This document provides data on day-ahead and real-time locational marginal prices (LMPs) in the Midcontinent Independent System Operator (MISO) system from April 2014 to April 2015. It shows average monthly LMPs were generally higher in the day-ahead market than in real-time, with price divergence ranging from 0.23$/MWh to 13.41$/MWh. The document also includes data on fuel prices, congestion collections, flowgate outages, and other market metrics over this period.

1. MISO System-wide DA and RT LMPs
40.06
44.49
39.22
33.27
33.37
32.39
33.37
35.34
30.17
28.48
31.73
28.42
25.20
41.13
44.16
36.95
32.15
32.12
33.09
32.44
34.34
29.38
28.19
30.46
29.04
24.64
0
5
10
15
20
25
30
35
40
45
50
55
60
65
70
75
80
Apr-14May-14Jun-14 Jul-14 Aug-14Sep-14 Oct-14 Nov-14Dec-14Jan-15 Feb-15Mar-15 Apr-15
$/MWh
Day-Ahead and Real-Time Average Monthly System-Wide MISO
Prices
MISO DA MISO RT
Note: MISO System-Wide price is based on the monthly hourly average of the active hubs.
1

2. 30.7%
30.1%
22.8%
14.0%
10.3%
12.3%
12.8%
14.0%
10.4%
11.1%
19.0%
17.9%
13.6%
0.0%
10.0%
20.0%
30.0%
40.0%
50.0%
60.0%
70.0%
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
PercentPriceDivergence*
DA/RT Price Deviation
Price Convergence: DA and RT LMP
12.30
13.41
8.94
4.65
3.44 4.00 4.27 4.93
3.13 3.17
6.03 5.08
3.42
-1.08
0.33 0.23 1.12 1.25
-0.70
0.93 1.00 0.78 0.29 1.27
-0.63
0.56
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
$/MWh
Average Absolute (DA-RT) difference Average (DA-RT) difference
* Monthly deviation, expressed as a percent of average DA LMP, is calculated as the average of hourly absolute (DA-RT) price differences divided by the average of hourly
DA LMPs for the month.
Note: MISO System-Wide price is based on the monthly hourly average of the active trading hubs.
2

3. 29.68
30.77
30.01
24.18
25.88
32.79
26.22
28.50
28.64
29.93
29.20
24.01
25.07
36.81
25.95
28.52
22.20
24.64
23.36
16.70
20.98
23.85
22.48
22.03
19.99
24.78
23.12
16.15
19.99
21.35
21.13
20.93
ILL IND MICH MINN ARK LOU TEX MISO
$/MWh
Peak/Off-Peak: March 2015
DA Peak RT Peak DA OffPeak RT OffPeak
MISO DA and RT Hub LMPs
3
ILL IND MICH MINN ARK LOU TEX MISO
DA Peak 1.55 1.54 0.31 -2.45 -1.55 3.70 -2.10 0.14
RT Peak 0.45 0.64 -0.36 -2.95 -2.18 8.03 -2.09 0.22
DA OffPeak 0.84 2.30 0.91 -3.35 0.03 1.75 0.56 0.43
RT OffPeak -0.79 3.07 1.42 -3.37 -0.16 0.14 0.06 0.05
Congestion Component
of LMP ($/MWh)

4. 0
100
200
300
400
500
600
0
20
40
60
80
100
120
140
160
180
200
220
240
260
280
300
320
340
360
$/MWh
Number of Hours
Price Duration Curve – Peak Hours
Note: MISO System-Wide price is based on the hourly average of the active hubs.
4
Apr-2015 MISO Real-Time Price 196.48 2(0.57%) 2(0.57%) 344(97.73%) 0(0.00%)
Apr-2015 MISO Day-Ahead Price 39.44 0(0.00%) 0(0.00%) 352(100.00%) 0(0.00%)
Mar-2015 MISO Real-Time Price 476.20 2(0.57%) 3(0.85%) 328(93.18%) 0(0.00%)
Mar-2015 MISO Day-Ahead Price 78.11 0(0.00%) 0(0.00%) 340(96.59%) 0(0.00%)
Hours w ith
LMP< $0/MWh
Hours w ith
LMP> $150/MWh
Hours w ith
LMP> $100/MWh
Hours w ith
LMP< $50/MWh
Peak Hourly
LMP

5. Price Duration Curve – Off-Peak Hours
Source MISO Information Delivery and Market Analysis Department
Note: MISO System-Wide price is based on the hourly average of the active hubs.
5
0
10
20
30
40
50
60
70
80
90
100
0
20
40
60
80
100
120
140
160
180
200
220
240
260
280
300
320
340
360
380
400
420
$/MWh
Number of Hours
Apr-2015 MISO Real-Time Price 55.80 0(0.00%) 0(0.00%) 367(99.73%) 0(0.00%)
Apr-2015 MISO Day-Ahead Price 38.69 0(0.00%) 0(0.00%) 368(100.00%) 0(0.00%)
Mar-2015 MISO Real-Time Price 86.65 0(0.00%) 0(0.00%) 386(98.47%) 0(0.00%)
Mar-2015 MISO Day-Ahead Price 56.99 0(0.00%) 0(0.00%) 390(99.49%) 0(0.00%)
Peak Hourly
LMP
Hours w ith
LMP< $0/MWh
Hours w ith
LMP> $150/MWh
Hours w ith
LMP> $100/MWh
Hours w ith
LMP< $50/MWh

6. 92.24
131.77
108.02
52.54 49.01
85.99 79.25 65.59
50.36 55.40
94.71
74.04
49.21
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
DA Congestion Collections
Normalized* Day-Ahead Market Congestion Collections
$/MWh
1.72
2.27
1.64
0.77 0.69
1.42 1.39
1.13
0.84 0.84
1.53
1.27
0.94
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
Day-Ahead Market Congestion Collections
$ in millions
Source: MISO Information Delivery and Market Analysis Department
* Normalized using Day-Ahead load
Date of Extraction: May 05, 2015.
6

7. 4.74
4.61
4.66
4.15
3.92
3.96
3.87
4.49
3.65
3.09
4.48
4.62
4.60
4.59
4.08
3.86
3.94
3.80
4.02
3.43
2.99
2.88
2.87
2.58
3.01
2.58
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
Chicago Citygate Hub Henry Hub
1.98 1.95 1.94 1.88 1.86 1.85 1.89 1.90 1.90 1.92
1.78 1.71 1.72
0.74 0.74 0.73 0.71 0.67 0.65 0.66 0.66 0.66 0.66 0.66 0.66 0.66
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
Illinois Basin Powder River Basin
Nominal Fuel Prices
Gas ($/mmbtu)
Coal ($/mmbtu)
Chicago Citygate
Trading Hub and
Henry Trading Hub
Oil* ($/mmbtu)
Illinois Basin Heat
Content =
11,800 btu/lb,
Powder River Basin
Heat Content =
8,800 btu/lb
Distillate Fuel Oil
Heat Content =
5.825 mmbtu/bbl
Source: Publicly Available/Government Sources-EIA and ICE
22.82 22.69 22.73 22.36 21.95 21.32 20.09 19.68
16.59
14.58 15.92 14.50 14.83
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
https://www.theice.com/marketdata/reports/76
http://www.eia.doe.gov/cneaf/coal/page/coalnews/coalmar.html#spot; “SNL Energy”
http://www.eia.gov/emeu/steo/pub/cf_tables/steotables.cfm?tableNumber=8
* Monthly oil prices are estimates and subject to change upon finalization.
7

8. 193.61
255.95
175.34
89.85
79.28
134.66
140.66
125.26
95.91
101.27
167.54
139.74
92.80
125.34
7.48
2.83
2.65
21.74
6.49
0.32
12.19
2.55
1.95
4.97
0.00
1.62
1.23
15.63
0
50
100
150
200
250
300
Apr
2014
May Jun Jul Aug Sep Oct Nov Dec Jan
2015
Feb Mar Apr YTD
Avg
$inMillions
Hourly and Monthly Funding for Credits Net FTR Shortfall
Source: MISO Market ECF Report
Date of Extraction: May 5, 2015. Values may change due to resettlement.
FTR Rolling 12-month percentage calculations can be found in the April 2015 FTRWG meeting materials.
FTR Monthly and Rolling 12-Month Funding
C
8
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
Monthly FTR Allocation% 89.9% 97.5% 99.8% 96.9% 96.8% 94.7% 90.0% 91.1% 97.4% 98.8% 99.0% 100.0% 94.9%
Rolling 12-month Allocation% 97.7% 98.2% 98.6% 98.4% 98.3% 97.9% 97.6% 97.5% 97.4% 96.1% 96.1% 96.1% 96.8%

9. Offered Capacity and RT Peak Load Obligation
Offered Capacity (Hourly Average per category)
MW
Source: MISO Information Delivery and Market Analysis Department
*Gas excludes CC and CT units.
**Other includes DRR as well as oil ,pet coke and waste units.
1Real-Time ICCP Load plus Real-Time Regulation Requirement plus Real-Time Spinning Requirement at the daily Peak hour
Average Net Scheduled
Interchange over all hours
Hydro
Nuclear
Gas*
CC
CT
Other**
1Real-Time peak
load obligation
Coal
Wind
9
0
10,000
20,000
30,000
40,000
50,000
60,000
70,000
80,000
90,000
100,000
110,000
120,000
130,000
140,000
150,000
160,000
4/1
4/2
4/3
4/4
4/5
4/6
4/7
4/8
4/9
4/10
4/11
4/12
4/13
4/14
4/15
4/16
4/17
4/18
4/19
4/20
4/21
4/22
4/23
4/24
4/25
4/26
4/27
4/28
4/29
4/30

10. Marginal Fuel – April 2015
Percentage of Time a Fuel is Marginal in the Real-Time Market
% of Time
Source: MISO Information Delivery and Market Analysis Department
42
85
30
0 0 0
66
46
82
48
0 2 1
55
44
83
39
0 1 0
61
0
20
40
60
80
100
120
CC Coal Gas^^ Nuclear Oil Hydro *Wind
Off-Peak On-Peak Total
Note: Binding transmission constraints can produce instances where more than one unit is marginal in the system. Consequently, more than one
fuel may be on the margin; and since each marginal unit is included in the analysis, the percentage may sum to more than 100%.
^^Gas excludes Combined Cycle units
10

11. Generation Outages and Derates
Source: MISO CROW Outage Scheduler
* Forced Outages include Emergency, Forced, and Urgent
* Planned Outages include Planned
*De-rates are based on limits observed in Real-Time and may reflect normal seasonal de-rates in addition to de-rates for maintenance
or other operating conditions.
Outages extracted on May 01, 2015
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
MW
Daily Average Generation Outages and Derates - Reliability Footprint
Forced* Planned* Derates*
Data includes both MISO market and reliability footprints. Outage data is “point in time” and
can change. The chart reflects the data as it resided in the system on the date of extraction.
11

12. 0 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
Count
Alerts* Warnings* Events*
Minimum and Maximum Generation Notifications
0 0 0
1
0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
Count
Alerts* Warnings* Events*
Minimum Generation Actions
Supply surplus situations during light load periods when on-line resources need to operate at Emergency Minimum levels or be decommitted as to not over
burden the interconnected system.
Maximum Generation Actions
System-wide or transmission contingency related capacity shortages that may jeopardize the reliable operation of all or part of the MISO system.
Source: MISO Real-Time Operations Department
* Alerts – forecasting specific emergency situations in a future time-frame
* Warnings – experiencing initial stages of an emergency situation and taking action
* Events – experiencing an emergency situation and taking action
12

13. 100 96 98.33 98.9
Apr-15 Mar-15 2015 YTD Avg 2014 Avg
-4.2
251.5 256.6 286.2
-11.6
-3.5
-20.6
254.4
Apr-15 Mar-15 2015 YTD Avg 2014 Avg
Mean STD
45 49
36
29
Apr-15 Mar-15 2015 YTD Avg 2014 Avg
6
0
0
0
0
0
Level 3 & 4
Level 5
Level 6
Apr-15 Mar-15
2.5
4.0
1.0
0.0
1.0
2.0
Apr-15 Mar-15 2015 YTD Avg 2014 Avg
MISO External
Reliability — Other Metrics
Transmission Loading Relief (TLR) Events Area Control Error (ACE)
MW
Levels:
3 – curtailing non-firm
4 – curtailing non-firm and reconfiguring
5 – curtailing firm
6 – emergency
Manual Redispatches (Count)
23,518 MWh Non-Firm MWh Curtailed
0 MWh Firm MWh Curtailed
Source: MISO Real-Time Operations Department
April 2015 Unit Commitment Efficiency
Percentage of days with online generation held to target and sufficient to meet
demand and constraints
N
Contingency Reserve Sharing
# of ARS events
O
13

14. Generation Interconnect Queue – Overall
0
50
100
150
200
250
300
350
400
450
Apr
2013
May Jun Jul Aug Sep Oct Nov Dec Jan
2014
Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan
2015
Feb Mar Apr
#ofRequests
0
5,000
10,000
15,000
20,000
25,000
30,000
SizeofQueue(MW)
Size of Queue (MW) Number of Requests
Generation Interconnect Queue – Overall Status
Source: MISO Transmission Planning Department
84
2
81
Requests
Wind Coal Other
14

15. Generator Suspension/Retirement – Overall
0
5
10
15
20
Apr
2013
May Jun Jul Aug Sep Oct Nov Dec Jan
2014
Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan
2015
Feb Mar Apr
#ofRequests
0
500
1,000
1,500
2,000
2,500
3,000
3,500
SizeofQueue(MW)
Size of Queue (MW) Number of Requests
Generator Suspension/Retirement Requests – Overall
Source: MISO Transmission Planning Department
2
1
0
Requests in Study -
Current Month
Coal Gas Other
15

16. Regional DA and RT Average Hub LMP
Source: MISO Information Delivery and Market Analysis Department
16
29.68
30.77
30.01
24.18
25.88
32.79
26.22
28.64
29.93
29.20
24.01
25.07
36.81
25.95
22.20
24.64
23.36
16.70
20.98
23.85
22.48
19.99
24.78
23.12
16.15
19.99
21.35
21.13
ILL IND MICH MINN ARK LOU TEX
Central Region North Region South Region
Day-Ahead and Real-Time Average Monthly LMP for Hubs
Peak/Off-Peak : April 2015
DA_Peak RT_Peak DA_offPeak RT_offPeak

17. Source: MISO Information Delivery and Market Analysis Department
Regional & System-wide DA & RT LMP – MISO, PJM, SPP
Note: SPP price is the hourly average of LMPs at SPP’s Settlement Locations. Hourly LMP data provided by SPP.
21.70
25.20
30.35
22.00
24.64
29.81
SPP MISO PJM
$/MWh
Day-Ahead and Real-Time Average Monthly LMP for MISO, PJM and SPP:
April 2015
Day-Ahead Real-Time
26.12
23.38
27.64
24.77
27.12
22.47
27.30
24.75
SPP South Hub MISO Arkansas Hub MISO Indiana Hub PJM Chicago Hub
$/MWh
17

18. 6.92
6.83
6.83
6.83
6.83
6.83
7.45
6.83
7.46
6.64
6.64
6.64
6.64
6.64
12.37
6.64
1.75
1.66
1.66
1.66
1.66
1.66
2.27
1.66
2.02
1.20
1.20
1.20
1.20
1.20
6.93
1.20
0.65
0.54
0.54
0.54
0.54
0.54
1.29
0.54
1.28
0.44
0.44
0.44
0.44
0.44
6.32
0.44
MISO Zone 1 Zone 2 Zone 3 Zone 4 Zone 5 Zone 6 Zone 7
Non-Zone Indiana Michigan Wisconsin Minnesota Louisiana Texas
$/MWh
Day-Ahead and Real-Time Monthly Average of Hourly
MCPs by Zones: April 2015
REG_DA_MCP REG_RT_MCP SPIN_DA_MCP SPIN_RT_MCP SUPP_DA_MCP SUPP_RT_MCP
Source: MISO Information Delivery and Market Analysis Department
Note: No reserve MCP separation across zones if no reserve zone constraints bind. The definition of the Reserve Zones is updated on a
quarterly basis, in conjunction with the update of the Network Model. See Zonal Regulation Map
Zonal DA and RT MCP
18

19. Average Load by Region
Central Region
(GW)
South Region
(GW)
North Region
(GW)
Source: MISO Information Delivery and Market Analysis Department
* Monthly data based on hourly ICCP load data.
36.57 37.93
43.12 42.36 44.35
39.51 37.18
40.40 41.28
43.61 45.07
39.37
35.83
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
15.27 15.05 16.68 17.20 17.70
15.70 15.43
17.22 17.47 17.91 18.39
16.04 14.84
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
16.81 18.15
21.48 21.88 22.75
20.96
17.69 17.86 17.88
19.51 19.48
16.88 16.68
Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15
Hourly Integrated Peak Load Hour: 04/09/2015 HE 14 Peak load: 79.00 GW
Central Region: 41.60GW North Region: 17.18GW South Region: 20.22GW
19

20. Source: MISO Information Delivery and Market Analysis Department
*Based on 5-minute unit level generation dispatch target
Dispatched Generation Fuel Mix by Region
20
67.6%
50.4%
15.3%
67.8%
49.0%
10.5%
13.7%
12.3%
26.4%
15.7%
9.9%
31.2%
14.7%
7.2%
53.9%
11.4%
7.1%
52.5%
3.3%
28.0%
3.7%
31.4%
4.3% 5.8%
0.0%
20.0%
40.0%
60.0%
80.0%
100.0%
120.0%
Central Region North Region South Region Central Region North Region South Region
Mar-2015 Apr-2015
Coal(%) Nuclear(%) Gas(%) Wind(%) Other(%)

21. Generation Outages by Region
Source: MISO CROW Outage Scheduler
* Forced Outages include Emergency, Forced, and Urgent
* Planned Outages include Planned
*De-rates are based on limits observed in Real-Time and may reflect normal seasonal de-rates in addition to de-rates for maintenance
or other operating conditions.
Outages extracted on May 01, 2015 Data includes both MISO market and reliability footprints. Outage data is “point in time” and
can change. The chart reflects the data as it resided in the system on the date of extraction.
21
0
2
4
6
8
10
12
14
16
18
Central Region North Region South Region Central Region North Region South Region
Mar-2015 Apr-2015
GW
Daily Average Generation Outages and Derates - Reliability Footprint
Forced Planned Derates

22. Source: The Web-based Revenue Sufficiency Guarantee Report
Revenue Sufficiency Guarantee by Regions
*DA_RSG_VLR% is the ratio of DA RSG associated with VLR commitments to the total DA RSG MWP.
*RT_RSG_Txx% is the ratio of RT RSG associated with congestion mitigation to the total RT RSG MWP.
Date of Extraction: May 5, 2015. Values may change due to resettlement.
22
0%
10%
20%
30%
40%
50%
60%
70%
80%
$0.00
$2.00
$4.00
$6.00
$8.00
$10.00
Central Region North Region South Region
Apr-2015
Millions
DA RSG & DA RSG Associated with VLR
Total DA RSG MWP DA RSG Associated with VLR Commitments DA_RSG_VLR%*
0%
5%
10%
15%
20%
25%
30%
35%
40%
$0.00
$2.00
$4.00
$6.00
$8.00
$10.00
Central Region North Region South Region
Apr-2015
Millions
RT RSG & RT RSG Associated with Congestion Mitigation
RT RSG MWP RT RSG Associated with Congestion Mitigation RT_RSG_Txx%*

23. Reliability – Manual Re-dispatches and TLR by Region
Transmission Loading Relief (TLR) Events (Count)
Levels:
3 – curtailing non-firm
4 – curtailing non-firm and reconfiguring
5 – curtailing firm
6 – emergency
Manual Redispatches (Count)
Source: MISO Real-Time Operations Department
TLR – April 2015
Notifications – April 2015
• 04/08/15 15:38-23:00 EST: Severe
Weather Alert for areas in the Central
Region, due to Tornado Warnings.
• 04/09/15 01:00-02:30 EST: System
Status Level 1 YELLOW due to network
issues affecting M2M, ARS, MCS and the
portal.
• 04/09/15 19:30 EST to 04/10/2015
03:00 EST: Severe Weather Alert for
MISO footprint due to a long line of
severe thunderstorms including tornado
watches and warnings.
• 04/27/15: 05:50 – 14:00 EST Severe
Weather Alert issued for southern
Louisiana and southern Mississippi areas
due to heavy storms, tornadoes,
damaging wind and hail.
• 04/27/15: 10:10 – 14:00 EST
Conservative Operations issued for EES,
CLEC, LAFA, LEPA, SME due to multiple
forced transmission outages.
0 Firm MWh Curtailed
23,518 Non-Firm MWh Curtailed
23
0 0 0
4
2
00 0 0 0 0 00 0 0 0 0 0
Central Region North Region South Region Central Region North Region South Region
Mar-2015 Apr-2015
Level 3&4 Level 5 Level 6
3
25
8
2
10
17
49
Central Region North Region South Region Central Region North Region South Region MISO
Mar-2015 Apr-2015 2014 AVG
# Number of Manual Redispatch

24. Transmission Service and Generation Interconnection
Request by Region
Long-term Firm Transmission Service Queue
Source: MISO Transmission Planning Department
Generation Interconnect Queue
Number of Requests
April 2015
Note: The regions are determined based on POINT_OF_RECEIPT.
24
0
5
10
15
20
25
30
35
40
Central Region North Region South Region
Apr-2015
# of Requests in Study
0
4
8
12
Central Region North Region South Region
Apr-2015
# of Requests Processed
0
5,000
10,000
15,000
20,000
25,000
30,000
Central Region North Region South Region
Apr-2015
MW
Size of Queue( MW) -Total
0
200
400
600
800
1,000
1,200
1,400
Central Region North Region South Region
Apr-2015
MW
Size of Queue( MW) -New Size of Queue (MW) - Resolved
Region Total New Resolved
Central 83 0 4
North 55 2 1
South 22 0 1

25. Transmission Service and Generation Interconnection Request by
Region Long-term Firm Transmission Service Queue
Generation Interconnect Queue
Number of Requests
February 2015
Note: The regions are determined based on POINT_OF_RECEIPT.
25
0
5
10
15
20
25
30
35
Central Region North Region South Region
Feb-2015
# of Requests in Study
0
4
8
12
16
20
24
Central Region North Region South Region
Feb-2015
# of Requests Processed
0
5,000
10,000
15,000
20,000
25,000
30,000
Central Region North Region South Region
Feb-2015
MW
Size of Queue( MW) -Total
0
100
200
300
400
500
600
700
Central Region North Region South Region
Feb-2015
MW
Size of Queue( MW) -New Size of Queue (MW) - Resolved
Region Total New Resolved
Central 89 0 3
North 51 0 0
South 25 0 1