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For Discussion Purposes Only DRAFT - DRAFT
Comparison of Regional Reliability Techniques
Presented to PSPC
November 22, 2004
Westborough, MA
For Discussion Purposes Only DRAFT - DRAFT
Purpose of Presentation
• Compare various planning assumptions– NPCC Regions– PJM
• Follow-up to the November 18th Meeting• Begin comprehensive discussions of ISO-NE
assumptions for 2005/06 Objective Capability• Caveats:
– Preliminary data for other areas needs further review
For Discussion Purposes Only DRAFT - DRAFT
Comparison of Regional Metrics
• “Regional Practices” review to:– Identify range of practices that are in use– Allow relative comparison among industry participants– Establish hypotheses for benefits / problems with outliers
• Several industry metrics will be reviewed:– Reserve margin percentages– Tie benefits as a percent of reserve margins – Tie benefits as a percent of regional reserves
• Impact of Emergency Operating Procedures
For Discussion Purposes Only DRAFT - DRAFT
Reserve Margins
Data Needs Further Review
Required Reserve Margin Comparison (Percent)
0.0
5.0
10.0
15.0
20.0
25.0
Region
Re
qu
ire
d R
es
erv
e M
arg
in
(Pe
rce
nt)
Required Reserves
For Discussion Purposes Only DRAFT - DRAFT
Tie Benefits Part of Reserves
Data Needs Further Review
Tie Benefits as a Percent of Required Reserves (Percent)
0
10
20
30
40
50
Region
Tie
Be
ne
fits
as
a P
erc
en
t o
f R
eq
uir
ed
Re
se
rve
M
arg
in
Tie Benefits as a Percent of Required Reserve Margin
Note: PJM’s 3500 MW CBM Converted to 1500 MW Firm Equivalent Tie Benefit
For Discussion Purposes Only DRAFT - DRAFT
1995 Monthly Load Profiles
2004 Projected Coincident Monthly Peak Loads - MW1995 Load Shape
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
MW
Q MT NE NY ON
For Discussion Purposes Only DRAFT - DRAFT
2002 Monthly Load Profiles
2004 Projected Coincident Monthly Peak Loads - MW2002 Load Shape
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
MW
Q MT NE NY ON
For Discussion Purposes Only DRAFT - DRAFT
NERC Region Monthly Profiles
2004 Projected Coincident Monthly Peak Loads - MW
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
MW
NPCC MAAC ECAR
For Discussion Purposes Only DRAFT - DRAFT
Weather Based LFU
Weather Based Load Forecast Uncertainty
0.00
0.10
0.20
0.30
0.40
0.50
0.60
0.70
0.80
0.90
1.00
0.88
0.90
0.92
0.94
0.96
0.98
1.00
1.02
1.04
1.06
1.08
1.10
1.12
1.14
Multiplier
Cu
mu
lati
ve P
rob
abil
ity
Q MT NE NY ON
For Discussion Purposes Only DRAFT - DRAFT
NPCC Operating Procedures to Mitigate Resource Shortages
Excludes Elimination of Required 10 and 30 Minute Operating Reserves
Actions Q MT NE NY ON PJM1. Curtail Load / Utility Surplus 0 0 45 0 450 0 LRP/SCR/EDRP 0 0 331 785 0 0 Manual Voltage Reduction 0 0 0 80 0 0
0.26%of load
2. No 30-min Reserves (a) (a) (a) (a) (a) (a)
4. No 10-min Reserves (a) (a) (a) (a) (a) (a)5. General Public Appeals 0 0 0 213 200 0
3. Voltage Reduction or Interruptible Loads 300 464 0580
365 1.42% of
load
500 1.59% of
load
NA
For Discussion Purposes Only DRAFT - DRAFT
Operating Procedures to Mitigate Resource Shortages (MW)
0
200
400
600
800
1000
1200
1400
1600
1800
Q MT NE NY ON PJM
MW
of
Lo
ad R
elie
f
Curtail Load / Utility Surplus LRP/SCR/EDRP Manual Voltage Reduction
Voltage Reduction or General Public Appeals
Emergency Operating Procedures
NA
For Discussion Purposes Only DRAFT - DRAFT
Emergency Operating Procedures
Operating Procedures to Mitigate Resource Shortages (Percent of Peak)
0.000
0.010
0.020
0.030
0.040
0.050
0.060
0.070
0.080
0.090
Q MT NE NY ON PJM
MW
of
Lo
ad R
elie
f
Curtail Load / Utility Surplus LRP/SCR/EDRP Manual Voltage Reduction
Voltage Red or Intr Load General Public Appeals
NA
For Discussion Purposes Only DRAFT - DRAFT
Risk Profile For NPCC Regions
0
1
2
Estimated Number of
Occurrences (days/period)
NE NY ON MT HQ
Reduce 30-min Reserve Voltage Reduction Reduce 10-min Reserve Appeals Disconnect Load
With Resources Currently Available
For Discussion Purposes Only DRAFT - DRAFT
EFORd Affects PJM IRM
PJM Review of IRM vs. EFORd
0
5
10
15
20
25
1999
/200
0
2000
/200
1
2001
/200
2
2002
/200
3
2003
/200
4
2004
/200
5
2005
/200
6
Year
PJM
Rec
om
men
ded
IR
M
0.00%
2.00%
4.00%
6.00%
8.00%
10.00%
12.00%
Ave
rag
e E
FO
Rd
IRM Avg. EFORd
Source: http://www.pjm.com/committees/reliability/downloads/20040803-item4-irm-study.pdf
Note: PJM’s EFORd rate does not include two (2) assumed large units whose maintenance is shifted over the summer peak load season.
Each large unit has about 1.7 % effect on IRM
For Discussion Purposes Only DRAFT - DRAFT
Sensitivity of OC to Parameters
July Objective Capability Values
27,800
28,000
28,200
28,400
28,600
28,800
29,000
29,200
29,400
29,600
03-04 OC UpdatedLoad
Forecast
UpdatedCapacityValues*
UpdatedEFORs
July
OC
(M
W)
752 MW
227 MW
03-04 OC Value