1
A Conversation about MISO
Paul Spicer
November 8, 2007
2
How does the MISO Market affect you-the industrial customer
Electric Rates Capacity Transmission Energy
Market pricing index during economic interruptions Day-ahead Real-time
Delivery reliability October 06 (Weston Lightning Strike) ASM opportunity?
3
Electric Rates
Capacity Reserve margins
Currently no uniform requirement Wisconsin ~ 18% during summer months
MISO records reserves in “Module E” Resources can count if the they are “deliverable” to the market Resources can count if they are local capacity (firm tx) This has enabled more short-term capacity transactions
WPSC has gained about $1.5 million from these transactions
These revenues go through the Wisconsin Fuel Rules as a credit to Purchase Power costs
4
Electric Rates
Transmission Network Service
From Designated Network Resources (DNRs) To Network Load 12 CP Coincident Peak Zonal Price (ATC zone for us) Currently about $32.50/Kw-year for Network Charge
Schedule Charges currently about $3/Kw-year Schedule 1 (System Control) Schedule 2 (Reactive Supply) Schedule 10 (Scheduling/reliability/market planning) Schedule 26 (Network Upgrade) FERC Charges
Creates entitlement to candidates for allocated FTRs
5
Electric Rates
Transmission
6
Electric Rates Energy
Portfolio Approach
GenerationGenerationGenerationGeneration
GenerationGenerationGenerationGeneration
Fuel
Electricity(to MISO)
DistributionDistributionDistributionDistribution
Electricity(from MISO)
Dollars for
Fuel
Dollars for Generator’s Electricity(from MISO)
Dollars for Electricity
Consumed (to MISO)
Dollars for rights to use transmission
(to ATC)
Dollars for Financial
Transmission Rights (FTR)
(from MISO)
Dollars for market
administration and up-lift
(to MISO)
7
Electric Rates Energy
8
Electric Rates Energy
Importing Utility Perspective
Day-ahead LMP Comparison by MISO Region
$0.00
$5.00
$10.00
$15.00
$20.00
$25.00
$30.00
$35.00
$40.00
$45.00
$50.00
$55.00
$60.00
$65.00
$70.00
$75.00
ILLINOIS MICHIGAN MINNESOTA WPSC WEC-South
Location
$/M
Wh
r 2005
2006
2007
9
Electric Rates Energy
Importing Utility Perspective
-600 -500 -400 -300 -200 -100 0 100 200 300 400 500 600 700 800
0
50
100
150
200
250
MW of Import (negative) or Export (positive)
Day-ahead Net Import/Export for September 2007
Sept 07 with W4
Sept 07 Actual
10
Market Pricing During Day-ahead Economic Interruptions
Ratio of Day-ahead LMP and Economic Interruption Threshold Price (EITP)
0.00
0.20
0.40
0.60
0.80
1.00
1.20
1.40
1.60
0% 5% 10%15%
20%25%
30%35%
40%45%
50%55%
60%65%
70%75%
80%85%
90%95%
100%
Percent of Hours in 2007
Rat
io (
LM
P/E
ITP
)
Based on WPSC LMP
about 225 hours
11
Market Pricing During Day-ahead Economic Interruptions
Ratio of Day-ahead LMP and Economic Interruption Threshold Price (EITP)
0.00
0.20
0.40
0.60
0.80
1.00
1.20
1.40
1.60
0% 5% 10%15%
20%25%
30%35%
40%45%
50%55%
60%65%
70%75%
80%85%
90%95%
100%
Percent of Hours in 2007
Rat
io (
LM
P/E
ITP
)
Based on WPSC LMP Based on MISO Average
about 225 hours
About 70 hours
12
Market Pricing During Day-ahead Economic Interruptions
Comparison of Day-ahead and Real-time LMP During Economic Interruption
0
200
400
600
800
1000
1200
1400
100 110 120 130 140 150 160 170 180 190
Day-ahead LMP ($/MWhr)
Real-
tim
e L
MP
($/M
Wh
r)
Actual Real-time LMP Day-ahead = Real-time LMP
Average Day-ahead LMP = $135/MWhrAverage Real-time LMP = $130/MWhrReal-time was better 66% of the time, butRSG fees average $4/Mwhr making the two alternatives near equal.
October 8Scarcity
Price
13
Average of Real-time 5 minute LMPs as a Predictor of Settlement Real-time LMP
0%
50%
100%
150%
200%
250%
300%
350%
400%
0 5 10 15 20 25 30 35 40 45 50 55 60
Clock Minute Average
2 S
tan
dar
d D
evia
tio
ns
of
Per
cen
t P
rice
Example: If the average of the four 5 LMPs (20 minutes) is $100/MWhr, you can be 95% confident that the actual settlement LMP will be less than (1.9*$100/MWhr) $190/MWhr. If by 35 minutes into the hour the average of seven 5 minute LMPs continues to be $100/MWhr, then you can be 95% confident that the settlement LMP will be less than (1.5*$100/MWhr) $150/MWhr.
14
Reliability Importing Utility Perspective
Day-ahead Import/Export Since W3 Outage on October 6th, 2007
0
20
40
60
80
100
120
140
-1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100 200 300 400 500
Ho
urs
15
Reliability
Ancillary Service Market (ASM) Regulation
Second to second generator control and frequency response Performed today by local “Balancing Authorities”
Operating Reserve- Spinning Generators synchronized to the grid Generally used for contingency response Performed today by local “Balancing Authorities” and the Contingency
Reserve Sharing Group (CRSG) Operating Reserve- Supplemental
Fast acting (not necessarily connected) resources including load response
Generally used for contingency response Performed today by local “Balancing Authorities” and the Contingency
Reserve Sharing Group (CRSG)