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DMM 2017 Q1 Report Highlights
Gabe Murtaugh – Senior Analyst, Monitoring and ReportingDepartment of Market MonitoringCalifornia ISO
Conference callJuly 31, 2017
Discussion outline
Page 2
• ISO market results
• EIM market results
• Load adjustments
• Special Issues– Aliso Canyon gas constraints– Load bias limiter
Prices declined in the first quarter because of low loads and high renewable generation.
Page 3
$0
$10
$20
$30
$40
$50
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar
2016 2017
Pric
e ($
/MW
h)
Day-ahead 15-Minute 5-Minute
Net loads were lower in the afternoon and prices followed a similar pattern.
Page 4
0
4,000
8,000
12,000
16,000
20,000
24,000
28,000
32,000
$0
$10
$20
$30
$40
$50
$60
$70
$80
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Aver
age
net s
yste
m lo
ad (M
W)
Pric
e ($
/MW
h)
Day-ahead 15-minute 5-minute Average net load
Day-ahead prices were consistently negative during the quarter.
Page 5
0%
5%
10%
15%
20%
25%
30%
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Perc
ent o
f hou
rs
-$15 to $10 -$10 to -$5 -$5 to $0 $0 to $1
Low loads and abundant renewables caused frequent negative prices in real-time.
Page 6
0%
2%
4%
6%
8%
10%
12%
14%
16%
18%
20%
22%
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar
2016 2017
Perc
ent o
f 5-m
inut
e in
terv
als
Below -$145 -$145 to -$50 -$50 to $0
With negative prices the ISO reduced more renewable output this quarter than.
Page 7
0%
1%
2%
3%
4%
5%
6%
0
20,000
40,000
60,000
80,000
100,000
120,000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar
2016 2017
Perc
ent r
educ
tion
Meg
atw
att h
our
Total economic decremental dispatch
Total self-scheduled curtailment
Wind and solar percent reduction
Virtual bidders made payments to the ISO for the second consecutive quarter.
Page 8
-$4
$0
$4
$8
$12
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar
2016 2017
$ m
illio
n
Virtual supply net revenueVirtual demand net revenueTotal bid cost recovery chargesTotal revenues less charges
Auction revenues continued to be less than payments made to CRR holders.
Page 9
0%
30%
60%
90%
120%
150%
$0
$20
$40
$60
$80
$100
$120
$140
$160
$180
$200
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017
Perc
ent o
f auc
tione
d C
RR
pay
men
ts
Rev
enue
s an
d pa
ymen
ts ($
mill
ion)
Auction revenues received by ratepayersPayments to auctioned CRRsAuction revenues as a percent of payments
EIM prices were lower in Northwest areas during many hours because of congestion.
Page 10
$0
$10
$20
$30
$40
$50
$60
$70
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Aver
age
hour
ly p
rice
($/M
Wh)
PacifiCorp East, NV Energy, and Arizona Public ServicePacifiCorp West and Puget Sound EnergySouthern California EdisonPacific Gas and Electric
EIM prices in Puget and Arizona were significantly impacted by transition pricing.
Page 11
Dollars PercentPuget Sound Energy 15-minute market (FMM) $18.75 $19.16 -$0.41 -2.1% 5-minute market (RTD) $15.54 $17.31 -$1.77 -10.2%Arizona Public Service 15-minute market (FMM) $19.45 $8.64 $10.81 125% 5-minute market (RTD) $17.44 $5.13 $12.31 240%
Average EIM price
Estimated EIM price without transition
period pricing
Estimated impact of transition period pricing
Frequent flex ramp sufficiency test failures limited transfers to and from Arizona.
Page 12
0%
10%
20%
30%
40%
50%
60%
Nov Dec Jan Feb Mar
2016 2017
Perc
ent o
f hou
rs
PacifiCorp East PacifiCorp West NV EnergyPuget Sound Energy Arizona Public Service
NV Energy continued to receive imports from the ISO during the middle of the day.
Page 13
-300
-200
-100
0
100
200
300
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Impo
rts
into
NV
Ener
gy (M
W)
PacifiCorp East to NV Energy California ISO to NV Energy
Average transfer
Arizona increased positive load adjustments in 2017.
Page 14
0%10%20%30%40%50%60%70%80%90%
100%O
ctN
ovD
ec Jan
Feb
Mar Oct
Nov
Dec Jan
Feb
Mar Oct
Nov
Dec Jan
Feb
Mar Oct
Nov
Dec Jan
Feb
Mar Oct
Nov
Dec Jan
Feb
Mar Oct
Nov
Dec Jan
Feb
Mar
2016 2017 2016 2017 2016 2017 2016 2017 2016 2017 2016 2017
California ISO PacifiCorpEast
PacifiCorpWest
NV Energy Puget SoundEnergy
Arizona PublicService
Perc
ent o
f int
erva
ls
Negative load adjustment Positive load adjustment
• Permanently update day-ahead indices with ICE information
• Use Monday only trading information on ICE to update day-ahead market index
• Update indices in real-time market with same day gas information
• Clarify after-the-fact recovery provisions
Page 15
Recommended approach for Phase 1:Use available gas information
Aliso measures related to gas constraints should be carefully considered because of gas trade data and the mitigation process.
Page 16
60% 80% 100% 120% 140%0%
10%
20%
30%
Perc
ent o
f tra
ded
volu
me
Trade price as percent of next-day average
First trade-day of week
Other days
110% 125%
Aliso measures related to gas constraints should be carefully considered because of gas trade data and the mitigation process.
Page 17
60% 80% 100% 120% 140%0%
15%
30%
45%
60%
Perc
ent o
f tra
ded
volu
me
Trade price as percent of average at 8:30 a.m.
110% 125%
Proposed changes to load bias limiter would reduce impact on prices.
Page 18
0
200
400
600
800
Power balance excess Power balance insufficiency
CAISO
Num
ber o
f 5-m
inut
e in
terv
als
(201
6) Current load bias limiter not triggered
Current load bias limiter tiggered
Proposed load bias limiter triggered
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