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Viewing cable 05PRETORIA94, RESTRUCTURING OF THE SOUTH AFRICAN ELECTRICITY
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| Reference ID | Created | Released | Classification | Origin |
|---|---|---|---|---|
| 05PRETORIA94 | 2005-01-10 10:58 | 2011-08-24 01:00 | UNCLASSIFIED | Embassy Pretoria |
This record is a partial extract of the original cable. The full text of the original cable is not available.
UNCLAS SECTION 01 OF 05 PRETORIA 000094
SIPDIS
STATE PLEASE PASS USAID STATE PLEASE PASS USGS
E.O. 12958: N/A
TAGS: EPET ENRG EINV EIND ETRD ECON SF
SUBJECT: RESTRUCTURING OF THE SOUTH AFRICAN ELECTRICITY
INDUSTRY -- THE SUPPLY SECTOR
¶1. (U) Introduction: In light of recent government
initiatives to restructure the South African energy industry,
post will submit separate reports on the supply, distribution
and transmission sectors. Each cable will serve as a general
review of that sector, and be the launch-pad from which
subsequent cables on specific topics are prepared, as
developments take place in each sector. The first, dealing
with the supply sector, follows. The purpose of these cables
is to indicate the potential opportunities for investment,
technology and service providers created by the energy-
restructuring program. End introduction.
---------------------------------
Electricity Supply Industry (ESI)
---------------------------------
¶2. (U) Summary: At the beginning of this decade, in the
absence of new supply, the South African Government concluded
that demand for electricity would soon overtake existing
generation capacity. Government tasked the National Energy
Regulator (NER) to develop a National Integrated Resource
Plan (NIRP) for insuring security of future supply. The
first NIRP was completed and published in March 2002. At the
beginning of 2003, the NER established an Advisory and Review
Committee (ARC) to solicit stakeholder contributions to the
NIRP process. The updated study (October 2003), generated
under the guidance and approval of the NER, was carried out
by a NIRP team comprising the Eskom Resources and Strategy
Group (headed by their Managing Director, Dr Steve Lennon),
the Energy Research Institute (ERI) of the University of Cape
Town, and the NER.
¶3. (U) In the early seventies Eskom forecast an electricity
growth rate of 8%, and consequently built and commissioned a
number of six-pack (six generation units per station) coal-
fired stations. In the middle of the construction program,
the demand growth rate dropped as low as minus 0.4%, causing
a serious over capacity, and three of the stations - Camden,
Komati and Grootvlei - were "mothballed". Decommissioning
ended in about 1990. The excess capacity allowed Eskom to
become the lowest cost producer of electricity in the world.
Eskom's tracking of electricity consumption identified a
significant increase in demand (from about 2000), and they
forecast that new peaking capacity would be required by 2007,
and new base load capacity by 2011. In October 2003, the
NIRP-team updated the 20-year energy supply plan based on the
new demand projections, and estimated capital expenditure of
some $17 billion to 2010. The main purpose of the plan was
to identify the most cost-effective and environmentally
friendly combination of options and technologies available to
ensure South Africa of a timely, reliable and quality supply
of electricity in the future. Schedules and technologies
will inevitably change over time as new developments occur.
End summary.
Current Capacity and Technology Mix
-----------------------------------
¶4. (U) South Africa's total licensed generation capacity is
about 44,000 MW of which Eskom (state-owned electricity
utility) owns 42,000 MW. Eskom mothballed 3,600 MW of
capacity in 1990 and their total net operating capacity (NOC)
at December 31, 2003 was 36,200 MW. Coal-fired stations
generate 86% of the electricity, nuclear 5%, pumped-storage
4%, hydro 2%, emergency gas turbines 1%, and 2% is imported
from the Cahora Bassa hydro station in Mozambique.
¶5. (U) Eskom currently operates 10 large coal-fired power
stations, a two-reactor 1,800 MW nuclear station (Koeberg
located 30 kilometers north of Cape Town), six small hydro
stations, and two pumped-storage schemes that play a critical
role in meeting peak demand. Municipalities own 22 small
power stations and back-up gas turbines, but these total only
5% of national generation capacity and generally run at low
load factors. Municipalities also own the transmission lines
and the transformers located within their boundaries.
Private generators comprise the remaining 2% of capacity. In
2003, the peak demand was 32,000 MW, equal to 89% of NOC.
Estimated demand growth is at least 1,000 MW per annum, and
the current growth rate stands at around 4.6%.
¶6. (U) According to Mike Cary, Managing Director of Rotek
Engineering an Eskom group engineering company, a
complicating factor to the capacity problem is that the power
stations are ageing. The ages of the newest stations vary
between 10 and 24 years, and the equipment on these stations
can be as old as 30 years. Although Eskom has a
comprehensive maintenance program, the old equipment is more
prone to failure. Part of the risk-management strategy is to
carry spares, but financial constraints limit this option.
Over the past 12 months, Eskom has experienced an abnormally
high failure rate (14 major supply disruptions in the
Johannesburg area alone) and some of the plant transformers
have failed to such an extent that some critical spares are
no longer available.
-----------------------
Eskom's Expansion Plans
-----------------------
¶7. (U) Government decided in 1998 to restructure Eskom and to
establish a multi-market model (MMM) for electricity trade in
South Africa. During the four-year model planning process,
Eskom submitted its investment program for new electricity
capacity (as its contribution to the NIRP) on an annual
basis. The estimated cost of the expansion program was about
$32 billion (over 20 years), and aimed to ensure that South
Africa had enough electricity to power its growing economy.
¶8. (U) However, during this time Eskom became a virtual "on-
looker" as government decided that Eskom would not be allowed
to build any new generation capacity as the government wanted
to have the MMM in place before the excess capacity ran out.
Eskom, however, remained the supplier of last resort and
obligated to ensure sufficient supply to the country. Part
of the plan to restructure Eskom was to sell 30% of their
generation capacity, valued at more than $4 billion, to
foreign power utilities. Due to a policy shift, this process
remained in limbo. Eskom and Government now face crucial
decisions about new power plants, and the balancing of
financial, operational and environmental criteria in
selecting the type and mix of energy projects it should
develop.
¶9. (U) Following the April 2004 elections, new Public
Enterprise Minister Alec Erwin (Eskom's shareholder
department) rescinded the "restructuring" of Eskom. This was
part of a general policy shift aimed at strengthening State
Owned Enterprises to ensure that the social objectives of
government would be met first. Erwin fast-tracked the go-
ahead for new investment in electricity supply, as outlined
in the NIRP. On October 20, the Cabinet approved $13.5
billion in capital expenditure for Eskom to return to service
the mothballed stations, build 70% of new capacity, and
upgrade existing stations, transmission lines, and
distribution networks. Government expects Eskom to source
much of this capital from the markets. Erwin also "offered"
independent power producers (IPP's), particularly foreign
utilities, a 30% slice of the proposed new generation
capacity. In this way, he hopes to ensure healthy
competition for Eskom and to attract foreign direct
investment into the infrastructure sector of the country
without damaging Eskom's ability to lead the expansion drive.
Steve Lennon, Eskom's Managing Director for Resources and
Strategy, has stated that the investment decision was in time
to avoid early supply disruptions in 2006 and 2010.
Short-Term Expansions to 2010
-----------------------------
¶10. (U) The latest update of the NIRP's power expansion
strategy (October 2003) deals with expansions envisaged up to
¶2022. The first phase deals with immediate electricity needs
over the next five years. This requires Eskom and IPP's to
add at least 1,000 MW of capacity every year, from 2005 to
2010, to avoid shortages during peak usage time. The
investment package portions the $13.5 billion as $9.7 billion
for generation, $2.2 billion for distribution, and $1.6
billion for transmission. The plan is for Eskom to return to
service three coal-fired stations between 2005 and 2011 --
total base-load capacity of 3,600 MW. In addition, Eskom is
to build a new 1,000 MW open cycle gas turbine (OCGT) plant
by 2007 (location not specified), and by mid 2005 the DME
plans to request the private sector to tender for a 1,000 MW
OCGT plant (location not specified), fueled by a light diesel
distillate, to be operational by 2008.
Longer-Term Expansions - 2011-2022
----------------------------------
¶11. (U) By 2010 Eskom will have to start commissioning power
plants that will add to the base load for which planning will
start in 2005. According to Lennon, the program was based on
the forecast of an increase in demand of 1.5%-4% per year
over the next 20 years. However, there are contingency plans
for an uptake of 5% should demand exceed estimates. The long-
term base load capacity would include a combination of new
power plants and imports of electricity from a number of
African projects. Capacity increases include:
-- a $0.7 billion, 1,330 MW pumped-storage scheme at
Braamhoek in KwaZulu/Natal Province, by 2013,
-- a $0.8 billion, 1,000 MW pumped-storage scheme at
Steelpoort in Mpumalanga province, by 2014,
-- a third 1,000 MW pumped-storage facility at Monontsa in
the Free State province, and planned for 2019,
-- a $1.4 billion, 1,500 MW combined cycle gas turbine (CCGT)
facility, possibly located near Coega (new deep water port
under construction) in the Eastern Cape Province, by 2013,
-- three generation units (total rated capacity of nearly
2,000 MW) added to the six already operating at the Mathimba
power station in Limpopo Province, at a cost of $3.2 billion,
-- a 4,000 MW greenfields coal-fired power station, at an
estimated cost of almost $6.4 billion, near coal reserves in
either Limpopo or Mpumalanga provinces, or in neighboring
Botswana or Mozambique.
Summary of Capacity Expansions to 2022
--------------------------------------
¶12. (U) Some electricity expansion options considered by the
NIRP team extend beyond the 2022 time-period, but are shown
for information completeness. Obviously, these technologies
and time schedules will change over time as energy demand,
innovations and other developments occur.
Generation Stations Implementation New (MW)
and Technologies Schedule Capacity
-------------------- -------------- --------
3 De-mothballed coal-fired 2005-2011 3,600
(possibly fast-tracked to 2009)
10 Single/Open Cycle Gas (SCGT) 2006-2010 2,640
1 SCGT 2022 240
3 Dry-cooled coal-fired 2016-2022 9,630
2 Pumped-storage 2012-2014 2,330
1 Pumped-storage 2019 1,000
5 Fluid Bed Combustion 2012-2014 2,330
1 IPP Open Cycle Gas (OCGT) 2008 1,000
Total new capacity 22,770
Other possible options for the future (probably beyond 2022)
include:
3 Combined Cycle natural gas 3,470
1 Nuclear Pebble Bed cluster of 8 reactor units 1,320
1 Coal-fired 3,780
1 Pumped-storage 1,000
Total possible new capacity 9,570
PBMR
----
¶13. (U) According to Lennon, environmental criteria are
critically important in deciding the combination of new power
plants to be developed. This could benefit non-coal
projects, as Eskom's coal-fired plants are the chief emitters
of carbon dioxide and other pollutants. Environmental
considerations could also provide a boost to development of
South Africa's fourth-generation nuclear-based pebble bed
modular reactor (PBMR), which could be ready for commercial
launch by 2013, and features in Eskom's long-term expansion
plans, from about 2015 onwards. The capacity of a single
PBMR reactor unit is 165 MW, and that of an 8-pack cluster,
1,320 MW. Johan Kriek, CEO of PBMR Ltd, plans to start
construction of a PBMR demonstration unit in the second
quarter of 2007, the first commercial unit by 2013, and to
supply Eskom with 24 units (three clusters) between 2013 and
¶2023. Lennon said that negotiations have started in the
process to develop a PBMR supply agreement between PBMR Ltd
and Eskom.
Imports
-------
¶14. (U) The African electricity import projects on the Eskom
drawing board include Cahora Bassa in Mozambique, the
proposed Inga3 hydro-electric project in the DRC, and buying
surplus power from the Southern African Power Pool, as
available. Lennon said that part of Eskom's strategy could
be to put equity into Cahora Bassa, depending on the
financial details of such a deal. In addition, in November
2004, the South African utility was one of five Southern
African utilities that bought equal equity stakes in Westcor,
the company earmarked to build the $5 billion power station
at Inga3, and the associated transmission and interconnect
supply lines. The project has the potential to supply 3,500
MW of electricity by 2011, but many experts believe this to
be an unrealistic target, given the political (and
investment) uncertainties in the DRC.
Status of the Expansion Plan
----------------------------
¶15. (U) The first phase of the expansion, dealing with
new capacity over the next five years, is well under
way. Eskom has commissioned the return to service of
three mothballed power stations at a total cost of $1.9
billion. These three facilities, when refurbished,
should supply 3,600 MW to the grid. The largest of the
three, Camden, is set to return to service in 2005. The
DME has also authorized Eskom to build a new 1,000 MW
open cycle gas turbine (OCGT) plant by 2007 (location
not specified), and a 1330 MW pumped-storage station
(Braamhoek) by 2013, as part of a $13.5 billion
investment. In December, the DME issued an IPP
"Expression of Interest" document for a 1,000 MW OCGT
facility (location not specified), fueled by a light
diesel distillate, to be operational by 2008. The
tender document should be available by August 2005, and
Eskom, as the purchaser of the electricity, cannot bid
for the project. The final leg of Eskom's short-term
revamp will be to upgrade a number of its older base-
load stations, including a $160 million upgrade of the
2,100 MW Arnot station. Through demand and supply side
efficiency-improvement strategies, Eskom management
plans to take 4,000 MW out of the system by 2013.
Financing the Expansions
------------------------
¶16. (U) Eskom spokesman, Fani Zulu, has indicated that Eskom
would finance the $13.5 billion expansion for the first three
years through a combination of cash flows and loan financing.
After that, Eskom is likely to revert to the local and
offshore capital markets. Eskom, has a relatively low 30%
gearing, and has some room on its balance sheet to raise its
debt level. A crucial part of the financing would be the
electricity price, which the NER determines. The regulator
has recently granted Eskom below-inflation tariff increases,
but Minister Erwin has backed Eskom's call for more realistic
prices to enable the huge capital expenditure requirement.
¶17. (U) In summary, the main conclusions drawn from the
latest NIRP study by energy experts, are that:
-- Options for diversifying away from coal-fired plants are
insufficient to meet forecast electricity demand over the
next 20-years,
-- Economic justification for diversification plants would
prove difficult in the absence of persuasive measures such as
penalties and subsidies for non-use or use,
-- Clean coal technologies and demand side efficiency
strategies are required to meet environmental standards,
-- Base load plants would be required for commercial
operation after 2010,
-- At assumed future costs, and after returning the Eskom
mothballed plants to service, fluidized bed combustion (FBC)
technology offers the most economical option, followed by
coal-fired plants, and then CCGT plants (in the western
Cape), using imported gas/LNG,
-- NIRP plans indicate that 920 MW OCGT peak load plants must
begin commissioning from 2008,
-- NIRP plans assume the attainment and sustainability of
demand side management targets, power plant availability,
imports, and interruptible supply strategies,
-- short-term peak-load requirements can be facilitated using
single cycle gas turbines fueled by locally-produced
synthetic gas.
------------------------------------------
Summary of South African Energy Statistics
------------------------------------------
¶18. (U) Projected Electricity Supply/Demand (MW)
2004 2008 2012 2016 2022
Generating
Capacity 38,620 41,990 46,060 50,700 57,540
Peak Demand 34,620 38,530 42,020 45,660 51,890
Reserve
Margin (%) 11.6 9.0 9.6 11.0 10.9
New capacity - 3,390 8,460 13,140 19,990
Current Supply (MW)
Eskom:
Coal-fired 32,070
Nuclear 1,800
Pump Storage 1,400
Hydro 570
Gas Turbines 340
Total 36,180
Non-Eskom:
Coal-fired 1,320
Pump Storage 180
Hydro 70
Gas Turbines 90
Total (MW) 1,660
Imports:
Cahora Bassa (hydro) 780
Total 38,620
South Africa's Energy Mix
Product Electricity Energy End Use %
Generation % Supply %
Coal 86 69% 30
Crude - 18% -
Biomas - 9 8
Nat gas 1 3% -
Hydro 2