nypd3 selective reopener nersa public hearings - 23 june 2015
TRANSCRIPT
Eskom MYPD3 Selective Re-opener
Public Hearings
23 June 2015
Agenda
1
• Introduction
• Breakdown of the selective reopener
• Operational and financial challenges
• Benefit of OCGT and STPPP usage
• Conclusion
Regulatory rules allow application to reopen tariffs if circumstances significantly change from the decision
2
Eskom has implemented initiatives to operate within the 8% tariff increase
The original decision is removed from current realities
Eskom, therefore, needs a selective reopener to address immediate
operational and financial challenges
The selective reopener (9.58%) will fund higher OCGT usage and cover the
cost of STPPP capacity which requires
R32.5bn for OCGTs over MYPD3 (6.43%)
R17.5bn for STPPP over MYPD3 (3.15%)
Alternatively, costs would be recovered through the RCA process
retrospectively if necessary, once deemed prudent by Nersa
OCGTs and STPPP will be purely used to reduce intensity of load shedding
and cost to the economy
The selective reopener application will add 9.58% to the already approved 12.69% for 2015/16
3
2015/16 Comments
Rest of normal costs and returns 6.8%
Open cycle gas turbines (OCGTs) 0.1% Allowed R1,5bn
Other IPPs (Renewables and DOE Peaker) 0.7% Allowed R14.4bn
Short term power procurement programme (STPPP) 0% Allowed R0bn
Environmental levy 0.4% Allowed R9.3bn
MYPD3 Original price decision 8.0%
MYPD2 RCA clawback decision by Nersa 4.69%
Revised price already granted by Nersa 12.69% Nersa decision awarded after
RCA
Selective Reopener 9.58% Required to reduce load
shedding
- Open cycle gas turbines (OCGTs) 6.43% Applied for R10.9bn
- Short term power procurement programme (STPPP) 3.15% Applied for R5.3bn
Environmental levy increase *(if gazetted) 2.51% Pass through of levy costs
Overall price to consumer (1+2+3) 24.78%
1
2
3
A tariff increase is required to leverage supply options and reduce the impact of load shedding on the economy
4
Changes to
assumptions in the
MYPD application
have resulted in
reduced capacity
and space to
reduce backlog
maintenance
The selective
reopener is aimed at
reducing levels of
load shedding to
reduce the impact
on the economy
Eskom has lived within MYPD3 8% tariff decision
through
‒ Optimisation and reduction of the cost base,
achieved through an internal efficiency program
‒ Maximised borrowings by leveraging the balance
sheet
‒ Shareholder equity injection
Tariffs are not cost reflective
Financial
Operational
Ageing Generation fleet
Delays to the New Build Programme have been
exacerbated by major incidents (e.g. Duvha, Majuba)
Challenge Circumstances
Availability of OCGTs and STPPP reduced peak hour load shedding in April by more than 50%
5
Load shedding avoided during April 2015, due to OCGT and STPPP usage
MW
OCGTs and STPPP
usage reduced load
shedding by
providing additional
capacity
If OCGTs and STPPP
were not dispatched
in April, load
shedding would have
been required
everyday
Actual load
shedding was
reduced by more
than 50% owing to
OCGTs and STPPP
Without OCGTs and STPPP load shedding will be more regular and severe
- Shortfall is calculated on demand and
1000MW operational reserves
- Shortfall does NOT take primary
energy constraints into account
0
01. A
pr
2015
500
1,000
2,000
3,000
4,000
5,000
6,000
1,500
2,500
3,500
4,500
5,500
6,500
30. A
pr
2015
29. A
pr
2015
28. A
pr
2015
27. A
pr
2015
26. A
pr
2015
23. A
pr
2015
22. A
pr
2015
21. A
pr
2015
20. A
pr
2015
19. A
pr
2015
18. A
pr
2015
17. A
pr
2015
16. A
pr
2015
15. A
pr
2015
14. A
pr
2015
13. A
pr
2015
12. A
pr
2015
11. A
pr
2015
10. A
pr
2015
09. A
pr
2015
08. A
pr
2015
07. A
pr
2015
06. A
pr
2015
05. A
pr
2015
04. A
pr
2015
03. A
pr
2015
02. A
pr
2015
24. A
pr
2015
25. A
pr
2015
Actual Load shedding Load shedding without OCGTs Load shedding without STPPP
Eskom agrees that cost savings setoff must be taken into account but computation thereof must be correct
6
Selective reopener for 2015/16 Unit STPPP OCGTs TOTAL
Energy volumes GWh 5 794 5 400 11 194
Costs applied for Rands R5 357m R10 950m R16 307m
Net costs after costs savings setoff
Generation total price – 53c/kWh Rands -R5 933m R10 374m
Generation variable price – 23c/kWh Rands -R2 575m R13 732m
• MYPD3 decision of 8% included recovery of costs of production from Generation stations
• Eskom can only offset the price which was incorporated in the original MYPD3 decision
• In 2015/16 the total selling price awarded by Nersa was 75c/kWh which covers the entire Eskom value
chain of Generation, Transmission and Distribution
• Generation business comprises about 75% of the Eskom operations and thus its contribution is
53c/kWh
• However within the Generation business there are fixed and variable cost components which are linked
to production. Hence only variable costs of 23c/kWh must be used for calculating cost set off savings
Approach to computing cost savings setoffs
1
2
Costs savings setoff cannot exceed the total selling price of 75c/kWh . The offset of R2.5bn will
reduce the price from 9.58% to ~8%
Eskom discounts on diesel purchases are included in the calculation of additional funding for OCGTs
7
Eskom discounts on diesel purchases were included in the calculation of
the R12.5bn requirement for FY2016. These discounts include
• R3.10/litre rebate
• R0.30/litre wholesale discount
Key insights
▪ Only 2.8% of post
outage UCLF was as a
result of direct
execution quality, owing
to outage work well
within the 10% target
▪ Drivers of post outage
UCLF include
– Postponed mid life
refurbishment of
units
– Insufficient funding
– Capacity constraints
forcing outages to be
postponed
▪ Postponement of
outage scope accounts
for the majority of post
outage UCLF
2.80.1
1.82.00.2
5.64.44.6
0.0
6.19.1
1.01.8
17.3
27.229.0
25.123.1
18.019.718.718.5
11.6
3.44.52.5
Ave Apr May Mar Feb Jan Dec Nov Oct Sep Aug Jul Jun
Post maintenance UCLF on areas within scope is well within international standards and target
Post outage UCLF as a result of direct execution quality UCLF % (June 2014 – May 2015)
Post outage UCLF as a result of other plant failures UCLF % (June 2014 – May 2015)
8
Transmission technical performance measures meet and exceed Nersa targets
Year SM < 1 MI's LF/100km
2003/04 2.398 1 1.90
2004/05 4.555 0 2.20
2005/06 3.131 4 2.60
2006/07 3.486 1 2.70
2007/08 3.564 5 2.31
2008/09 4.211 3 2.46
2009/10 4.09 1 2.54
2010/11 2.626 0 2.72
2011/12 4.733 1 2.41
2012/13 3.519 3 1.74
10 Y Avg 3.6 1.9 2.36
St Dev 0.78 1.73 0.33
Historical Performance
Major Incidents System Minutes < 1
Line Faults/100km
9
2015 = 2.85 2014 = 3.05
2014 = 0
2015 = 2
2014 = 1.73 2015 = 2.01
Distribution technical performance measure, SAIDI, meets and exceed Nersa targets
The system average interruption duration index (SAIDI) scheme consists of a dead band, an
incentive/reward zone and a penalty zone as indicated. Both the incentive/reward and penalty zones
are capped at R145.9m (50% weight) per annum. There is a dead band between the incentive and
penalty. Improved performance is lowering the number
Incentive
between green
and brown
Dead band
black box
Penalty
between blue
and orange
10
Conclusion
11
The selective reopener is required to improve supply options available to Eskom
so that
‒ Load shedding can be minimised
‒ System stability can be improved
‒ Impact on the economy is reduced
Owing to operational challenges, high cost supply options must be deployed to
meet demand which include OCGTs and STPPP
Additional OCGT and STPPP usage costs are low compared to the effect of load
shedding on economic sustainability
Load shedding costs R9-R15/kWh1 compared to OCGT costs ~R3/kWh
Every R1bn spent on OCGTs saves the economy up to R4bn
MYPD3 approved tariffs do not include allowance for recovery of STPPP costs
and only a small allowance for OCGT costs
Access to funding is limited which has resulted in the need to request additional
tariff increases rather than wait for an RCA claw back
1. Source Trade & Industrial Policy Strategies (TIPS)_February 2015