KEt 3 22 pi 'OB ARKANSAS PUBLIC SERVICE COMMISSION

/f

By: ")

-.- a j F ;: -7 IN THE MATTER OF AN INQUIRY INTO ELECTRtC 1 :,ULh

TRANSMISSION ISSUES WITHIN THE AREAS 1 SERVED BY THE SOUTHWEST POWER POOL REGIONAL TRANSMISSION ORGANZATION AND 1 THE ENTERGY CORPORATION AS SUCH ISSUES 1 AFFECT ELECTRIC SERVICE WITHIN ARKAMSAS 1

) DOCKET NO. 08-1364

&

RESPONSE OF SOUTHWEST POWER POOL, INC. TO ORDER NO. 2

EIS MONTHLY STATE OF THE MARKET REPORT FOR NOVEM8ER 2008

COMES now Southwest Power Pool, Inc. (YSPP"), by and through its attorneys,

and hereby submits its Response to Order No. 2 - EIS Monthly State of the Market

Report for November 2008. In support thereof, SPP states as follows:

1. Pursuant to Order No. 2, issued October 17,2008 in this docket, the Commission

directed SPP to file the EIS Monthly State of the Market Report contemporaneously as it

is provided informally to FERC via posting on the SPP website. The report for

November 2008 is provided herein as Exhibit 1 to this Response and can also be

accessed via the SPP website at the following link:

Respectfully submitted,

Southwest Power Pool. Inc.

MO BIN 52608 Y

And

Susan E. Polk, AR BIN 2007198

And

H. Edward Skinner, AR BIN 81 145 WRIGHT, BERRY, HUGHES & MOORE Attorneys at Law P.O. Drawer 947 303 Professional Park Drive Arkadelphia, AR 71 923

Attorneys for Southwest Power Pool, Inc.

2

EXHIBIT 1

SPP EIS Monthly State of the Market Report

November 2008

3

State

, . .. . . . . . . i

Monthly of the Market Report

November 2008

published December 16,2008

produced by SPP Market Monitoring Unit

SPP Market Monitoring Unit

Table of Contents

Executive Summary .............................................................................................................................................. 3

Figur ..................................................................................................................................................................... 4

Figure 1 - SPP EIS Price Contour Map ................................................................................................... 4

Figure 2 - Congestion by Shadow Price impact - Novmbcr 2008 ........................................................ 5

Fibwre 3 - Congestion by Shadow Price impact - Previous 12 months .................................................. 6

Figure 4 -- Breached and Binding Flowgates by Interval ......................................................................... 7 Figure S . Hourly Price Ranges by Market Participant - November 2008 ............................................. 8

Figure 6 - Hourly Price Ranges by Market Participant - Previous 12 months ....................................... 9

Figure 7 - Regional Monthly Prices ...................................................................................................... 10

Figure X Generation by Fuel Type ...................................................................................................... 1 1

Figure 9 - Wind Generation & Capacity ............................................................................................... 12 . . . Figure 10 - Wind Variability ................................................................................................................. 13

Figure I 1 - Fuel on the Margin .............................................................................................................. 14

Figure 12 - Gas Cost I LIP Comparison ................................................................................................ 15 Fibare 13 - EIS Settlements . GWh ....................................................................................................... 16

Figure 15 - Depth of Energy Market for Resources Only - by Status .................................................. 18

Figure 14 - Resource Five Minute Ramp Rates .................................................................................... 19

Figure 17 Monthly Summary of Market Ramp Rate Deficiency ........................................................ 20

Figure 18 - Dispatckable Range ............................................................................................................ 21

Figire 19 - Transmission Owner Revenue ............................................................................................ 22

Figure 20 - Average Transmission Reservations and Schedules ........................................................... 23

Figure 14 - EIS Settlements . $ ............................................................................................................. 17

Figure 21 RNU Components ............................................................................................................... 24

November 2008 2

SPP Market Monitoring Unit

Executive Summary

Participation in the SPP Energy Imbalance market continues to be robust with market dispatch capacity near 80% (Figwe 15). Locational Imbalance Prices (LIPS) for November are relatively low as compared to prices in the summer months and the twelve month average price. The SPP average LIP for November is $35 and the price volatility is 48%. A new chart (Jigurc 7) shows SPP price voIatility to generally be less than that experienced in MlSU or ERCOT.

Congestion continues to be an important determinant of LIP in southeast Oklahoma, northwest Louisiana, and the panhandle of Texas (Figtirc I ) . The three congestion metrics presented in he report show an increase for the second month in a row (Figures 2 and 4). Scheduled maintenance on transmission lines and generation resources undoubtedly play a role in the congestion; however, the Market Monitoring Unit (MMU) is concerned about an increasing trend in congestion. New metrics me heing developed to track the cost of congestion and Figure 3 has been revised to inchde an additional column specifying proposed solutions to congestion problems at the top 10 congested flowgates. These proposed solutions were compiled by the SPP Transmission PIanning Group.

Offered ramp significantly increased in November by about 2 1 %, (Figure 19. This increase is likely to be attributed to PRRl13, which gives participants much more flexibility in setting ramp rate limits used by the market dispatch engine. Prior to implementation of this PRR, a single ramp rate limit was applied at all generation levels whether ramping up or down. With PRRll3, a resource can break its dispatchable range into as many as 10 diffcrent segments, each with a different up and down ramp rate. This allows a resource to offer more ramp rate at some generation levels and less where the resource is more restricted. The decline in m p deficiency intervals for November may be a result of this increase in offered ramp (Figwe 27).

The calculation of offered ramp rate averages the ramp rates that apply to each MW of generation level between a resource’s dispatchable minimum and maximum points. The dispatchable minimum and maximum points are determined by the resource plan adjusted for ancillary services. This process produces an average offered up ramp rate and an average offered down ramp rate. To arrive at a single figure for tracking purposes, the final step in the caiculation consists of taking a simple average of the up and down rates. This calculation method can be applied to historical data and will produce the same rcsults as posted in previous reports. it applies to current data where resources of’fer the same up and down ramp rates over their entire dispatchable range, and to resources offering different up and down rates over ail ten segments of their dispatchable range.

In recent months, the dispatchable range offered to the market has been declining; however the downward trend has been reversed this month by an increase to 46% (Figure 18). While this is a good indication, the metric is still below the twehe month average of 49% and the MMU wilI continue to watch this metric closely.

RNU continues to be a problem with an EIS RNU of $4.3 million (Figure 21). This is an indication of possible inefficiencies in the design of the EIS market and the MMU continues to work with Market Design and Market Operations in an effort to identify the principal drivers of the RNU.

November 2008 3

SPP Market Monitoring Unit L YUil

Figures

Figure i - SPP €IS Price Contour Map

November 2008

I f”ix

November 2008 4

Lone Oak to Sardis (138)

Ism Binding)

csws $ 72v1 *2% Located in Southeast OK, planned and Fomd generation

Hugo Power Plant to Vallimt (138)

WFEC- $ 68.28 24.2% congestion. csws

' 12.85

8,75

$ 7.22

$ 5.27

'Ibis Wcyr to East flwpk from OK IO Shrevepgrt, I,A was congested while the linc from Okay to Pattersun to k w w n in sou*wesi AR was out. A= maintmancr also contribuled.

Ihe 500 kV lint from Ft. Smith to A N 0 was out. Gcncration in hrkanm has a big impact of this flowgate.

Imge I'LEI'O resrrurce outage in Western 1.h impacted

3-6%

o.7yo

1.1% thisflowgaL,

Transmission forced outages c a d congestion on t h i s 1.6% flowwk in mml KS,

SPP Market Monitoring Unit

Figure 2 - Congestion by Shadow Price impact - November 2008 40%

30%

1

lDXi i!

k 0%

$40 I - - , -... . -. , . . . . . - . _- . ... . .. ..-~ .

.. . - - . . - .

J

- Awage Hourly Shadow Price ($mmrvh) 96 Total IntervaIs Congeestad

I A v e q e l Total4 I Flowgate Natm Detailad Description

*ONSARPIlvAL

4PPVALPITVAL

The 0- of Flint C'wck to li. h w m n 161 kV and

bc built in this NonhwcsI RR Dycss to "st RogeFs I CSWS I $ 25.85 I 2.6% I Flint ( h y k 'lontituwn 161 kV necessitwod TtfMP04 to (161)

Plant X to Sundown These lrionh South tcmpmy flowgates in the

requests for thmnsl loading dccreases. SPS ha3

undcTgone m internal ratings methodology change to reducc the flow on WVLI'BI flowgaics. Plannod and forced gcneration outages in the Panhandk comhmcd

(230)

Kress to Hale Co. ( I 15)

Pmhndle ofTexas were put in xrvice to enable SPS EEyP11-15m

EM W7-15337

Craig Junction to AsMuwn West (13K)

Tahlquah to Highway 59(161)

:RAASHVALLYD csws

'AUHSMUSFTS GRDA- OKCiE

mOU(FRELDWR Dolet 10 E1 mmdo Transformer (345 123 0) CI.EC

WR South Phillips to West McPherson ( 1 15)

November 2008 5

SPP Market Moniforing Unit

Figure 3 - Congestion by Shadow Price impact - Previous 12 months - _ -

Figure 3 - Congestion by Shadow Price impact - Previous 12 months

T - _ -

-Awrage HoudyShadow Price (SIMWh) +% Total Intervals Congested

P r o m Solution [estimated completion date]

* ** Project includes new 32 mile 1 15 kV line from Knob Hill to Steele City, new 15 mile 1 15 kV line from Steele City tb

Part of the Balanced Portfolio P3-A to be approved in January 2009 by the CAWG, MOPC and BOD.

Harbine, and rebuild of 10.3 mile 115 kV line between Kelly and South Senem in northem Kansas. [6/1/2010]

November 2008 6

SPP Market Monitoring Unit

'ntervals

% Breadwd

Binding %

Figure 4 - Breached and Binding Flowgates by Interval

NOV DEC JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV last12 2QO7 2W7 2008 2008 2008 2008 2008 2008 2008 2008 2008 2008 2008 monihs

3% 1% 3% 4% 2% 3% 7% 11% 13% 10% 7% 8% 10% 6%

61% 44% 25% 23% 72% 72% 48% 70% 77% 68% 42% 46% 63% 54%

i 5%

-0 p1 c

10% m

c 5%

w n I

0%

60% w E rr E - E

0%

% Intervals Breached

t

Nov-07 Dee-07 Jan-08 Feb-08 Mar-08 Apr-08 May-08 Jun-08 Jul-08 Aug-OB Sep-08 Oct-08 Nov-OS

%Intervals Binding n - . .. .. ... ... m

Nov-07 OBc-07 Jan-08 kb-08 Mar-08 Apr-Ql May08 Jun-OS JuCOS Aug-OS Sep-OS oet-08 Nov-08

November 2008 7

SPP Market Monitoring Unit

in$ AECC AEPM EDEP GRDX GSEC KBPU KCPS KEPC KPP WDW M E OHPA S€CI SPSH WFES WRGG

Max 329 326 227 43 303 166 167 192 144 417 105 103 194 311 120 146

Avg 39 41 35 30 34 35 35 34 33 35 29 29 33 36 28 34

Min -13 -65 -6 -4 -17 8 8 -4 -8 -46 -22 -20 -77 -18 -41 6 -

o S P # L s r Power Pool

Figure 5 - Hourly Price Ranges by Market Participant - November 2008

$500

WO

5300

5100

M

-$lor

-'I

T

-~ AECC AEPH EOEP GRDX GSEC K W U KCPS KEPC KPP YlDW OGE OHPA SECl SPSM WFES WRGI

Markst Partlclpanl

I500

$300

st00

so

4100

- M P M a - MP Min

November 2008 8

SPP Market Monitoring Unit

in$ AECC AEPM EDEP GRDX GSEC KBPU KCPS KEPC KPP MIDW OGE OMPA SECl SPSM WFES

Max 580 536 54.4 530 2,302 548 548 543 556 971 537 537 833 2,229 537

h 0 53 56 51 50 63 49 50 50 SI 50 5 1 51 53 62 52

Min -156 -153 -155 -157 409 -175 -175 -156 -155 -167 -153 -153 -164 -418 -153

Figure 6 - Hourly Price Ranges by Market Parficipanf - Prev~ous .12 months

WRGS

551

50

-161

woo

1500

5300

$100

i o

-$loo

4200

.-

I

I

TI -r --I I I

AECC W M BP GRDX GSEC KBPU KCPS KEPC KPP MlDW OGE OMPA 8ECI SPSM WFES WRGS Market Partlclpant

- M P M a - MPMin M P A q -SPPAwmp= 5A25

$600

. $300

$200

$100

' so

- 4100

November 2008 9

SPP Market Monitoring Unit

Figure 7 - Regional Monthly Prices

$100 $'"I - .-

, . , .- . , . , , , . . -. .- . .

BSPP ~ E R C O T - - . . - . . - . .

4

I

Average Average Volatility On-Peak Off-peak

Price Price

Average Maximum Prim Price Prlce Region

SPP $ 34.98 $ 146.81 $ -13.31 48% $ 43.47 $ 28.78

I MISO I $ 36.58 I !I 191.51 I $ -35.30 I 61% I $ 46.21 I $ 28.87

I ERCOT I $ 37.94 I $ 422.76 I $ 15.51 I 103% I $ 45.02 I $ 32.28

Note: This table is a "rough comparison" because of inherent differences in the structure of the three markets and also because ofthe differences in how prices for SPP, MISO, and ERCOT 3re calculated. For SPP, load weighted averages are used, while the data from MISO and ERCOT are not bad weighted. Volatility is measured by the Cmffrcient of Variation, which is the standard deviation across all hours divided by the average of all hours.

A

- .* ,

Nw-07 B c 4 7 Jan-OB FebOB Mar44 Apr- YwO8 Jun-08 JuI-08 Augd8 Sep-08 oCt98 b w . 0 8

November 2008 10

864

419

45

13,688

888 720 831 463 -5 436 846 871 868 843 880 865

382 553 438 544 598 570 490 449 301 402 538 550

102 118 168 199 191 197 194 191 133 150 152 96

15,004 15,265 13,954 13,194 12,105 13,626 16,416 18,551 18,062 14,997 13,937 14,004

SPP Markef Monitoring Unit

Figure 8 - Generation by Fuel Type - . ... .. - - - . .... -. . , . .

II 1 . I . 1. I

t I Gas r N udear R Wind Other Coal

I Nuclear

I Wlnd I

bY% Nov- Dec- Jan- Feb Mar- Apr- May- dun- Jul- Aug- Sep Ocb Nor 07 07 08 08 08 08 08 08 08 08 08 08 08

68% 70% 68% 70% 67% 67% 68% 62% 60% 62% 68% 65% 65%

22% 21% 23% 20% 24% 27% 23% 29% 32% 31% 23% 24% 24%

6% 6% 5% 6% 4% 0% 3% 5% 5% 5% 6% 6% 6% 3% 3% 4% 3% 4% 5% 4% 3% 2% 2% 3% 4% 4%

0% I% I% 1% 2% 2% 1% 1% 1% 1% 1% 1% 1%

Coal 1 68%1 70% I 68%1 70%( 67% I 67%1 68%1 62% I 6U%I 62% I 68% I 65%1 65% Gas I 22% I 21% I 23% 1 20% I 24% I 27% I 23% I 29% I 32% 1 31% I 23% I 24% I 24%

Nuclear

Wind I 3%1 3%1 4%1 3%1 4%1 5%1 4%1 3%1 2 % [ 2%1 3%1 4%1 4% Other

Source: A

November 2008

SPP Market Monitoring Unit

Figure 9 - Wind Generation & Capacity

! 2,500

2,000

z E. - a 1,500 V B 0 U E

1,000

, - ... - . . .

2,000

a .- s 2 E 5

1,500 2

1,000 (9 W

500

0 Nov-07 Dew07 Jan-08 Feb-08 Mar-08 Apr-08 Yay-08 Jun-OS JuC08 Au9-08 Sep-08 od-08 Now08

D Wind Capaciiy (MW) -Wind Generation (GWh)

Now- Det Jan- Feb. Mar- Apr- May- Jun- JuC Aug- Sep Oct- Now 07 07 08 08 08 08 08 08 08 08 08 08 08

1,662 1,763 1,763 1,763 1,823 1,823 1,823 1,823 1,823 1,788 2,083 2,337 2,486

420.7 382.0 552.9 438.4 544.1 597.8 569.7 490.0 448.2 301.3 401.8 538.0 550.4

35% 29% 42% 36% 40% 46% 42% 37% 33% 23% 26% 31% 31%

20 23 23 23 27 25 25 25 25 25 29 32 33

ww)

GenePation (-1

F- #of

Resou-

t

Notes: I . In April 2008, 4 distinct re.mirces were combined tooform 2 resources, uccountingnfor the decrease in

the numha. of resources. 2. In Augacst 2008, a 95 MW resource was terminated, hut a 60 MW resource wus udded, accounting for

the wductiun of cnpuci@ of 35 MW.

November 2008 12

SPP Markei Monitoring Unit -

Figure f 0 - Wind Variabirity

This metric i: I under development

and will appear in the December report.

November 2008 13

SPP Market Monitoring Unit

loo1 80%

6046 t " ,'I

Figure V I - Fuel on the Margin

. %.

- u -

I;.

...

J

r "

:oal [I

I

0% 4 Now07 Dee07 Jan48 Feb-08 Mar-08 Apr-08 May-OB hn-08 Jul-08 Aug-08 Sep-OB Oct-08 Nov-08

a Gas rn Coal Other

Note: During nun-congested periods, oiie resource sets the price-fir ihe entire> marktt. During congesfd periods, the muvket is <ffectiidy segmented into seawul sub-areas, each with its owti marginal rcsuurcc. All conxm6ed intends count the Same us u nun-copages fed period, hut the marginal f i e / @pe,fir wch srah-arcw is r~pr~~~entc.cdprtlpclP.ti~na~1~ in the congested pciiod.

November 2008 74

Figure f 2 - Gas Cost 1 LIP Comparison

Electrlcity (UP)

[$IMWh]

Gas [QM M Btu]

$14 -

512 -*

$10 --

u : t $8 --

(3

Nov- Dec- Jan- Feb- Mar- Apr- May- Jun- Jul- Aug- Sep- Qct- Nov- 07 07 08 08 08 08 08 08 08 08 08 08 08

47-05 47.52 54.25 52.44 61.58 67.00 59.05 75.52 77.36 56.46 34.74 29.82 34.98

7.00 7.11 7.96 8.46 9.34 10.12 11.23 12.61 11.32 8.29 7.72 6.75 6.59

$6

$4

7 . . . . . .- - . . .. .

i '

" \- - 1

- 580

- $70

- $60 E

8 - $40 E

- E30

$2 I 1 Nov-07 Dee07 Jan-OB kb-08 Yar-08 Apr-08 Allay48 Jun-08 JuCOIL Aug-08 Sep-08 oct-08 b v - 0 8

-Gas --.e- 12 Month Average Gas I Electricity(L1P) -t 12 b n t h Awrage LIP

- $20

November 2008 45

SPP Market Monitwing Unit

by %

L Load)

+ S P # L s t Power Food

NOV DEC JAN FEE MAR APR MAY JUN JUL AUG SEP OCT NOV 2007 2007 2008 2068 2008 2668 2008 2 W 2008 2008 2008 2008 2008

7.8% 7.3% 6.9% 6.6% 8.4% 9.9% 9.1% 6.3% 9.1% 8.9% 8.4% 8 .5% 8.7% f 8.4%

Figure 13 - €IS Settlements - G Wh

Scheduled 92.2%

, . - , ... .. .

91 .bye 92.7% 93.1% 93.4% 91.6% 90.1% 60.9% 90.7% 90.9% 91.1% 91.6% 91.5% 91.3%

5 0

30,000

20,000

10,000

0 NOV JAN MAR APR MAY JUN J U nWj SEP OCT NOV 2007 2007 2008 2008 2008 2008 2008 2008 2008 2008 2008 2008 2008

Scheduled Transactions (GWh) H Load El GWh Resource El GWh

November 2008 16

SPP Markef Monitoring Unit

Figure 14 - €IS Settlements - $

5300 -

$200 ---

(#

5 s .- - -

$100

- . . . . - .. . . . , , ..... . . , - .. ,

W ryoV DEC JAN 2007 2007 2008

FEB MAR APR 2008 2008 2008

Load El

MAY JUN JUL

Resource El

2008 200s 2008

-I N W 2008

in million $

Resoure El

h d El

Total El

NOV DEC JAN FEB MAR APR MAY JUN JUL 2007 I 2007 1 2008 I 2008 I 2008 I 2008 I 2008 I 2008 I 2008 I tg

78 79 90 77 113 135 118 I93 215 148

21 24 24 20 31 42 38 57 65 53

90 I 69 I 79 11 1.758

November 2008 17

SPP Market Monitoring Unit

inGWh

tsEh SalfDlapatch

SUpplemSlIhl Only

Manual (*r) Manual

(intermittent)

TdTAL

Figure 75 - Depth of Energy Market for Resources Only - by Status

T 20,000

HOV DEC JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV 2007 2007 2008 2008 2000 200a 2008 Moa moa 2008 2008 2008 MOB

10,374 11,248 11,724 10,712 10,081 9,697 10,678 12.857 14,856 14,436 11.978 11,llX 11.048 I 140,432

t,922 2,202 1,741 1,R03 1,520 741 1,135 1,775 1,977 2,011 1,777 1,499 1,538

1 1 1 0 0 5 0 1 1 1 1 0 2

451 1,116 1,223 970 1,043 1,060 1,268 1379 1242 1,288 855 761 831

464 433 621 191 593 654 626 540 513 436 56n 720 724 6,W I

13.7I3 15.000 tS.310 13.976 13,237 12,157 13.706 16,451 18,589 18,173 15.171 14,098 14,143 180,011

1

5,000

0 1 - - .,. .." - ....

Nw DEC JAN AB MAR APR MAY JUN JUL AUG S8p OCT NOV

I Market Oispatch Self-Dispatch R Supplemental only rn Wnual (other) rn k n u a l (intermittent) 2007 zoo7 2008 2008 2008 2008 2008 2008 a m 2008 m a 2008 2008

. ,

77%

13%

0%)

7%

3% I 3% I 4% I 4% -

. Muy not m a l to 100% due to :e: Mctcred Settlement &tu

November 2008

SPP Market Monitmhg Unit

NOV DEC 2007 2007

2.2 2.5

61 63

Figure 16 - Resource Five Minute Ramp Rates Ofired and Available fo the €IS Market

JAN FEB MAR APR MAY JUN JUL AUG SEP Dcf NOV 2008 2008 2008 2008 2008 2008 2008 2008 2008 2008 2008

2.7 2.6 2.6 2.7 2.5 2.6 2.6 2.7 2.8 2.9 3.5

63 61 61 63 68 87 96 92 73 ti3 A4

4.0

3.5 v

I 0 a J E ’ 3.0 k

2 .o

I00

x E 2

60 Now07 DBc-07 Jan48 Feb-08 Mar-08 Apr-08 May-OB Jun-08 J u M Aug-OS Sep-08 Oct-08 N o ~ 0 8

Average MW per Minute

Ramp offered

Average C w n t of Rasourms

Offwing Ramp

-Average M per Minute of Ramp m r e d Average Count of ReSources OPfeflng Ramp

12 month amraw

2.7

71

November 2008 19

SPP Market lwonitm'ng Unit

Figure 17 - Monthly Summary of #arket Ramp Rate Deficiency

160

120

0 s 40 '

. . .. ~ . . . I _ _ _ , . .. .. ... ...-... "

I I- I

I

I

I

.. . . . . - .- .

/

b u r wc-w Jan-08 Feo-ua m a r - l Apr-Ol May-08 Jun-08 JuC08 Aug48 Sep.08 Lmv8 Nov-bd - UP Ramp Deficiency Intemals +ToiaI MW Ramp Available per Mnub

D DOWN Ramp Deficiency Intewls

I '

I I ' .

I I '

300

250

200

150

100

$2 month -w

54

10

64

0.7%

i94

November 2008 20

SPP Market Monitoriig Unit

' Mow Dee Jam Fob- Msr- Apr- Map Juw JuC Aug S%p 8d- Nev- b t f 2

Average 47.9% 4S.5% 48.1% 49.0% 50.1% 39.4% 48.0% 50.6% 51.5% 49.4% 47.8% 44.8% 46.2% 48.6% 07 07 OB os 08 08 oa 08 08 08 08 08 08 mo ---------------

a)SP$#rbturJt Power Pool

Figure 18 - Dispatchable Range

52%

48%

44%

. - . . . . - .. , .. - , . ". , I_ . ._-I

I 1 I I I I I I I I I I I I 1 1 I I I 1 1

Now07 Dee47 Jan-08 Feb-08 Mar48 Apr-08 May08 Jun-08 Jul-OS Au@S Sep-08 Oct-08 N o d B

AdjMax = Resource Plan Max, adjusted for ancillay service. AdjMin = Resource Plan Min, adjusted for ancillary service. Resource Plan Range = (AdjMax - AdjMin) I AdjMax for a particular resource.

For example: Resource A: AdjMax = 200, AdjMin = 100; (200 - 100) I 200 = 50% Range Resource B: AdjMax = 200, AdjMin = 180; (200 - 180) / 200 = 10% Range

November 2008 27

SPP Market Monitoring Unit L)SP$#tbssst Power Pool

Figure I 9 - Transmission Owner Revenue

#

$30

$10

. .... - . ... . - .. -. . . . . - ..

1.

DEC - 25.0 32.0

November 20U8 22

PO WdY PO 0

in~%#sands NOV DEC JAN FEB MAR APR YAY JUN JUL AUG MWh 2007 2007 2008 2008 2008 2008 2008 2008 2008 2008

381 385 422 397 384 389 370 384 420 412

91 88 92 87 86 93 78 86 96 94

Arerage Dally

Reoervations Average

* M U M -- -- -- % 24% 23% 22% 22% 22% 24% 21% 22% 23% 23%

SPP Market Monitoring Unit

SEW OCT NOV 2008 2008 2008

396 410 404 1 398

89 89 89 92 I d-

23% 22% 23% 22%

Figure 20 - Average Trahsmission Reservations and Schedules

f 300 E I

-1

60% r I 20% - -

I 1 - 0%

I 0-

ND-07 Dee-L! Jan-08 Feb-OB Mar-08 Apr-OB May-08 Jun-08 JuM8 Aug-08 Sap08 oct.08 Now08

- A y . DailyTransmission Reservations -Schedules as a % of Reservations

I

No wember 2008 23

A!!!/

$(mmndsl

EIS

SPP Market Moniiofiig Unit

How D e e Jan- Feb- Mar- Apr- May- Jun- Jul- Aug Sep Oct- NOW 07 07 08 08 08 08 08 08 08 08 os oa oa

-1,377 -2,735 -1,138 -1,295 4,731 -3,473 -1,961 -1,834 3,625 1,309 370 1.593 4.294

a r - v1ap Y t bwes f

Power P o d

UIS UDC

Figure 21 - RNU Components

-40 -70 -23 -48 -472 -1,047 -560 435 -428 417 4 2 -80 -107

-83 -109 -126 -100 -130 -151 -175 -266 -363 -235 -137 -108 - 1 1 1

$4

SP Loss 64

Total RNU -1,506

$2

19 7 0 5 -3 -14 -45 4 9 -44 - 1 5 -45 -67

-2.914 -1,288 -1.455 -5.376 -4.731 -2,829 -2,852 2,582 366 36 1,255 3,843

II R

' ?.1 I I m

Nw07 Dec-07 Jan48 Few8 Mar-OB Apr-08 Map08 JuwO8 Jut48 AuMS SepO8 Oet-08 NOM8 - EIS DIS =UIs DUDC -SPLOSS -TotalRNU

I I I I I I I

I 01s I -69 I -19 I -9 I -11 I -47 I -57 I -119 I -272 I -183 I -247 I -139 1 -105 I -167 I

I I I I I I I I I I I I I

- EIS (Energy Imbalance ChargelCdZ) - All energy deviatims bsfween actual generation or bad and schedules are settled as (€IS). pLs (Over-Scheduling Charge) - During any hour, if Locational Imbalance Prices diverge and a Market Partlapant's Load imbalance is more than

- UIS (Under-Scheduling Charge) - During any hour, if Locational Imbalance P W s diverge and a Market Participant's Load imbalance is more than

- UDC (Uninstructed Resource Deviation) - the difference between the &pat& in$tWction$ and the amal performance of a Resource. SP Loss - Self-Provided Losses

4% (but at least 2 MW) at an app4icabk Settlement Location in that hwr, that MP may be subjed to an Over-Scheduling Charge.

4% (but at least 2 MW) at an applicable Settlement Lmtion in that hour, that MP may be subject to an Under-Scheduling Charge.

November 2008 24

CERTIFICATE OF SERVICE

I, Heather H. Starnes, attorne of record for Southwest Power Pool, Inc., do hereby certfl that I have, on this 1 + day of December, 2008, duly served a true and correct copy of the above and foregoing pleading upon all parties of record by electronic mail.

ther H. StamXs -

4