forecast
0
1000
2000
3000
4000
5000
End July
Electricity supply forecast(Illustrative)
Key:
27 March
2006
24 April
2006
19 June 2006
22 May 2
006
25 Sept 2
006
28 Aug 2006
Limited electricity supply Sufficient electricity supply
Koeberg Unit 900 MW
Transmission System 2400 to 2800 MW
(varies according to Koeberg output)
Koeberg Unit 480 to 900 MW
Palmiet Up to 400 MW
44
What does this mean? – Supply Shortfall
0
1000
2000
3000
4000
5000
End July
We need more electricity than can be supplied
Enough electricity to meet needs
Electricity supply forecast
Electricity need/demand forecast
Key:Gap = Electricity Supply
Shortfall of 300 to 400 MW during morning and evening
peak times through the winter
27 March
2006
24 April
2006
19 June 2006
22 May 2
006
25 Sept 2
006
28 Aug 2006
45
What are our Action Plans?
Koeberg Repairs and refueling
Transmission Grid activities
Load Shedding Plan Demand Side Management
(DSM)
No shortage of electricity supply after the end of July since supply will be provided by: Koeberg Unit 1 Koeberg Unit 2 Palmiet (during
peaks) Transmission System
End July
We need more electricity than can be supplied
Enough electricity to meet needs
46
Koeberg - Update
Area Progress Update Risks
Unit 1 Synchronised on to the grid at 10h30 on 17th May
Steadily increasing its power output
Currently generating 99% (890 MW sent out) power
Final adjustments to be made before increasing to full power
At this stage there are no major known risks on the plant
Unit 2 Unit 2 shutdown during the early hours of the 22nd May for its routine refuelling shutdown
Shutdown is planned for 59 days
Should synchronise on to the grid on the 19th July
As it is early days in the outage no new risks or threats have been identified
47
Issues to note
Electrification Progress to date and funding requirements Universal Access Approach/Strategy Co – ordination of projects to meet IDP requirements Training, development and capacity building initiatives
as part of Eskom’s social responsibility programme Revenue Enhancement pilot project REDS and associated benefits Western Cape recovery Plan
48
Thank You