Managing consultant and power industry veteran, Bill Babcock, presented on "Nodal Insights for Generation Owners" at the 2014 EMFC and discusses why both local and interregional transmission constraints matter. He outlines what constitutes nodal hub prices vs. zonal prices, and discusses the role shift factors, congestion, and marginal losses have on prices. Based on work he has done modeling PJM with AURORAxmp’s Nodal Capability, including its LMP contributions output report, Bill shows how to identify those constraints that drive congestion-based LMP differences. Visit http://epis.com/xmp_in_action/real_examples.php for more real examples of AURORAxmp in action or visit http://epis.com/aurora_xmp/nodal_analysis.php to see more about Nodal Insights.

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NODAL INSIGHTS
2014 Electric Market Forecasting
Conference
September 17-19, 2014

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Overview
Nodal Background
• Constraints -- $ matter
• What’s in a Hub price? What’s in a Zonal price?
Shift Factors and Congestion
Pricing Considerations
• Congestion
• Marginal Losses
Nodal vs. Zonal – the role of Interregional and Local Constraints

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Four constraints account for 50+% of projected 2015 PJM congestion
______________________________
Source: PJM Market Efficiency Analysis Base Congestion Results
0%
2%
4%
6%
8%
10%
12%
14%
16%
18%
20%
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%

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Two of the top four constraints are M2M
Source: PJM Market Efficiency Analysis Base Congestion Results
Facility Name Area Constraint Type
Frequency
(Hours)
Market
Congestion ($
Millions)
Share of 2015
Congestion (%)
Cumulative 2015
Congestion (%)
AP SOUTH L/O BED-BLA PJM INTERFACE 1,627 103.6 17% 17%
Monticello to East Winamac 138 kV M2M LINE 2,569 99.0 17% 34%
Oak Grove to Galesburg 161 kV M2M LINE 3,281 60.0 10% 44%
Cloverdale to Lexington 500 kV AEP - DVP LINE 631 37.0 6% 51%
Elliot to Elliot 138 kV AEP LINE 338 30.0 5% 56%
AEP-DOM L/O BED-BLA PJM INTERFACE 706 26.7 5% 60%
Graceton to BAGLEY 230 kV BGE LINE 826 22.0 4% 64%
Miami Fort to Willey 138 kV DEO&K LINE 310 20.0 3% 67%
Braidwood to East Frankfort 345 kV CE LINE 147 18.0 3% 70%
Hunterstown 230 kV ME XFMR 254 18.0 3% 73%
Dravosburg to West Mifflin 138 kV DLCO LINE 1,275 14.4 2% 76%
Tiltonsville to Windsor 138 kV AP - AEP LINE 36 12.4 2% 78%
Wurno to Claytor Lake 138 kV AEP LINE 84 11.0 2% 80%
Cordova to Nelson 345 kV CE LINE 333 9.9 2% 81%
Belvidere to Marengo Tap 138 kV CE LINE 227 8.0 1% 83%
WESTERN INTERFACE PJM INTERFACE 257 7.1 1% 84%
CENTRAL INTERFACE PJM INTERFACE 658 6.6 1% 85%
6EDFERRY to Dickerson Station "D" 230 kV PEPCO - DVP LINE 39 6.3 1% 86%
Hennepin to Hennepin 138 kV M2M LINE 570 5.9 1% 87%
Kewanee to E D Edwards 138 kV M2M LINE 298 5.9 1% 88%
Cherry Valley to Cherry Valley 138 kV CE LINE 119 5.3 1% 89%
Woodville to 15USAP 138 kV DLCO LINE 449 5.0 1% 90%
2014 Market Efficiency Analysis Base Congestion Results: 2015 System Topology

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PJM East Hub – it may not be what you think
ISO hubs typically consist of numerous individual nodes.
Nodes can be geographically and electrically diverse,
making it difficult to isolate the impact of individual
transmission constraints.
• PJM East consists of 216 individual nodes
• 84% of the nodes are load nodes
• 49% of the nodes are located in the Delmarva area
• 92% are located in PECO and Delmarva
Transmission Zone EHV GEN LOAD Total % Total
AECO 1 1 0%
DPL 14 99 113 49%
JCPL 1 1 0%
PECO 17 81 98 43%
PPL 1 1 0%
PSEG 1 4 10 15 7%
Total 1 36 192 229 100%
% Total 0% 16% 84% 100%
Bus Type
PJM East Hub Definition

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Load buses dominate the composition of PJM Hub definitions
Hub
Total
Buses EHV GEN LOAD Total
AEP GEN HUB 39 100% 100%
AEP-DAYTON HUB 1108 11% 89% 100%
ATSI GEN HUB 64 100% 100%
CHICAGO GEN HUB 131 100% 100%
CHICAGO HUB 190 5% 95% 100%
DOMINION HUB 626 12% 88% 100%
EASTERN HUB 216 0% 15% 84% 100%
N ILLINOIS HUB 219 11% 89% 100%
NEW JERSEY HUB 367 100% 100%
OHIO HUB 761 4% 96% 100%
WESTERN HUB 99 4% 27% 69% 100%

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Pricing in the PECO zone: Congestion and Marginal Losses

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While average losses basis differentials can be larger than congestion basis
differentials, variation in congestion basis differentials is an order of magnitude
greater.
Liberty Basis Basis Component Year*
Average Basis
($/MWh)
Standard
Deviation
Coefficient of
Variation
2009 (1.48) 1.69 114
2010 (2.56) 5.74 224
2011 (1.66) 2.82 170
2012 (2.98) 4.69 157
2009 (1.25) 0.80 64
2010 (1.60) 1.22 76
2011 (1.52) 1.17 77
2012 (1.46) 0.74 51
2009 (0.23) 1.26 544
2010 (0.96) 5.15 538
2011 (0.14) 2.48 1,782
2012 (1.53) 4.46 293
2009 (0.31) 0.34 110
2010 (0.90) 5.52 616
2011 (0.36) 2.21 611
2012 (0.22) 0.25 112
2009 (0.37) 0.28 75
2010 (0.45) 0.43 95
2011 (0.31) 0.40 127
2012 (0.24) 0.12 51
2009 0.06 0.23 410
2010 (0.44) 5.32 1,198
2011 (0.05) 2.09 4,192
2012 0.02 0.22 1,321
* 2012 values for the period through 3/31/2012
Variation in Basis Differentials
LibertyBasistoPECOZone
Total LMP Basis
Loss Basis
Congestion Basis
Total LMP Basis
Loss Basis
Congestion Basis
LibertyBasistoPJMEastHubUnitBasistoPECOZoneUnitBasistoPJMEastHub

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Shift factors represent the change in power flow on a line when an injection is made
at one bus and a corresponding change in withdrawal is made at the reference bus
Shift factors are calculated for a specific system topology. Shift factors change when the
topology changes or line impedance changes. Shift factors do not change if the
injection/withdrawal amount increases for any set of locations.
Source: CAISO

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Generators that drive flows on the Eddystone-Island Road Constraint
Unit(s) S.F. Description
Eddystone 3 .252 380 MW oil/gas-fired steam (Exelon Generating)
Eddystone CT .250 (4) 18-20 MW oil-fired CTs (Exelon Generating)
Eddystone 4 .247 380 MW oil/gas-fired steam (Exelon Generating)
Liberty CC .231 540 MW gas-fired CC (Equipower Resources)
Marcus Hook .139 808 MW gas-fired CC (NextEra Energy)
Hay Road 4 .116 182 MW gas-fired CT (Calpine)
Edge Moor 5 .116 445 MW oil/gas-fired steam (Calpine)
Hay Road 1, 3 .088 (2) 121 MW gas-fired CT (Calpine)
Edge Moor 3, 4 .088 86 MW and 174 MW gas-fired steam (Calpine)
Units that Increase Congestion on the Eddystone–Island Road Constraint
Unit(s) S.F. Description
Southwark -.175 (4) 18 MW oil-fired CTs (Exelon Generation)
Schuylkill CT -.170 (2) 18 MW oil-fired CTs (Exelon Generation)
Grays Ferry Cogeneration -.167 150 MW gas-fired CC (Veolia Environnement S.A.)
Schuylkill -.164 175 MW oil-fired steam (Exelon Generation)
Delaware CT -.100 (4) 18 MW oil-fired CTs (Exelon Generating)
Richmond -.058 (2) 65 MW oil-fired CTs (Exelon Generating)
Fairless Works -.036 (2) 680 MW gas-fired CCs (Dominion)
Croydon -.035 (8) 60 MW oil-fired CTs (Exelon Generating)
Burlington GT -.035 (13) mostly 40-50 MW oil/gas-fired CTs (PSEG)
Limerick 1 -.025 1190 MW nuclear (Exelon Generating)
Limerick 2 -.018 1190 MW nuclear (Exelon Generating)
Units that offset Congestion on the Eddystone–Island Road Constraint

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Pricing across PJM reflects local and broader regional constraints
Western
Hub
AEP –
Dayton Hub
NI Hub

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Generators competing for west to east transfer across Black Oak – Beddington
Unit/Bus Area Shift Factor
Capacity at
Node (MW)
Potential Impact
on Constraint
% of
Potential
Impact
Cum %
Potential
Impact
Hatfield AP 0.115 1,550 178 9.6% 9.6%
02MNFDG3 FE 0.033 2,682 88 4.7% 14.3%
Harrison AP 0.040 1,901 76 4.1% 18.4%
Fort Martin AP 0.066 1,072 71 3.8% 22.2%
Sammis FE 0.032 1,925 62 3.3% 25.5%
15BVRVL1 DLCO 0.033 1,866 62 3.3% 28.9%
05GVG1 AEP 0.017 2,620 45 2.4% 31.3%
05RKG2 AEP 0.014 3,095 42 2.3% 33.5%
KEYS G2 PJM 0.024 1,642 40 2.1% 35.7%
05CDG3 AEP 0.032 1,215 39 2.1% 37.7%
01PLEAS1 AP 0.031 1,222 38 2.0% 39.8%
Twin Ridges AP 0.183 200 37 2.0% 41.7%
02CALPG2 FE 0.022 1,633 36 1.9% 43.7%
Warrior Run AP 0.200 176 35 1.9% 45.6%
09STUART DAY 0.015 2,255 34 1.8% 47.4%
02PERRG1 FE 0.026 1,281 33 1.8% 49.2%
05CVG4 AEP 0.020 1,580 32 1.7% 50.9%

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The broader regional transmission system will be improved if/when the Byron to
Wayne 345 kV line is added
Transmission flows
across ComEd are
generally west-to-
east and are limited
by the constraints
involving the two
large 345 kV lines,
and its interaction
with the underlying
138 kV system.

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Shift factors differ substantially, even for units located geographically close together
AEP PJM
Contingent Branch Monitored Element
From
Area
To
Area
All Gen:
Max -
Min
Gen in
ComEd
Zone:
Max -
Min Gavin Wauk Byron Dresden Kincaid Zion Keystn
CHERRY VA; R_SILVER LK; R NERC_FG_ID_3771 WEC CE 0.207 0.207 0.000 0.091 0.119 (0.016) 0.000 (0.088) 0.000
05DUMONT_WILTON ; NERC_FG_ID_2286 CE NIPS 0.242 0.190 0.023 (0.132) (0.120) (0.137) (0.079) (0.132) 0.023
NERC_FG_ID_3771 WEC CE 0.180 0.180 0.000 0.098 0.077 (0.014) 0.000 (0.082) 0.000
NERC_FG_ID_2286 CE NIPS 0.179 0.176 0.013 (0.075) (0.068) (0.076) (0.043) (0.076) 0.013
05DUMONT_WILTON ; NERC_FG_ID_2515 NIPS CE 0.152 0.089 (0.018) 0.110 0.100 0.113 0.065 0.110 (0.018)
GARFIELD ; R_To_TAYLOR ; R CE CE 0.077 0.077 0.007 (0.027) (0.022) (0.023) (0.008) (0.027) 0.007
NERC_FG_ID_3222 E FRANKFO; R_To_E FRxmid CE CE 0.074 0.074 0.002 (0.016) (0.012) (0.024) (0.008) (0.016) 0.002
NERC_FG_ID_2515 NIPS CE 0.097 0.074 (0.010) 0.065 0.058 0.064 0.036 0.065 (0.010)
NERC_FG_ID_2407 AEP-DOM AEP DVP 0.163 0.041 0.189 0.065 0.053 0.071 0.044 0.065 0.027
8MT STM_8VALLEY_500 AEP-DOM AEP DVP 0.163 0.041 0.190 0.065 0.054 0.071 0.045 0.065 0.027
AEP-Dom_01PRNTY_8MT STM AEP-DOM AEP DVP 0.181 0.040 0.204 0.078 0.067 0.084 0.059 0.078 0.023
05JEFRSO_05ROCKPT 06CLIFTY_To_7TRIMBLE OVEC LGEE 0.066 0.040 0.017 (0.019) (0.025) (0.017) (0.049) (0.019) 0.008
AEP-DOM AEP DVP 0.180 0.040 0.195 0.071 0.059 0.076 0.052 0.071 0.015
GARFIELD ; B_To_TAYLOR ; B CE CE 0.039 0.039 0.006 (0.026) (0.021) (0.021) (0.006) (0.026) 0.006
05MOUNTN_05BELMON AEP-DOM AEP DVP 0.269 0.038 0.262 0.097 0.086 0.103 0.080 0.097 (0.007)
06CLIFTY_To_7TRIMBLE OVEC LGEE 0.040 0.021 0.013 (0.009) (0.014) (0.007) (0.027) (0.009) 0.005
01BEDNGT_01BLACKO APSouthInterface AP DVP 0.026 0.016 0.129 0.110 0.107 0.117 0.103 0.110 0.125
APSouthInterface AP DVP 0.023 0.015 0.103 0.089 0.086 0.095 0.082 0.089 0.099
05DUMONT_WILTON ; NERC_FG_ID_2563 CE CE 0.019 0.014 0.001 (0.016) (0.015) (0.017) (0.009) (0.016) 0.001
05DUMONT_WILTON ; NERC_FG_ID_556 CE NIPS 0.019 0.014 0.001 (0.016) (0.015) (0.017) (0.009) (0.016) 0.001
ComEd

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Shift factors can be transformed to highlight differences between nodes and pricing
points
AEP PJM
Contingent Branch Monitored Element From Area To Area Gavin Wauk Byron Dresden Kincaid Zion Keystn
CHERRY VA; R_SILVER LK; R NERC_FG_ID_3771 WEC CE (0.119) (0.027) - (0.135) (0.119) (0.207) (0.119)
05DUMONT_WILTON ; NERC_FG_ID_2286 CE NIPS 0.143 (0.011) - (0.017) 0.041 (0.011) 0.143
NERC_FG_ID_3771 WEC CE (0.077) 0.021 - (0.091) (0.077) (0.159) (0.077)
NERC_FG_ID_2286 CE NIPS 0.081 (0.008) - (0.008) 0.025 (0.008) 0.081
05DUMONT_WILTON ; NERC_FG_ID_2515 NIPS CE (0.118) 0.010 - 0.013 (0.035) 0.010 (0.118)
GARFIELD ; R_To_TAYLOR ; R CE CE 0.029 (0.005) - (0.000) 0.015 (0.005) 0.029
NERC_FG_ID_3222 E FRANKFO; R_To_E FRxmid CE CE 0.014 (0.003) - (0.011) 0.004 (0.003) 0.014
NERC_FG_ID_2515 NIPS CE (0.068) 0.007 - 0.006 (0.022) 0.007 (0.068)
NERC_FG_ID_2407 AEP-DOM AEP DVP 0.136 0.012 - 0.018 (0.009) 0.012 (0.026)
8MT STM_8VALLEY_500 AEP-DOM AEP DVP 0.136 0.012 - 0.018 (0.009) 0.012 (0.027)
AEP-Dom_01PRNTY_8MT STM AEP-DOM AEP DVP 0.137 0.012 - 0.017 (0.008) 0.011 (0.044)
05JEFRSO_05ROCKPT 06CLIFTY_To_7TRIMBLE OVEC LGEE 0.042 0.006 - 0.009 (0.024) 0.006 0.033
AEP-DOM AEP DVP 0.135 0.011 - 0.017 (0.008) 0.011 (0.045)
GARFIELD ; B_To_TAYLOR ; B CE CE 0.027 (0.005) - (0.001) 0.014 (0.005) 0.027
05MOUNTN_05BELMON AEP-DOM AEP DVP 0.176 0.011 - 0.017 (0.007) 0.011 (0.093)
06CLIFTY_To_7TRIMBLE OVEC LGEE 0.027 0.005 - 0.007 (0.013) 0.005 0.019
01BEDNGT_01BLACKO APSouthInterface AP DVP 0.021 0.003 - 0.010 (0.004) 0.003 0.017
APSouthInterface AP DVP 0.017 0.003 - 0.009 (0.004) 0.003 0.013
05DUMONT_WILTON ; NERC_FG_ID_2563 CE CE 0.016 (0.001) - (0.002) 0.005 (0.001) 0.016
05DUMONT_WILTON ; NERC_FG_ID_556 CE NIPS 0.016 (0.001) - (0.002) 0.005 (0.001) 0.016
ComEd

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Aurora’s LMP contribution output provides the basis for identifying those constraints
that drive congestion-based LMP differences.
Contingent Branch Monitored Element Index #
From
Area To Area Generator Sample
Generators in
ComEd Zone
Average of all Binding Constraints 2.27 0.20
GARFIELD ; R_To_TAYLOR ; R 1 CE CE 30.32 30.32
NERC_FG_ID_2417 JFRANTBROSUL NERC_FG_ID_2871NHBHBG__PTDF 2 BREC LGEE 36.91 9.77
GARFIELD ; B_To_TAYLOR ; B 3 CE CE 8.51 5.43
05JEFRSO_05ROCKPT 06CLIFTY_To_7TRIMBLE 4 OVEC LGEE 12.69 6.55
05DUMONT_WILTON ; NERC_FG_ID_2286BURMUNWILDUM 5 CE NIPS 9.28 4.75
CHERRY VA; R_SILVER LK; R NERC_FG_ID_3771PPRZIO__PTDF 6 WEC CE 5.67 5.67
05MOUNTN_05BELMON 05CLOVRD_To_05CLOVRD 7 AEP AEP 170.60 5.15
NERC_FG_ID_3222 EFRGDBEFRGDR E FRANKFO; R_To_E FRxmid 8 CE CE 3.88 3.88
NERC_FG_ID_2353 BLOBEDPRNMTS 05CLOVRD_To_05CLOVRD 9 AEP AEP 134.78 3.85
NERC_FG_ID_3217 BYCH_BBYNWEM NERC_FG_ID_3814MGPSTR__PTDF 10 METC WEC 3.62 3.62
NERC_FG_ID_2417 JFRANTBROSUL 05NAGEL_To_05NAGEL 11 AEP AEP 7.50 2.13
NERC_FG_ID_2407 CLVLEXMTSVAL AEP-DOM 12 AEP DVP 8.77 2.05
01HATFLD_01RONCO CLEVELAND 13 METC METC 3.48 1.71
8MT STM_8VALLEY_500 AEP-DOM 14 AEP DVP 6.10 1.42
NERC_FG_ID_2353 BLOBEDPRNMTS CLEVELAND 15 METC METC 2.48 1.25
AEP-Dom_01PRNTY_8MT STM AEP-DOM 16 AEP DVP 5.93 1.23
05MOUNTN_05BELMON AEP-DOM 17 AEP DVP 6.37 0.84
05DUMONT_WILTON ; NERC_FG_ID_2515BURSHE__PTDF 18 NIPS CE 1.43 0.50
06CLIFTY_To_7TRIMBLE 19 OVEC LGEE 0.85 0.46
01HATFLD_01RONCO 05KAMMER_To_05WBELLA 20 AEP AEP 53.33 0.13
LMP Contribution (Max - Min)

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While average congestion is similar across generating nodes in the ComEd zone,
the impact of individual constraints differs greatly.
ComEd nodal prices are driven by constraints located outside of that zone.
Const.
From
Area To Area
CE Max -
Min Wauk Byron
Bright
Stalk Wind
Farm
Lee
Energy Dresden Powrtn
Quad
Cities
Will
County
Kendall
County Kincaid Zion
Avg all Constraints 0.20 (2.70) (2.70) (2.67) (2.65) (2.61) (2.60) (2.60) (2.59) (2.59) (2.57) (2.50)
1 CE CE 30.32 10.84 8.83 (16.18) 8.38 9.01 10.70 7.32 11.61 14.15 3.16 10.86
2 BREC LGEE 9.77 (16.19) (19.16) (13.70) (20.16) (14.59) (16.00) (23.47) (14.58) (14.91) (21.90) (16.23)
3 CE CE 5.43 5.45 4.35 1.49 4.09 4.47 5.16 3.55 6.84 6.06 1.60 5.49
4 OVEC LGEE 6.55 (3.85) (5.02) (2.92) (5.43) (3.33) (4.18) (6.71) (3.36) (3.53) (9.47) (3.93)
5 CE NIPS 4.75 5.04 4.61 7.77 4.47 5.25 4.91 4.02 5.53 5.03 3.02 5.04
6 WEC CE 5.67 (2.51) (3.26) 0.47 (2.57) 0.44 0.26 (2.26) 0.56 0.58 0.00 2.42
7 AEP AEP 5.15 (99.40) (100.54) (98.49) (100.95) (98.95) (99.64) (102.22) (98.88) (99.05) (103.63) (99.41)
8 CE CE 3.88 1.17 0.89 1.49 0.84 1.70 1.37 0.75 2.97 1.26 0.58 1.17
9 AEP AEP 3.85 (103.79) (104.62) (103.12) (104.92) (103.45) (103.97) (105.86) (103.41) (103.53) (106.97) (103.79)
10 METC WEC 3.62 3.04 3.35 0.00 3.21 0.00 0.00 3.28 0.00 0.00 0.00 3.17
11 AEP AEP 2.13 (4.52) (5.17) (4.00) (5.40) (4.19) (4.51) (6.13) (4.19) (4.27) (5.82) (4.52)
12 AEP DVP 2.05 (3.49) (2.86) (3.99) (2.65) (3.81) (3.52) (1.94) (3.81) (3.74) (2.40) (3.48)
13 METC METC 1.71 (5.91) (4.83) (6.10) (4.77) (5.97) (5.86) (4.57) (6.00) (5.98) (4.39) (5.91)
14 AEP DVP 1.42 (2.44) (2.00) (2.79) (1.86) (2.66) (2.46) (1.37) (2.66) (2.61) (1.68) (2.44)
15 METC METC 1.25 (4.09) (3.31) (4.23) (3.27) (4.14) (4.06) (3.12) (4.16) (4.14) (2.99) (4.09)
16 AEP DVP 1.23 (2.57) (2.19) (2.87) (2.07) (2.76) (2.59) (1.64) (2.76) (2.72) (1.92) (2.57)
17 AEP DVP 0.84 (2.30) (2.04) (2.51) (1.96) (2.44) (2.32) (1.67) (2.43) (2.41) (1.89) (2.30)
18 NIPS CE 0.50 (1.05) (0.95) (0.79) (0.93) (1.08) (1.04) (0.84) (1.08) (1.12) (0.62) (1.05)
Selected Generating Plants Located in ComEd Zone

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Congestion contribution can be transformed to highlight differences among nodes
and pricing points
Const.
From
Area To Area
CE Max -
Min Wauk Byron
Bright
Stalk Wind
Farm
Lee
Energy Dresden Powrtn
Quad
Cities
Will
County
Kendall
County Kincaid Zion
Avg all Constraints 0.20 (0.01) - 0.03 0.04 0.08 0.10 0.10 0.10 0.10 0.12 0.19
1 CE CE 30.32 2.01 - (25.01) (0.46) 0.17 1.87 (1.51) 2.77 5.31 (5.67) 2.03
2 BREC LGEE 9.77 2.97 - 5.46 (1.00) 4.57 3.16 (4.31) 4.59 4.25 (2.74) 2.93
3 CE CE 5.43 1.10 - (2.87) (0.26) 0.11 0.80 (0.81) 2.48 1.71 (2.75) 1.14
4 OVEC LGEE 6.55 1.17 - 2.10 (0.41) 1.69 0.84 (1.68) 1.66 1.49 (4.45) 1.10
5 CE NIPS 4.75 0.44 - 3.17 (0.14) 0.65 0.31 (0.59) 0.92 0.42 (1.59) 0.43
6 WEC CE 5.67 0.75 - 3.73 0.69 3.70 3.51 1.00 3.82 3.84 3.26 5.67
7 AEP AEP 5.15 1.14 - 2.05 (0.41) 1.59 0.90 (1.68) 1.66 1.49 (3.09) 1.13
8 CE CE 3.88 0.28 - 0.60 (0.05) 0.81 0.48 (0.14) 2.08 0.37 (0.31) 0.28
9 AEP AEP 3.85 0.84 - 1.51 (0.30) 1.17 0.65 (1.23) 1.22 1.09 (2.34) 0.83
10 METC WEC 3.62 (0.32) - (3.35) (0.14) (3.35) (3.35) (0.08) (3.35) (3.35) (3.35) (0.18)
11 AEP AEP 2.13 0.66 - 1.18 (0.22) 0.98 0.67 (0.95) 0.98 0.91 (0.64) 0.65
12 AEP DVP 2.05 (0.63) - (1.13) 0.21 (0.95) (0.66) 0.92 (0.95) (0.88) 0.46 (0.62)
13 METC METC 1.71 (1.08) - (1.27) 0.07 (1.13) (1.03) 0.26 (1.17) (1.14) 0.45 (1.08)
14 AEP DVP 1.42 (0.44) - (0.78) 0.15 (0.66) (0.46) 0.63 (0.66) (0.61) 0.32 (0.43)
15 METC METC 1.25 (0.78) - (0.92) 0.05 (0.82) (0.75) 0.20 (0.85) (0.83) 0.33 (0.78)
16 AEP DVP 1.23 (0.38) - (0.68) 0.13 (0.57) (0.40) 0.55 (0.57) (0.53) 0.27 (0.37)
17 AEP DVP 0.84 (0.26) - (0.47) 0.09 (0.39) (0.28) 0.38 (0.39) (0.36) 0.16 (0.26)
18 NIPS CE 0.50 (0.09) - 0.17 0.03 (0.12) (0.08) 0.12 (0.13) (0.17) 0.33 (0.09)
19 OVEC LGEE 0.46 0.10 - 0.18 (0.04) 0.15 0.08 (0.15) 0.15 0.14 (0.28) 0.10
20 AEP DVP 0.23 0.05 - 0.09 (0.02) 0.07 0.04 (0.07) 0.07 0.07 (0.14) 0.05
Selected Generating Plants Located in ComEd Zone

19. © PA Knowledge Limited 2014
19
Transformation also makes it easier to identify constraints that drive broader
interregional congestion
PJM 500
Penelec
Index #
From
Area To Area Gavin DC Cook Wauk Byron
Bright
Stalk
Wind
Farm
Lee
Energy Dresden Powrtn
Quad
Cities
Will
County
Kendall
County Kincaid Zion Keystone
Average - 0.64 0.66 0.66 0.69 0.71 0.75 0.76 0.76 0.76 0.77 0.79 0.86 2.27
1 CE CE - -0.05 13.38 11.37 -13.64 10.92 11.55 13.24 9.86 14.15 16.69 5.70 13.40 0.00
2 BREC LGEE - -22.25 -29.63 -32.60 -27.14 -33.60 -28.02 -29.43 -36.91 -28.01 -28.34 -35.34 -29.66 -7.90
3 CE CE - 0.32 7.09 6.00 3.13 5.74 6.11 6.80 5.19 8.48 7.70 3.24 7.14 0.32
4 OVEC LGEE - -4.24 -7.07 -8.24 -6.14 -8.64 -6.55 -7.40 -9.92 -6.58 -6.74 -12.69 -7.14 -1.76
5 CE NIPS - -0.64 5.91 5.47 8.64 5.33 6.12 5.78 4.89 6.39 5.89 3.88 5.91 0.00
6 WEC CE - 0.02 -2.51 -3.26 0.47 -2.57 0.44 0.26 -2.26 0.56 0.58 0.00 2.42 0.00
7 AEP AEP - 36.29 31.14 30.00 32.06 29.60 31.60 30.90 28.33 31.66 31.49 26.91 31.14 170.60
8 CE CE - -0.29 1.32 1.04 1.64 0.99 1.85 1.52 0.90 3.12 1.42 0.73 1.32 0.00
9 AEP AEP - 12.03 8.25 7.41 8.92 7.11 8.58 8.06 6.18 8.63 8.50 5.07 8.24 134.78
10 METC WEC - 0.00 3.04 3.35 0.00 3.21 0.00 0.00 3.28 0.00 0.00 0.00 3.17 0.00
11 AEP AEP - -2.26 -5.89 -6.54 -5.37 -6.77 -5.56 -5.88 -7.50 -5.56 -5.64 -7.19 -5.89 -0.81
12 AEP DVP - 5.28 6.73 7.36 6.23 7.58 6.42 6.70 8.28 6.42 6.48 7.82 6.74 8.77
13 METC METC - 1.78 -1.52 -0.44 -1.70 -0.37 -1.57 -1.47 -0.18 -1.61 -1.58 0.01 -1.52 1.00
14 AEP DVP - 3.66 4.66 5.10 4.32 5.25 4.45 4.65 5.74 4.45 4.49 5.42 4.67 6.10
15 METC METC - 1.21 -1.12 -0.34 -1.26 -0.30 -1.17 -1.09 -0.15 -1.20 -1.17 -0.02 -1.13 -0.42
16 AEP DVP - 3.25 4.11 4.49 3.81 4.62 3.92 4.09 5.04 3.92 3.96 4.76 4.12 5.93
17 AEP DVP - 3.34 3.90 4.16 3.69 4.25 3.77 3.88 4.54 3.77 3.80 4.32 3.90 6.37
18 NIPS CE - 0.14 -1.22 -1.13 -0.96 -1.10 -1.25 -1.21 -1.01 -1.25 -1.30 -0.79 -1.22 0.00
19 OVEC LGEE - -0.28 -0.48 -0.58 -0.40 -0.61 -0.43 -0.50 -0.73 -0.43 -0.44 -0.85 -0.48 -0.17
20 AEP AEP - 5.18 4.74 4.78 4.72 4.79 4.70 4.73 4.83 4.72 4.72 4.73 4.75 53.33
AEP ComEd