cogeneration project at four rand water sites · eskom rebate: • eskom in collaboration with...
TRANSCRIPT
COGENERATION PROJECT AT FOUR RAND
WATER SITES
PRESENTED BY IVEEN MBHELE 29 MAY 2012
PRESENTATION
• INTRODUCTION
• RAND WATER CONCEPTUAL DESIGNS
• ESKOM AND NERSA INITIATIVES
• IMPLEMENTATION STRATEGY
• FINANCIAL MODEL
• STRATEGIC IMPLICATIONS
• PROJECT CHALLENGES
• RISKS
• SEQUENCE OF EVENTS SINCE PROJECT INCEPTION
INTRODUCTION
• South Africa is experiencing power supply shortages and Eskom has embarked
on an extensive capital investment programme to build new power stations.
• The two coal fired power stations currently being built by Eskom are Medupi
and Kusile; these would however take a number of years to complete.
• Eskom and NERSA has in the short term embarked on a number of initiatives
including power conservation and load shedding together with industry and other
stakeholders.
INTRODUCTION
Rand Water has identified four sites within its current water transfer infrastructure
where hydropower can be generated.
ZOEKFONTEIN KLIPFONTEIN BRAKFONTEIN HARTEBEESHOEK
Location 8 600 m downstream
from the Vaal Dam
Chloorokop, Kempton
Park
Midrand Rosslyn
Pressure (m) 23 - 15 65 70 - 75 150 - 155
Flow (m3/s 13.8 - 23.86 5.7 - 6.9 2.3 - 2.76 1.38 - 1.61
INTRODUCTION
Location: Zoekfontein site
INTRODUCTION
Location:n: Klipfontein, Brakfontein and Hartebeeshoek sites
INTRODUCTION
CONVENTIONAL HYDROPOWER PLANT:
INTRODUCTION
TYPICAL HYDROPOWER PLANTS WITHIN PIPELINE NETWORK:
RAND WATER CONCEPTUAL DESIGNS
ZOEKFONTEIN SITE:
RAND WATER CONCEPTUAL DESIGNS
ZOEKFONTEIN SITE: HYDRAULIC MODELING
RAND WATER CONCEPTUAL DESIGNS
KLIPFONTEIN SITE:
RAND WATER CONCEPTUAL DESIGNS
BRAKFONTEIN SITE:
RAND WATER CONCEPTUAL DESIGNS
HARTEBEESHOEK SITE:
ESKOM AND NERSA SUPPLY SIDE INITIATIVES
• Pilot National Cogeneration Program (PNCP) - launched in 2007.
• Renewable Feed-in Tariff (REFIT) scheme – launched in 2009
• Renewable Bid-in Tariff (REBIT) scheme – launched in 2011
ESKOM AND NERSA INITIATIVES
Pilot National Cogeneration Program (PNCP):
• Eskom launched the PNCP in May 2007 for organisations to build power
generation capacity for cogeneration with Eskom.
• Eskom would contract to purchase the energy from sites with more than 1MW.
• The contract period with these organisations would range from 7 to 15 years.
• Eskom also offered an early completion incentive to bidders and a premium
price for power generated between April 2008 and April 2013; this being the
most critical period of the power shortages in the country.
• Rand Water submitted its bid prices of 45c /kWh for all sites.
ESKOM AND NERSA INITIATIVES
Renewable Feed-in Tariff (REFIT) scheme :
• The National Energy Regulator of South Africa (NERSA) introduced the
Renewable Energy Feed-in Tariff (REFIT) scheme with the aim to harvest 10,000
GWh of Renewable energy in South Africa by 2013.
• In order for a project to qualify for Renewable Energy, the electricity should be
produced by means of naturally occurring, non-depletable sources of energy such
as solar, wind, biomass, hydro, tidal, wave, ocean current and geothermal.
• Small hydro power plant of less than 10MW qualifies.
• Feed-in Tariffs were, in essence, guaranteed prices for electricity supply rather
than conventional consumer tariffs.
• A tariff of 94 c/kWh was offered by NERSA for hydro power.
ESKOM AND NERSA INITIATIVES
Renewable Bid-in Tariff (REBIT) scheme :
• Due to concerns with legality of REFIT scheme, the Department of Energy
introduced the REBIT scheme (2011).
• REBIT follows similar process as PNCP where companies submit bids with
prices for approval.
• It is based on competitive price bidding.
IMPLEMENTATION STRATEGIES
Own Use
Rand Water generates power and wheels it through Eskom or
Municipality networks. This power is discounted against power used at
Rand Water sites (Under this option Rand Water funds the project).
BOOT
An Independent Power Producer (IPP) is appointed to generate and sell power
to the market in exchange for royalties to Rand Water
(Under this option, the IPP funds the project, REFIT prices used).
Rand Water/IPP Partnership
Rand Water forms a partnership with an IPP but
Rand Water ownership is limited to 49% and is liable to pay tax.
(Electricity is sold under the REFIT scheme)
COMPARISON OF IMPLEMENTATION STRATEGIES
Parameter Own Use IPP/Partnership BOOT
Speed of
implementation
Relatively quick and
simple
Project finance structure
required and more
complicated
Dependent on IPP
Cost of funding Advantage of strong credit
rating
Funding based on project
finance and expensive
Does not affect Rand
Water
Source of funding Could be local or
international
Could be local or
international
Does not affect Rand
Water
Term of funding Term could be shorter Long term funding Does not affect Rand
Water
Impact on Rand Water
borrowing capacity
Will impact due to
utilization of credit lines
Lesser impact due to
limited shareholding
Does not affect Rand
Water
Return on investment Would expect utility level
return of about 8%
Would expect IPP return
in the region of 20%
Does not affect Rand
Water
Transaction cost Low transaction cost High transaction cost
Does not affect Rand
Water
Legal complexity Relatively simple Complex set of legal
requirements to ring fence
Multitude of agreements
to secure concessions
Construction risk Risk lies with Rand Water
but mostly can be passed
on to the EPC contractor
Most risk can be passed
on to the IPP
If risks are to high can
lead to project failure
Operation and
maintenance
Rand Water retains
responsibility and ensures
its core function is fulfilled.
Responsibility mostly lies
with IPP and requires
contractual agreements
Responsibility fully lies
with IPP and requires
contractual agreements
FINANCIAL MODEL
• Objectives of the financial model
Compare the Own Use business model against other models.
Determine return on investment per site.
Determine return on investment per tender per site.
FINANCIAL MODEL
ASSUMPTIONS:
• FINANCIAL MODEL
RESULTS COMPARISON:
Own Use IPP Partnership BOOT
NPV (R, million) 303 476 63
IRR (%) 17 26 -
Payback (years) 8 6 -
• OWN USE MODEL PER SITE:
FINANCIAL MODEL
Zoekfontein Klipfontein Brakfontein Hartebeeshoek Total
Average Power
generated (MW)
5.6 3.4 1.8 2.2 13
Average Cost c/kWh
over 20 year period
69 38 85 60 61
Average Capital
outlay (R, millions)
180 61 64 58 364
Discount rate 10% 10% 10% 10% 10%
NPV (R, millions) 103 132 16 52 303
IRR 15% 24% 12% 17% 16
Payback years 8 6 10 8 7
Zoekfontein
Klipfontein
Brakfontein
Hartebeesthoek
Total hours
(22x365)
8 030 8 030 8 030 8 030
Total kWh per
annum
40 150 000 24 491 500 13 249 500 15 257 000
Annual O & M
cost (Rands)
3 504 675 1 192 669 1 249 389 1 131 170
Operating cost
per kWh
R0.08 R0.05 R0.1 R0.08
Total Cost per
kWh
R0.61 R0.27 R0.61 R0.43
• FINANCIAL MODEL
COST PER UNIT GENERATED:
FINANCIAL MODEL
• CAPEX, REVENUE, AND OPSA & MAINT, NET PROFIT (OWN USE):
FINANCIAL MODEL
• NPV (OWN USE):
FINANCIAL MODEL
• CUM NPV (OWN USE):
STRATEGIC IMPLICATIONS
ENERGY SAVING:
• Cogeneration is an energy saving opportunity that can offset the high energy costs.
• The average of 13 MW generated equates to an annual energy saving of 7% of
total Rand Water power consumption.
• Rand Water has the potential to save up to 20% of energy should all other viable
sites be fully explored) .
•
• In addition to the financial benefit, there would be an increased operational
reliability due to reduced reliance on power supplied by Eskom or municipalities.
STRATEGIC IMPLICATIONS
ESKOM REBATE:
• Eskom in collaboration with NERSA has a rebate system for energy saving
initiatives.
• Eskom has recommended that an application for rebate be submitted only for the
Zoekfontein site.
• The estimated rebate from Eskom will be about R26 million based on net power
generated from Zoekfontein.
• Eskom has also indicated that this scheme would be valid until March 2013.
STARTEGIS IMPLICATIONS
CARBON CREDITS:
• Carbon Credits (CC) are traded internationally as a commodity for initiatives that
result in the reduction of environmentally unfriendly emission gases.
• Based on the estimated combined capacity of 13 MW for this project, there is a
potential of generating up to R10 million per annum over a period of 10 years.
• This amount may be used to cover Operation and Maintenance costs.
•
The financial viability of this project has been assessed without the influence of
potential income derived from the sale of CC.
PROJECT CHALLENGES
PATENT CLAIM:
• Rand Water received notification that it should refrain from the project due to an
alleged infringement.
• An individual registered a South African patent in 2009 on hydro power generation
in pipelines.
• A comparison between the patent and the Rand Water designs was drawn and it
was found that the method Rand Water intends to generate power with is the same
method as used elsewhere in the world for many years.
• The expert opinion also further confirmed that the infringement has no basis.
PROJECT CHALLENGES
SERVITUDE AGREEMENTS:
Zoekfontein
• Rand Water is currently negotiating with the land owners of Zoekfontein to obtain
permission to erect a hydro power plant and transmission line in the area within the
Rand Water servitude.
Klipfontein, Brakfontein and Hartebeeshoek
• The hydropower plants on these sites will be based within the reservoir area which
is owned by Rand Water, and therefore there is no need to obtain servitudes
agreements.
•
• Servitudes agreements will, however, be needed for transmission line areas.
PROJECT CHALLENGES
POWER GENERATION LICENCE:
• The power generation licence application to is being prepared for submission to
NERSA.
WHEELING:
• The framework regarding the cost (use of system charges) for wheeling of power
through Eskom or municipal network cost has been issued by NERSA.
• Negotiations with Eskom and Municipalities are in progress.
PROJECT CHALLENGES
ENVIRONMENTAL IMPACT ASSESSMENT:
• GDARD indicated that Basic Assessment and WULA applications will be
necessary for Zoekfontein site only.
•
• Klipfontein, Brakfontein and Hartebeeshoek may not need EIA application.
• An EIA consultant was appointed and the application has been submitted.
• Authorization is expected in November 2012.
NOISE POLLUTION:
• Water inlet to reservoirs is controlled with Larner Johnson valves. When reservoirs
are full, a loud siren like noise is emitted, polluting the environment.
By installing the turbines this noise pollution will be minimized.
PROJECT CHALLENGES
OPERATION AND MAINTENANCE
• The cogeneration tender provides for a two year plant operation and maintenance
service.
• Because these plants will be highly integrated in the Rand Water network, skills
transfer during the contract period will be prioritised. This will ensure that Rand
Water’s primary operations are not compromised when the contract ends.
•
• It is also envisaged that these plants will be largely unmanned and fully automated;
only to be attended to if there is a problem.
RISKS
Risk item Impact Probability Mitigation
Pressure surges High Medium Hydraulic surge analysis during
design phase
Reservoir isolations Medium High Design to provide for flow with an
isolated reservoir
Turbine isolations Medium High Isolation valves to allow normal
water flow when turbine isolated.
Interest rate fluctuations Medium High Financial model provides CPI linked
energy rates
Exchange rate fluctuations Medium High Provision made in the financial
model
Wheeling cost changes High Medium Contract agreements with
municipalities and Eskom to be
expedited.
Authorizations / Licenses delays High Medium Construction period will take 2 years
and this time will be used to
expedite applications.
SEQUENCE OF EVENTS SINCE PROJECT INCEPTION
2006 – High level investigation on hydro power generation
carried out by Rand Water.
June 2007 – SSI appointed as Consultant for the four hydro power
stations.
May 2008 – Rand Water board approves Rand Water participation in
Eskom’s PNCP scheme.
January 2009 – REFIT scheme launched and proves to be more attractive
than the PNCP scheme.
May 2009 – Investigation started on appropriate business model for
Rand Water.
December 2010 – Trans African Energy (Pty) Ltd submits a report on
implementation strategy for Rand cogeneration project.
March 2011 – The tender for the cogeneration project issued.
July 2011 – The tender closed with four tenders received.
November 2011 – Tender evaluation process completed.
April 2012 - Tender for cogeneration cancelled due to non-
responsiveness of tenders & budget review.
Thank you
QUESTIONS / CLARIFICATIONS
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