CORPORATE METRICS metrics 2q2019.pdf · TMP270_23432 Eastern Oklahoma; TMP127_23359 Western...

CORPORATE METRICS

2nd Quarter 2019

July 23, 2019

1

Transmission and MarketFinanceEngineering Studies

M.1. TCR/ARR SummaryM.2. CongestionM.3. Regional Control PerformanceM.4. PricesM.5. Make Whole Payments / Revenue Neutrality UpliftM.6. Virtual ActivityM.7. Capacity and Commitments

Financial MetricsF.1. Admin Fee MeasurementF.2. CreditF.3. Settlement DisputesF.4. Human Resources

P.1. Regional Entity Compliance (no longer applicable)P.2. System PerformanceP.3. Transmission Service StudiesP.4. Generation Interconnection StudiesP.5. Strategic Plan

Metrics Definitions

SupplementsRegulatory Activity Update & OutlookGovernment Affairs Quarterly Activity Report

Southwest Power Pool Corporate Metrics

DISCLAIMERThe data and analysis in this report are provided for informational purposes only and shall not be considered or relied upon as market advice or market settlement data. Southwest Power Pool (SPP) makes no representation or warranties of any kind, express or implied, with respect to the accuracy or adequacy of the information contained herein.

SPP shall have no liability to recipients of this information or third parties for the consequences arising from errors or discrepancies in this information, or for any claim, loss or damage of any kind or nature whatsoever arising out of or in connection with (i) the deficiency or inadequacy of this information for any purpose, whether or not known or disclosed to the authors, (ii) any error or discrepancy in this information, (iii) the use of this information, or (iv) a loss of business or other consequential loss or damage whether or not resulting from any of the foregoing.

Performance Metrics

Transmission & Market Indicators

Dashboards

2

Das

hboa

rds

3

Das

hboa

rds

4

Das

hboa

rds

5

M.1.1. ARR Funding SummaryTr

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0%

50%

100%

150%

200%

250%

$0

$10

$20

$30

$40

$50

Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19

Mill

ions

TCR Revenue ARR FundingARR Surplus Funding PercentCumulative Funding Percent - Prior Year Cumulative Funding Percent - Current Year

6

M.1.2. TCR Funding SummaryTr

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-20%

0%

20%

40%

60%

80%

100%

120%

-$20

$0

$20

$40

$60

$80

$100

$120


Mill

ions

DA Revenue TCR FundingTCR Uplift Funding PercentCumulative Funding % - Prior Year Cumulative Funding % - Current Year

7

M.2.1. Congestion - TLR / CME Time

in hours Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19 2017 2018 2019Prev 12

moNon-Firm Curtailments

20 37 0 19 1 10 5 12 20 66 30 34 14 24 5 37 33 29 20

Firm Curtailments 24 36 0 0 9 3 5 73 13 52 0 7 0 42 165 43 48 44 31

Total 44 73 0 19 10 13 10 85 33 118 30 41 14 66 170 79 81 73 51 CME Time (loading >90%)

3918 2913 4615 3070 3837 3923 3349 5026 5338 4575 2391 3895 4086 3939 3674 5,414 4,222 3,760 3,925

Monthly Average in HoursTran

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0

2,000

4,000

6,000

8,000

0

100

200

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Hou

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CM

E

Hou

rs in

TLR

Firm Curtailments Non-Firm Curtailments CME Time (loading >90%)

-

25

50

75

100

2017 2018 2019 Prev 12mo

Monthly Average Non-Firm Curtailments (hrs)

-

25

50

75

100

2017 2018 2019 Prev 12mo

Monthly Average Firm Curtailments (hrs)

- 1,000 2,000 3,000 4,000 5,000 6,000

2017 2018 2019 Prev 12mo

Monthly Average CME Time (hrs)

8

M.2.2. Congestion - Congested Intervals (RTBM)

Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19 2016 2017 2018 12 mo

Uncongested Intervals

9% 12% 2% 2% 1% 2% 10% 13% 14% 7% 4% 20% 16% 15% 16% 15% 9% 18% 18%

Intervals with Binding Only

56% 50% 47% 44% 55% 51% 46% 50% 55% 56% 73% 57% 39% 41% 43% 64% 54% 53% 50%

Intervals with a Breach

35% 37% 51% 54% 44% 47% 44% 37% 32% 37% 22% 22% 45% 44% 41% 21% 37% 29% 32%

Interval = 5 minutes Average

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0%

10%

20%

30%

40%

2016 2017 2018 12 mo


0%

20%

40%

60%

80%

100%

Uncongested Intervals Intervals with Binding Only Intervals with a Breach

0%

20%

40%

60%

80%

100%

2016 2017 2018 12 mo


0%

10%

20%

30%

40%

50%

2016 2017 2018 12 mo


9

M.2.2.1 Congestion - Congested Intervals (DAMKT)

Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19 2016 2017 2018 12 mo


0% 1% 2% 1% 10% 0% 1% 1% 0% 0% 0% 3% 0% 0% 0% 1% 0% 2% 1%


99% 99% 96% 99% 90% 100% 99% 99% 99% 100% 100% 97% 100% 99% 99% 98% 99% 98% 98%


0% 0% 1% 0% 0% 0% 0% 0% 1% 0% 0% 0% 0% 1% 1% 0% 1% 0% 0%

Interval = 1 hour Average

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0%

2%

4%

6%

8%

2016 2017 2018 12 mo


0%

20%

40%

60%

80%

100%

Uncongested Intervals Intervals with Binding Only Intervals with a Breach

0%

20%

40%

60%

80%

100%

2016 2017 2018 12 mo


0%

2%

4%

6%

8%

2016 2017 2018 12 mo


10

M.2.3. Price Contour Map (July 2018 - June 2019)

Day-Ahead Real-Time

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11

M.2.4. Congestion - Flowgates (July 2018 - June 2019)

Flowgate Name Region Flowgate LocationTMP175_24736 North-central Oklahoma Braman-Newkirk Tap 69kV ftlo Hunter-Woodring 345kV (OKGE)TMP270_23432 Eastern OklahomaTMP127_23359 Western Nebraska Scotsbluff-Victory Hill 115kV (NPPD) ftlo Stegall Xfmr 345kV/1 (WAUE)TMP109_22593* Eastern OklahomaTMP421_24095 Central Oklahoma Cimarron Xfmr 345/138kV ftlo Cimarron Xfmr 345/138kV (OKGE)TEMP72_22893 Eastern Kansas Wolf Creek 345kv/1 (WR) ftlo Wolf Creek-Waverly 345kV (WR-KCPL)FRAMIDCANCED Central OklahomaTMP159_24149 South-central Oklahoma Russett Switch-Brown 138kV (WFEC) ftlo Little City-Brown Tap 138kV (OKGE)NEORIVNEOBLC* SE Kansas/SW Missouri Neosho-Riverton 161kV (WR-EDE) ftlo Neosho-Blackberry 345kV (WR-AECI)TEMP71_24753 Central Kansas Knoll-Redline 115kV ftlo Post Rock-Axtell 345kV (MIDW)

* SPP Market-to-Market flowgate

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Cleveland-Clev AECI 138kV (GRDA-AECI) ftlo Cleveland-Tulsa North 345kV (GRDA-CSWS)

Stonewall Tap-Tupelo Tap 138kV (WFEC) ftlo Seminole-Pittsburg 345kV (CSWS-OKGE)

Franklin-Midwest 138kV (WFEC-OKGE) ftlo Cedar Lane-Canadian 138kV (OKGE)

0%

10%

20%

30%

40%

$0

$10

$20

$30

$40

% C

onge

sted

Shad

ow P

rice

($/M

Wh)

DA Average Shadow Price RT Average Shadow Price DA % Intervals Congested RT % Intervals Congested

12

M.2.4.1 Congestion - Flowgates (July 2018 - June 2019)Flowgate Name Region Flowgate Location Projects or operations that may provide mitigation

TMP175_24736North-central

OklahomaBraman-Newkirk Tap 69kV ftlo Hunter-Woodring 345kV (OKGE)

None identified at this time

TMP270_23432Eastern

Oklahoma

Cleveland-Clev AECI 138kV (GRDA-AECI) ftlo Cleveland-Tulsa North 345kV (GRDA-CSWS)

None identified at this time. [Identified as an economic need in the 2019 ITP Assessment to be completed October 2019]

TMP127_23359Western Nebraska

Scotsbluff-Victory Hill 115kV (NPPD) ftlo Stegall Xfmr 345kV/1 (WAUE)


TMP109_22593*Eastern

Oklahoma

Stonewall Tap-Tupelo Tap 138kV (WFEC) ftlo Seminole-Pittsburg 345kV (CSWS-OKGE)

Tupelo 138 kV Terminal Upgrades (July 2021, 2017 ITP10)

TMP421_24095Central

OklahomaCimarron Xfmr 345/138kV ftlo Cimarron Xfmr 345/138kV (OKGE)


TEMP72_22893 Eastern KansasWolf Creek 345kv/1 (WR) ftlo Wolf Creek-Waverly 345kV (WR-KCPL)

None identified at this time. [Related to an economic and reliability need in the 2019 ITP Assessment to be completed October 2019]

FRAMIDCANCEDCentral

Oklahoma

Franklin-Midwest 138kV (WFEC-OKGE) ftlo Cedar Lane-Canadian 138kV (OKGE)


TMP159_24149South-central

OklahomaRussett Switch-Brown 138kV (WFEC) ftlo Little City-Brown Tap 138kV (OKGE)

None identified at this time. [Related to an economic need in the 2019 ITP Assessment to be completed October 2019]

NEORIVNEOBLC*SE Kansas/SW

MissouriNeosho-Riverton 161kV (WR-EDE) ftlo Neosho-Blackberry 345kV (WR-AECI)

None identified at this time. [Related to an economic need in the 2019 ITP Assessment to be completed October 2019]

TEMP71_24753 Central KansasKnoll-Redline 115kV ftlo Post Rock-Axtell 345kV (MIDW)


* SPP Market-to-Market flowgate

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M.3.1. Balancing Authority Report - CPS PerformanceTr

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0%

25%

50%

75%

100%

125%

150%

175%

200%


CPS1 (statistical measure of 1 minute average ACE vs. Frequency)

> 120% >=110% and <=120% >=100% and <110% <100%

14

M.3.2. Balancing Authority Report - BAAL Performance

Event Length Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19

>10 and <=20 min 0 0 2 1 0 0 0 1 0 0 0 0 1 0 1

>20 and <=25 min 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1

>25 and <=30 min 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

>30 min 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Tran

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0

2

4

6

8

10


Even

tsBAAL Performance

>10 and <=20 min >20 and <=25 min >25 and <=30 min >30 min

15

M.4.1. Price (July 2018 - June 2019)Tr

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s

$25.49

$24.86

$18

$22

$26

$30

$34

AECC

/AEC

CAE

PE/B

PWN

AEPE

/CO

SNAE

PE/S

SCN

AEPE

/WTM

NAE

PM_X

/AEP

MBE

PM/B

EPM

BEPM

/NM

CA_X

BRPS

/BRP

SCH

AN/C

HAN

EDEP

/ED

EPET

EC/E

TEC

FREM

/FRE

MGR

DX/G

RDX

GSEC

/GSE

CH

MM

U/H

MM

UIN

DN/IN

DN

KBPU

/KBP

UKC

PS/K

CPS

KCPS

/UCU

KMEA

/EM

P1_X

KMEA

/EM

P2_X

KMEA

/EM

P3_X

KMEA

/EUD

O_X

KPP/

KPP

LESM

/LES

MM

ECB/

MEC

BM

EUC/

MEU

CM

IDW

/MID

WM

RES/

MUM

Z_X

NSP

P/N

SPP

NW

PS/N

WM

T_X

NW

PS/N

WPS

OGE

/OGE

OM

PA/O

MPA

OPP

M/O

PPM

OTP

W/O

TPR_

XRE

MC/

CWEP

REM

C/PR

TTSE

PC/S

EPC

SPSM

/SPS

MTE

A/FC

U_X

TEA/

MEA

NTE

A/N

CU_X

TEA/

NEL

I_XTE

A/N

PPM

TEA/

SPRM

TNSK

/GAT

E_X

TNSK

/TN

GI_X

TNSK

/TN

HP_

XTN

SK/T

NH

U_X

UGPM

/EW

A_X

UGPM

/MM

PA_X

UGPM

/OTP

_XUG

PM/U

GPM

WFE

S/W

FES

WRG

S/10

73W

RGS/

CHAN

WRG

S/CO

WP

WRG

S/KN

01W

RGS/

PARL

WRG

S/PB

EL

LMP

($/M

Wh)

Day-ahead LMP Real-time LMP SPP day-ahead average LMP SPP real-time average LMP16

M.4.2. Price Volatility - standard deviation (July 2018 - June 2019)Tr

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Mar

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12.3

47.1

0

10

20

30

40

50

60

70

AECC

/AEC

CAE

PE/B

PWN

AEPE

/CO

SNAE

PE/S

SCN

AEPE

/WTM

NAE

PM_X

/AEP

MBE

PM/B

EPM

BEPM

/NM

CA_X

BRPS

/BRP

SCH

AN/C

HAN

EDEP

/ED

EPET

EC/E

TEC

FREM

/FRE

MGR

DX/G

RDX

GSEC

/GSE

CH

MM

U/H

MM

UIN

DN/IN

DN

KBPU

/KBP

UKC

PS/K

CPS

KCPS

/UCU

KMEA

/EM

P1_X

KMEA

/EM

P2_X

KMEA

/EM

P3_X

KMEA

/EUD

O_X

KPP/

KPP

LESM

/LES

MM

ECB/

MEC

BM

EUC/

MEU

CM

IDW

/MID

WM

RES/

MUM

Z_X

NSP

P/N

SPP

NW

PS/N

WM

T_X

NW

PS/N

WPS

OGE

/OGE

OM

PA/O

MPA

OPP

M/O

PPM

OTP

W/O

TPR_

XRE

MC/

CWEP

REM

C/PR

TTSE

PC/S

EPC

SPSM

/SPS

MTE

A/FC

U_X

TEA/

MEA

NTE

A/N

CU_X

TEA/

NEL

I_XTE

A/N

PPM

TEA/

SPRM

TNSK

/GAT

E_X

TNSK

/TN

GI_X

TNSK

/TN

HP_

XTN

SK/T

NH

U_X

UGPM

/EW

A_X

UGPM

/MM

PA_X

UGPM

/OTP

_XUG

PM/U

GPM

WFE

S/W

FES

WRG

S/10

73W

RGS/

CHAN

WRG

S/CO

WP

WRG

S/KN

01W

RGS/

PARL

WRG

S/PB

EL

Vola

tility

(sta

ndar

d de

viat

ion)

Day-ahead volatility Real-time volatility SPP day-ahead average volatility SPP real-time average volatility17

M.4.3. Electricity/Gas Price Comparison

Average in $ Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19

DA LMP ($/MWh)

22.32 25.27 24.69 28.06 24.29 20.58 28.01 33.08 26.79 23.59 24.26 27.20 20.18 23.76 21.32

RT LMP ($/MWh)

21.67 22.80 24.06 28.08 22.48 20.96 31.00 30.12 24.00 22.89 23.44 21.49 21.88 24.24 20.69

PEPL GasCost ($/MMBtu)

2.23 2.08 2.25 2.44 2.37 2.12 2.80 3.67 3.56 2.91 2.51 2.72 1.82 1.88 1.37

Tran

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$0

$1

$2

$3

$4

$0

$10

$20

$30

$40


Gas

Cost

(Pan

hand

le E

aste

rn P

ipel

ine)

$/M

MBt

u

DA LMP RT LMP Gas (PEPL)

Elec

tric

ity P

rice

($/M

Wh)

18

M.4.3.1 Prices - annual

avg (in $) 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018Day-ahead Price ($/MWh)

32.36 22.84 22.43 23.11 25.11

Real-time Price* ($/MWh)

49.42 53.21 27.89 31.33 29.28 22.29 25.89 31.42 21.85 22.36 23.43 24.56

PEPL Gas Cost ($/MMBtu)

6.15 7.12 3.31 4.17 3.89 2.64 3.58 4.45 2.43 2.32 2.65 2.59

Tran

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* 2014 RTBM includes last two months of LIP for the EIS market, and RTBM LMP for the first ten months of the Integrated Marketplace. All prior years use EIS LIP.

$0

$2

$4

$6

$8

$0

$20

$40

$60

$80

2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018

$/M

Wh

$/M

MBt

u

Day-ahead Price ($/MWh) Real-time Price* ($/MWh) PEPL Gas Cost ($/MMBtu)

19

M.4.4. Price DivergenceTr

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20

M.5.1. Revenue Neutrality Uplift

in thousands $ Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19 2016 2017 2018 12 mo

Total Uplift 7,665 4,710 5,535 5,493 2,958 7,841 6,181 8,192 10,178 10,614 10,524 3,674 13,849 18,923 10,421 26,566 62,268 59,562 92,557

Revenue Neutrality Uplift (RNU) ensures settlement payments/receipts for each settlement interval equal zero.• Positive RNU - SPP receives insufficient revenue and collects from market participants.• Negative RNU - SPP receives excess revenue, which must be credited back to market participants.

Tran

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Total

$0

$4

$8

$12

$16

$20in

mill

ions

$

$0

$20

$40

$60

$80

$100

2016 2017 2018 12 mo

Tota

l in

mill

ions

$

21

M.5.1.1 Revenue Neutrality Uplift Table

in thousands $ Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19

DA Revenue Inadequacy 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

RT Revenue Inadequacy 22 24 -83 -101 -30 -89 -107 -90 -116 -60 30 19 -226 -89 -178

RT OOME MWP -392 -158 -199 -498 -64 -191 -133 -234 -273 -243 -187 -258 -390 -1,186 -189

RT Regulation Deployment Adj -201 47 -168 -102 -18 -35 -143 -220 -61 -137 -61 -80 10 -4 -3

RT JOA Adj 1,924 300 28 -1,653 -514 -165 30 1,111 1,549 1,458 3,652 2,531 1,655 3,633 -2,276

RT Congestion Adj -8,805 -4,876 -4,885 -2,849 -2,296 -7,357 -5,699 -8,653 -11,363 -11,340 -13,712 -5,633 -14,628 -21,135 -7,356

SUBTOTAL -7,452 -4,664 -5,308 -5,201 -2,922 -7,837 -6,053 -8,086 -10,264 -10,322 -10,278 -3,421 -13,580 -18,781 -10,001

Less RT Net Inadvertent Adj 214 46 227 292 35 4 128 106 -86 292 247 253 270 142 421

TOTAL RNU 7,665 4,710 5,535 5,493 2,958 7,841 6,181 8,192 10,178 10,614 10,524 3,674 13,849 18,923 10,421

* This table is based on the latest available settlements data and is subject to change due to resettlement.

Tran

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22

M.5.2. Make Whole PaymentsTr

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$0

$3

$6

$9M

illio

nsDay-Ahead

Coal Gas-CC Gas-CT Hydro Other Wind

$0

$3

$6

$9

Mill

ions

RUC (Real-Time)

Coal Gas-CC Gas-CT Hydro Other Wind

23

M.5.3. All-In PriceTr

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Mar

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24

M.6. Virtual ActivityTr

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Mar

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25

M.7.1. Excess CapacityTr

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26

M.7.2. Source of CommitmentTr

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DA_RUC – Day-Ahead Reliability Unit CommitmentID_RUC – Intra-Day Reliability Unit CommitmentDAMKT – Day-Ahead Market

27

F.1.1. Admin Fee MeasurementFi

nanc

ial M

etric

s

28


nanc

ial M

etric

s

29


nanc

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etric

s

30

F.2. Credit

Transmission ($000s) Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19 12 moLate Payments $0 $206 $184 $1,352 $6,197 $138 $1,331 $20 $824 $528 $72 $145 $10,998Total Payments $53,565 $54,159 $53,515 $49,442 $45,549 $42,145 $47,475 $47,762 $60,950 $56,208 $53,609 $54,355 $618,735% Late Payments 0% 0% 0% 3% 14% 0% 3% 0% 1% 1% 0% 0% 2%

Market ($000s) Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19 12 moLate Payments $8 $152 $2 $139 $50 $1 $11 $1,234 $24 $0 $12 $0 $1,634Total Payments $117,544 $78,359 $70,340 $108,725 $96,279 $106,611 $89,468 $87,771 $100,701 $95,804 $80,347 $78,620 $1,110,568% Late Payments 0% 0% 0% 0% 0% 0% 0% 1% 0% 0% 0% 0% 0%

Short Pays ($000s) Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19 12 moTransmission $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $9 $9Market $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Uncollectible ($000s) Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19 12 moTransmission $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Market $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Fina

ncia

l Met

rics

0%

3%

6%

9%

12%

15%%

of T

otal

Pay

out

% of Late Transmission Payments

0%

5%

10%

15%

20%

25%

% o

f Tot

al P

ayou

t

% of Late Market Payments

$0

$100

$200

$300

$400

in th

ousa

nds

Transmission Short Pays

$0

$10

$20

$30

$40

in th

ousa

nds

Market Short Pays

31

F.3. Settlement Disputes

Apr 18 May 18 Jun 18 Jul 18 Aug 18 Sep 18 Oct 18 Nov 18 Dec 18 Jan 19 Feb 19 Mar 19 Apr 19 May 19 Jun 19Total # of Open Disputes (at month-end)

9 7 7 - 2 3 4 1 5 3 4 1 2 3 -

Average Days Outstanding (granted in month)

10 5 9 12 - - 2 2 1 1 2 1 3 - 7

Average Dispute Amount (granted in month)

$1.5 $0.5 $16.5 $0.1 $11.3 $125.3 $17.2 $4.9 $81.3 $40.3 $12.8 $0.1 $2.1 $26.3 $1.7

# of Resettlements (published in month)

123 127 16 32 37 37 41 34 65 65 66 34 41 39 38

Fina

ncia

l Met

rics -

15

30

45

60

75Total # of Open Disputes (at month-end)

-

15

30

45

60

75Average Days Outstanding (granted in month)

$0

$40

$80

$120

$160

$200

in th

ousa

nds

Average Dispute Amount (granted in month)

-

25

50

75

100

125

150# of Resettlements (published in month)

32

F.4.1. Human ResourcesFi

nanc

ial M

etric

s

33

P.2.1. IT System PerformancePe

rfor

man

ce

34

P.2.2. Operational System AvailabilityPe

rfor

man

ce

STLF – Short-term load forecastRTLODF – Real-time Line Outage Distribution FactorDAMKT – Day-Ahead MarketDARUC – Day-Ahead Reliability Unit Commitment

35

P.2.3. System AvailabilityPe

rfor

man

ce

STLF – Short-term Load ForecastMTLF – Mid-term Load ForecastDAMKT – Day-Ahead MarketID RUC – Intra-day Reliability Unit CommitmentRTBM – Real-time Balancing Market

36

P.3. Transmission Service StudiesPe

rfor

man

ce

37

P.4.1. Generation Interconnection Studies

In Progress 2Q18 3Q18 4Q18 1Q19 2Q19Transfer IS QueueDISIS-2015-002 1,600 1,186 DISIS-2016-001 6,499 5,614 4,563 4,569 1,895 DISIS-2016-002 15,388 13,126 12,465 12,087 12,087 DISIS-2017-001 15,200 16,398 15,990 15,494 15,845 DISIS-2017-002 27,490 27,811 27,686 24,313 24,073 DISIS-2018-001 10,105 10,375 10,605 11,025 11,005 DISIS-2018-002 11,438 11,941 12,061 DSIS-2019-01 125 7,697 PISIS-2017-002 1,534 FCS-2017-003 320 FCS-2018-001 270 FCS-2018-002 750 650 500 FCS-2018-004 1,070 1,070 FCS-2019-002 1,814 FCS-2019-003 70

TOTAL 79,157 75,160 84,318 80,624 86,546

MW

Perf

orm

ance

- 5,000

10,000 15,000 20,000 25,000 30,000 35,000 40,000 45,000 50,000 55,000 60,000 65,000 70,000 75,000 80,000 85,000 90,000

2Q18 3Q18 4Q18 1Q19 2Q19

MW

Generation Interconnection MW - In Progress

2015 Studies 2016 Studies 2017 Studies 2018 Studies 2019 Studies

Battery, 6,896CT/Gas,

406Solar, 29,330

Wind, 49,914

Active Studies by Prime Mover (MW)

38

P.4.2. Commercial Operation Dates as of June 30, 2019

MW CapacityIA Fully Executed / On Suspension 1,301.0 IA Fully Executed / On Schedule 7,793.1 Total Scheduled or Suspended Generation 9,094.1

Charts above reflect Executed Generation Interconnection Agreements (GIA’s) with upcoming Commercial Operation Date (COD) milestones by year and month. Data based on Queue Status of “IA Fully Executed / On Schedule”.

Perf

orm

ance

0

200

400

600

800

1,000

1,200

1,400

1,600

1,800

2,000

Apr

Jun

Aug

Oct

Dec Feb

Apr

Jun

Aug

Oct

Dec Feb

Apr

Jun

Aug

Oct

Dec Feb

Apr

Jun

Aug

Oct

Dec Feb

Apr

Jun

Aug

Oct

Dec

2017 2018 2019 2020 2021

MW

Cap

acity

Commercial Operation Month

0

1

2

3

4

5

2017 2018 2019 2020 2021

GW

Cap

acity

Commercial Operation Year

CT/Gas*, 29

Solar, 290Wind, 7,454

On Schedule by Prime Mover (MW)

39

P.5. Strategic PlanPe

rfor

man

ce

40

P.5.1 Strategic Plan: Variable Energy Resources Initiative TrackingPe

rfor

man

ce

41

METRICS DEFINITIONS

Transmission and Market Indicators Two groups of metrics will be monitored to provide an overall health indication of the regional transmission system and market.

• Reliability Performance Indicators, which focus on the actual operations of the transmission system and whether or not it was operated within expected limits and standards.

• Market Performance Indicators, which focus on the performance of the market in terms of overall volume, prices and level of participation.

Reliability Performance Indicators This sub-group of metrics is designed to measure the operations of the transmission system from a reliability perspective.

• How well-funded are Transmission Congestion Rights (TCR). (see TCR/ARR Summary) • How much time was congested during the period. (see Congestion) • Was the system operated in compliance with the relevant control performance standards? (see Regional Control Performance)

M.1. TCR/ARR Summary

TCR/ARR funding is derived as follows: 1. Day-ahead revenue is collected daily 2. TCR holders are paid daily based on awarded TCR MW and Day-ahead clearing prices

a. Uplift is charged daily b. Surpluses are redistributed Monthly and Annually

3. TCR revenue is collected daily based on TCR MW and TCR ACPs (consistent through month/season) 4. ARR holders are paid daily based on ARR MW and TCR ACPs (consistent through month/season)

a. Uplift is charged daily b. Surpluses are redistributed Monthly and Annually

M.2. Congestion

M.2.1. TLR / CME Time

TLR Events by level (in hours)

• Non-Firm (Level 3) – curtailment of non-firm schedules and non-firm market flow • Firm (Level 5) – curtailment of all non-firm and some firm schedules and market flow

• CME (Congestion Management Events) where loading is greater than 90% (in hours)

M.2.2. Congested Intervals

Percent of intervals binding (flow = System Operating Limit [SOL]), breached (flow > SOL) and congested (either binding or breached) during the month. Charts are included for both the Day-Ahead Market (DAMKT) and the Real-Time Balancing Market (RTBM).

M.2.3. Price Contour Map

Graphic representation of average monthly prices by load area in both the Day-Ahead Market and Real-Time Balancing Market since the start of the Integrated Marketplace.

M.2.4. Congestion – Flowgates

• Congestion by flowgate ranked by average hourly shadow price in the RTBM for the last 12 months. DA values are also included.

• Table is included to show top ten most congested flowgates and any potential projects which may provide mitigation

to the congestion. 42

M.3. Regional Control Performance

The SPP BA is not subject to CPS, but is subject to BAAL. CPS is reported here for informational purposes only. Measures the aggregate performance to the NERC CPS (Control Performance Standards) for SPP. This indicator is set based on the NERC real time control performance standards (known as BAL-001 – Real Power Balancing Control Performance and BAL-002 – Disturbance Control Performance).

• CPS1 requires compliance for 100% of the periods measured within the month.

•

BAAL - each Balancing Authority shall operate such that its clock-minute average of reportingACE does not exceed for more than 30 consecutive clock-minutes its clock-minuteBalancing Authority ACE Limit (BAAL)

Market Performance Indicators This sub-group of indicators provides a view of the effectiveness of the market in the context of answering the following questions:

• What was the average wholesale price paid in the region and what was its volatility? (see Price)

• How much Revenue Neutrality Uplift was generated during the month? (see Uplift)

• What was the level of available generation offered to the market and EIS related energy sales in the month? (see Market Liquidity)

M.4.1.M.4.2.M.4.3.

Price •

Shows the prices and volatility for both the DAMKT and RTBM for each market participant with load within the footprint. Also provides an SPP-wide average price for the period reported. Volatility (measured as the coefficient of variation, which is average divided by the standard deviation) is shown for each market participant as well as SPP as a whole. A higher volatility indicates more variability in prices.

• SPP-wide monthly average LMP and the Gas Cost at the Panhandle Eastern Pipeline hub.

M.4.4. RT-DA Price Deviation

• The Absolute Difference is the daily average of the absolute values of the hourly difference between Day-AheadMarket LMPs and Real-Time Market LMPs

• The Average Difference is the daily average of the hourly difference between Day-Ahead Market LMPs and Real-TimeMarket LMPs

• The Average LMP %Difference is the Absolute Difference divided by the average Day-Ahead LMP.𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴 𝐷𝐷𝐷𝐷𝐷𝐷𝐷𝐷𝐴𝐴𝐴𝐴𝐴𝐴𝐷𝐷𝐷𝐷𝐴𝐴 = (� 𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐷𝐷𝐴𝐴𝑎𝑎𝐴𝐴ℎ𝐴𝐴𝐴𝐴𝑒𝑒 𝐿𝐿𝐿𝐿𝐿𝐿𝑝𝑝𝑝𝑝𝑝𝑝 𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑝𝑝𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠 − 𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝑎𝑎𝐴𝐴𝐴𝐴𝑙𝑙𝑇𝑇𝐷𝐷𝑇𝑇𝐴𝐴 𝐿𝐿𝐿𝐿𝐿𝐿𝑝𝑝𝑝𝑝𝑝𝑝 𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑝𝑝𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠

𝐷𝐷𝑠𝑠𝐷𝐷)

𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝑙𝑙𝐴𝐴𝐴𝐴𝐴𝐴 𝐷𝐷𝐷𝐷𝐷𝐷𝐷𝐷𝐴𝐴𝐴𝐴𝐴𝐴𝐷𝐷𝐷𝐷𝐴𝐴 = (� |𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐷𝐷𝐴𝐴𝑎𝑎𝐴𝐴ℎ𝐴𝐴𝐴𝐴𝑒𝑒 𝐿𝐿𝐿𝐿𝐿𝐿𝑝𝑝𝑝𝑝𝑝𝑝 𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑝𝑝𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠 − 𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝑎𝑎𝐴𝐴𝐴𝐴𝑙𝑙𝑇𝑇𝐷𝐷𝑇𝑇𝐴𝐴 𝐿𝐿𝐿𝐿𝐿𝐿𝑝𝑝𝑝𝑝𝑝𝑝 𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑝𝑝𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝐷𝐷𝑠𝑠𝐷𝐷

|)

𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴 𝐿𝐿𝐿𝐿𝐿𝐿 % 𝐷𝐷𝐷𝐷𝐷𝐷𝐷𝐷𝐴𝐴𝐴𝐴𝐴𝐴𝐷𝐷𝐷𝐷𝐴𝐴 = 𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝑙𝑙𝐴𝐴𝐴𝐴𝐴𝐴 𝐷𝐷𝐷𝐷𝐷𝐷𝐷𝐷𝐴𝐴𝐴𝐴𝐴𝐴𝐷𝐷𝐷𝐷𝐴𝐴

𝐴𝐴𝐴𝐴𝐴𝐴(∑ 𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐴𝐷𝐷𝐴𝐴𝑎𝑎𝐴𝐴ℎ𝐴𝐴𝐴𝐴𝑒𝑒 𝐿𝐿𝐿𝐿𝐿𝐿𝑝𝑝𝑝𝑝𝑝𝑝 𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑝𝑝𝑠𝑠𝑝𝑝𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝑠𝐷𝐷𝑠𝑠𝐷𝐷 )

M.5.1. Uplift

Tracks amount of RNU (Revenue Neutrality Uplift) charged or credited to market participants during the month, along with the category of uplift. RNU ensures settlement payments/receipts for each settlement interval equal zero.

• Positive RNU - SPP receives insufficient revenue and collects from market participants.

• Negative RNU - SPP receives excess revenue, which must be credited back to market participants.Tracks Make Whole Payments (MWP) for both the Day-Ahead Market and the RUC (Real-Time) with payments broken down by Fuel Type of the generation receiving the MWP.

43

M.5.2. MWP Distribution

• The All-in Price cost of each MW is broken down into different components associated with different product or costdistribution.

• The DA MWP and RUC MWP make up the MWP distribution per MWh paid out as component of all-in cost for eachMW of energy.

M.6. Virtual Activity

• The Cleared Virtual Profitability is the daily average of the hourly DA LMP minus the hourly averaged RT LMPmultiplied by the cleared virtual transactions from DA and all divided by the absolute value of the total cleared virtualtransactions from DA.

• The Monthly Market Index is the monthly average of the cleared virtual profitability.• Volume of Cleared MWh is the daily average of the total cleared virtual transactions in DA.

M.7.1. Excess Capacity

• Excess Capacity is calculated as the MW capacity remaining (on dispatchable resources) that is not being dispatchedfor energy or reserved for online operating reserves (Reg Up, Spin, Online Supplemental). This Excess Capacity iscalculated for each unit for every hour and that excess capacity is assigned to a “Commitment Source” that representswhere the unit’s commitment actually came from. Only excess capacity from the hour of the daily peak generationobligation (averaged by month) is considered. The final chart only includes those additional commitment changesmade by SPP outside of DAMKT or MP-initiated decisions.

• Excess Capacity = Effective Max – Dispatch MW – Cleared Reg Up – Cleared Spin – Cleared Online Supplemental

M.7.2. Source of Commitment

• Commitments are determined and separated into 5 different cases SELF, MANUAL, ID_RUC, DA_RUC and DAMKT andare taken from the Current Operating Plan table.

• Depending on the process the commitment is made, they are categorized into groups.• For the purpose of the Metrics on the dashboard, the DA_RUC, DAMKT and DBDA commitments are considered DA

commitments fulfilling Real-Time obligation.

44

Financial Metrics This group of metrics provides a view of the organization’s overall financial situation in terms of both the operating costs and settlement functions carried out.

F.1. Admin Fee Performance Measures actual costs incurred by SPP on an annual basis and compares this to the approved Admin Fee and Budgeted Net Revenue Requirement (NRR).

F.2. Credit Metric measures the timeliness of the financial settlements for both transmission billing and market billing and provides a proxy for the strength of the organization’s cash flow.

F.3. Settlement Disputes

Measures the number and value of disputes made with regard to the financial settlements of the markets. The objective in this area is twofold: (1) minimize the time to clear disputes; and (2) minimize the total value of dollars in dispute.

• The average dispute amount granted in the month.

• The number of disputes active at the end of the month, as well as the average days outstanding for those disputes iscalculated. In addition, the number of resettlements during the month is tracked.

F.4. Human Resources

Measures turnover rates, as well as the number of position vacancies, for each quarter.

• Turnover rates, on a quarterly basis, as well as annualized.• Percentage of positions vacant on a quarterly basis.

45

Performance Metrics The metrics in this group focus on NERC Compliance, System Availability, Studies and the Strategic Plan.

P.2.1. IT System Availability Measures availability of SPP IT Systems.

P.2.2. Operational System Availability

• STLF – This includes a count of days that the STLF Error has exceeded 1% for more than 2% of the RTBM study intervals.

• DAMKT - This portion of the graph includes a count of days that the DAMKT posted past the deadline. • DARUC – This portion of the graph includes a count of days that DARUC failed to solve within 3 hours and 15 minutes

of DAMKT Posting. Note: This was changed January 2018 due to changes to DAMKT/DARUC timelines. • SE/RTLODF - This portion of the graph shows a count of days that the SE solution failed to solve every 4 seconds.

The metric indicator will be green if the failure counts falls between 0 & 7. The metric indicator will fall in the yellow category if the count falls between 8 & 14.

P.2.3. System Availability

• MTLF - Percentage of time that the Mid-Term Load Forecast Error (Actual Load vs MTLF) was within 5% for each of the three previous months as well as from the previous 12 months. Note: Data is now pulled from the last 12 months instead of from go live. It is a large amount of data and processing time to continue to retrieve some of these metrics back to go live. That information is contained in previous reports.

• STLF - Percentage of time the Short-Term Load Forecast error (Actual Load vs STLF) was within 1% for each of the three previous months as well as from the previous 12 months.

• Day Ahead Market – This portion of the graph shows the percentage of time that the DAMKT posted on time for each of the three previous months as well as from the previous 12 months.

• Intra Day RUC – This portion of the graph shows the percentage of time that IDRUC studies successfully ran every four hours for each of the three previous months as well from the previous 12 months.

• State Estimator – This portion of the graph shows the percentage of time that there was a SE solution every four seconds for each of the three previous months as well as from the previous 12 months.

• Real Time Balancing Market – This portion of the graph shows the percentage of time that RTBM solved and approved successfully every five minutes for each of the three previous months as well as from the previous 12 months.

P.3. Transmission Service Studies • Dashboard showing status of transmission service studies.

P.4. Generation Interconnection Studies Tracks status of Generation Interconnection Studies by MW, as well as upcoming commercial operation dates for Generation Interconnection Agreements.

P.5. Strategic Plan Tracks status of Strategic Plan initiatives and assignments.

46

FERC Prehearing Conference begins at 11 AM Eastern Time (Order Scheduling Prehearing Conference issued on July 8, 2019)

07/18/2019

ER18-2358

FERC Initial Decision is due (Order Establishing Procedural Schedule issued on August 30, 2018; Order of Chief Judge Extending Initial Decision Deadline issued on June 18, 2019)

07/19/2019

ER18-99

FERC SPP's Ninth Informational Report due detailing SPP's and MISO's progress on resolving issues related to their implementation methodologies for Interface Bus Pricing, and analyzing whether the benefits of implementation of a day-ahead firm flow entitlement exchange process outweigh its costs, until such issues are resolved (Order Conditionally Accepting in Part and Rejecting in Part Revisions to Joint Operating Agreement issued on January 22, 2015)

07/22/2019

ER13-1864

FERC Comments due in response to the Notice of Proposed Rulemaking amending the Commission's regulations to incorporate by reference Version 003.2 of certain Standards for Business Practices and Communication Protocols for Public Utilities adopted by the Wholesale Electric Quadrant of the North American Energy Standards Board (Notice of Proposed Rulemaking issued on May 16, 2019)

07/23/2019

RM05-5

FERC Prehearing Conference begins at 2 PM Eastern Time (Order Scheduling Prehearing Conference issued on June 28, 2019)

07/24/2019

ER15-2028

FERC Prehearing Conference begins at 10 AM Eastern Time (Order Scheduling Prehearing Conference issued on June 28, 2019)

07/24/2019

ER15-2115

FERCSPP's response to letter requesting additional information is due (Letter issued on June 25, 2019)

07/25/2019

ER19-1680

FERC SPP to submit a compliance filing removing the exit fee requirement for non-transmission owners (Order on Complaint issued on April 18, 2019; Notice of Extension of Time issued on May 1, 2019)

08/01/2019

EL19-11

7/16/2019 9:37:53 AM Page 1 of 2

Regulatory Outlook

47

State of Kansas Parties to file comments on the possible methods or approaches whereby Kansas utilities and/or SPP can provide back-cast or historical evaluation of future cost/benefit studies (Order on General Investigation as to Whether Annual or Periodic Reporting by SPP, and Kansas Utilities that Participate in SPP, is in the Public Interest issued on March 19, 2019; Order Granting Joint Motion for Extension of Time issued on May 14, 2019)

08/13/2019

17-SPPE-117-GIE

State of Kansas SPP to file the Kansas-specific portion, by Kansas member utility if possible, for each of the most recently created SPP reports that evaluate the cost/benefit of Kansas utility participation in SPP (Order on General Investigation as to Whether Annual or Periodic Reporting by SPP, and Kansas Utilities that Participate in SPP, is in the Public Interest issued on March 19, 2019; Order Granting Joint Motion for Extension of Time issued on May 14, 2019)

08/13/2019

17-SPPE-117-GIE

FERC Comments due in response to Notice of Proposed Rulemaking proposing to approve Reliability Standard TPL-001-5 (Transmission System Planning Performance Requirements) (Notice of Proposed Rulemaking issued on June 20, 2019)

08/26/2019

RM19-10

FERCSPP to file its Annual Budget in FERC Docket Nos. ER04-48, ER08-1338, RT04-1

12/16/2019

ER08-1338

FERC Compliance filing to implement Tariff changes regarding quick-start pricing practices is due (Order on Paper Hearing issued on June 12, 2019)

12/31/2019

EL18-35

7/16/2019 9:37:53 AM Page 2 of 2

Regulatory Outlook

48

SPP Tariff/Governing Document Revisions Docket Number Short Description Summary ER16-1341

18-1005U.S. Court of Appeals

Petition of Southwest Power Pool, Inc. for Tariff Waiver Concerning the Crediting Process in Attachment Z2

Xcel Energy Services Inc. (“Xcel Energy”) v. Federal Energy Regulatory Commission (“FERC”): Petition for Review of Orders Issued in Docket No. ER16-1341 Regarding SPP’s Petition for Tariff Waiver Concerning the Implementation of the Revenue Crediting Process in Attachment Z2

On April 1, 2019, SPP filed a Request for Rehearing and Motion for Clarification of the Order on Remand.

On April 1, 2019, Flat Ridge 2 Wind Energy LLC filed a Request for Rehearing of the Order on Remand.

April 1, 2019, Oklahoma Gas and Electric Company filed a Request for Rehearing of the Order on Remand.

On May 1, 2019, FERC issued an Order Granting Rehearing for Further Consideration of the order issued on February 28, 2019.

On June 28, 2019, SPP filed a Motion for Stay of Refund Condition, to Hold Proceedings in Abeyance, and for Initiation of Settlement Procedures.

On June 28, 2019, SPP submitted its Compliance Report Describing Proposed Plan for Implementing Refunds of Historical Amounts Billed under Attachment Z2 and Request for Privileged Treatment.

ER18-939

EL16-91

Submission of Membership Agreement Revisions to Implement Refund Obligations for Non-Public Utility SPP Transmission Owners Consistent with Commission Orders in Docket Nos. EL16-91-000 and EL18-19-000

Section 206 Proceeding to Examine SPP's Open Access Transmission Tariff (“Tariff”) and Absence of Refund Commitment for Non-Public Utility Transmission Owners to Refund Revenues that they May Receive Associated with Service Provided due to their Status as Transmission-Owning Regional Transmission Organization

Commission action is pending on SPP’s compliance filing in Docket No. ER18-939.

49

SPP Tariff/Governing Document Revisions Docket Number Short Description Summary EL18-19

(“RTO”) Members in the Same Manner Public Utility Transmission Owners Could be Required to Provide Refunds of Such Revenues Section 206 Proceeding to Examine SPP's Membership Agreement (and Other Jurisdictional Documents) and Absence of Refund Commitment for Non-Public Utility Transmission Owners to Refund Revenues that they May Receive Associated with Service Provided due to their Status as Transmission-Owning RTO Members in the Same Manner Public Utility Transmission Owners Could be Required to Provide Refunds of Such Revenues

ER18-2318 Submission of Tariff Revisions to Comply with Order No. 844 (Revision Request 310)

On April 22, 2019, SPP submitted its compliance filing in response to the order issued on March 21, 2019. On July 11, 2019, FERC issued an order accepting SPP's compliance filing submitted on April 22, 2019. An effective date of January 1, 2019 was granted.

ER19-356 Submission of Tariff Revisions to Require that All Variable Energy Resources ("VER") Register as and Convert to Dispatchable Variable Energy Resources ("DVER") (Revision Request 272)

On April 12, 2019, FERC issued an order conditionally accepting SPP's revisions to Attachment AE of the Tariff to require that all VERs register and convert to DVERs by the later of January 1, 2021, or the 10-year anniversary of the Resource's original Commercial Operation Date, to be effective January 16, 2019, subject to a compliance filing. On May 13, 2019, SPP submitted its compliance filing in response to the order issued on April 12, 2019.

50

SPP Tariff/Governing Document Revisions Docket Number Short Description Summary

On June 26, 2019, FERC issued an order accepting SPP's compliance filing in response to the order issued on April 12, 2019. An effective date of January 16, 2019 was granted.

ER19-460 Submission of Order No. 841 Compliance Filing to Incorporate Electric Storage Resources (Revision Request 323)

On April 1, 2019, FERC issued a letter requesting additional information in order to process the filing. SPP’s response is due on May 1, 2019. On May 1, 2019, SPP filed its response to the letter requesting additional information issued on April 1, 2019.

ER19-1579 Submission of Tariff Revisions to the Generator Interconnection Procedures to Implement a Three-Stage Study Process (Revision Request 335)

On April 16, 2019, SPP submitted tariff revisions to modify its Generator Interconnection Procedures to implement a three-stage study process. On June 28, 2019, FERC issued an order accepting SPP's tariff revisions. An effective date of July 1, 2019 was granted.

ER19-1637 Submission of Tariff Revisions to Allow Dispatchable Variable Energy Resources ("DVERs") to Utilize Control Statuses to Indicate the Resource is not Currently Capable of Following a Dispatch Instruction (Revision Request 288)

On April 22, 2019, SPP submitted revisions to Section 4.1.2.4 of Attachment AE of the Tariff to allow DVERs to utilize control statuses to indicate the Resource is not currently capable of following a Dispatch Instruction. SPP requested that the Commission issue an order by July 1, 2019 to allow SPP to build software changes to implement the proposed revisions with a target completion date in the second quarter of 2020. SPP requested an effective date of 12/31/9998 for the Tariff Records submitted in the filing and committed to submitting a filing with the Commission to specify a precise effective at a later time. On June 21, 2019, FERC issued an order accepting SPP's revisions to Section 4.1.2.4 of Attachment AE of the Tariff. The Commission directed SPP to submit a filing to inform the Commission of the effective date of the tariff provisions within 15 days of the effective date.

ER19-1898 Submission of Tariff Revisions to Enhance Multi-Configuration Resource ("MCR") Market Design (Revision Request 316)

On May 20, 2019, SPP submitted revisions to Attachment AE of the Tariff to enhance the current MCR market design with the addition of two Resource commitment parameters. SPP requested that the Commission issue an order by July 19, 2019 to allow SPP staff to develop, test, and move the proposed revisions into the production phase. SPP requested an effective date of 12/31/9998 for the Tariff Records submitted in the filing and committed to submitting a filing with the Commission to specify a precise effective date at a later time.

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SPP Tariff/Governing Document Revisions Docket Number Short Description Summary

On July 9, 2019, FERC issued an order accepting SPP’s tariff revisions. The Commission directed SPP to submit a filing to inform the Commission of the effective date of the tariff provisions within 15 days of the effective date.

ER19-1901 Submission of Tariff Revisions to Enhance the Minimum Daily Contingency Reserve Requirement Calculation (Revision Request 318)

On May 20, 2019, SPP submitted revisions to Attachment AE of the Tariff to enhance the current Minimum Daily Contingency Reserve Requirement to use Most Severe Single Contingency as the basis for the calculation. SPP requested that the Commission issue an order by July 19, 2019 to allow SPP staff to develop, test, and move the proposed revisions into the production phase. SPP requested an effective date of 12/31/9998 for the Tariff Records submitted in the filing and committed to submitting a filing with the Commission to specify a precise effective date at a later time. On July 11, 2019, FERC issued an order accepting SPP’s tariff revisions. The Commission directed SPP to submit a filing to inform the Commission of the effective date of the tariff provisions within 15 days of the effective date.

ER19-1954 Order Nos. 845 and 845-A Compliance Filing (Revision Request 353)

On May 22, 2019, SPP submitted its compliance filing in response to Order Nos. 845 and 845-A. On June 26, 2019, the American Wind Energy Association, et al. filed a Motion to Intervene and Comments. The parties stated they have several concerns regarding SPP's proposed Option to Build, Surplus Interconnection Service, Interim Interconnection Service, and SPP's technological change provision details.

ER19-2131 Submission of Tariff Revisions to Clarify that a Major Maintenance Cost Component Applies to Mitigated Transition State Offers (Revision Request 346)

On June 14, 2019, SPP submitted revisions to Section 3.3.1 of Attachment AF of the Tariff to clarify that a major maintenance cost component applies to mitigated Transition State Offers. An effective date of August 14, 2019 was requested. On June 20, 2019, the SPP Market Monitoring Unit filed a Motion to Intervene.

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Other Filings of Interest Docket Number Short Description Summary ER13-1864 Joint Operating Agreement

("JOA") between SPP and the Midcontinent Independent System Operator, Inc. ("MISO") to Include Market-to-Market ("M2M") Terms and Conditions (SPP Rate Schedule FERC No. 9)

On January 22, 2019, SPP filed its eighth informational report regarding Interface Bus Pricing and a Day-Ahead Firm Flow Entitlement exchange process concerning market-to-market coordination with the Midcontinent Independent System Operator, Inc. SPP’s next informational report is due on July 22, 2019.

EL17-21 Kansas Electric Power Cooperative, Inc.'s ("KEPCo") Complaint Against SPP Concerning Direct Cost Assignment in Connection with the Attachment Z2 Revenue Crediting Process

Commission action is pending on the requests for rehearing of the order issued on November 6, 2017. On June 28, 2019, SPP filed a Motion for Stay of Refund Condition, to Hold Proceedings in Abeyance, and for Initiation of Settlement Procedures.

EL17-89 American Electric Power Service Corporation ("AEP") Complaint Against the Midcontinent Independent System Operator, Inc. ("MISO") and SPP Concerning Assessment of Duplicative Congestion Charges Associated with Southwestern Electric Power Company ("SWEPCO") Loads that are Pseudo-Tired from MISO to SPP

Commission action is pending on the Complaint.

EL18-9 Xcel Energy Services Inc.'s ("Xcel Energy"), on behalf of Southwestern Public Service Company ("SPS"), Complaint Against SPP Concerning the Attachment Z2 Revenue Crediting Process

Commission action is pending on the rehearing request of the order issued on March 6, 2018. On June 28, 2019, SPP filed a Motion for Stay of Refund Condition, to Hold Proceedings in Abeyance, and for Initiation of Settlement Procedures.

EL18-26 EDF Renewable Energy, Inc.'s ("EDF") Complaint Against the

Commission action is pending on the Complaint.

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Other Filings of Interest Docket Number Short Description Summary

Midcontinent Independent System Operator, Inc. (“MISO”), Southwest Power Pool, Inc. (“SPP”), and PJM Interconnection, L.L.C. (“PJM”) (collectively, the “RTOs”) Regarding Affected System Coordination

EL18-35 Order Instituting Section 206 Proceeding and Commencing Paper Hearing Procedures Regarding Pricing of Quick-Start Resources

On June 12, 2019, FERC issued an Order on Paper Hearing, directing SPP to revise its Tariff to implement the following changes: 1) Modify its real-time energy market clearing process to execute the cost-minimizing dispatch solution followed by a pricing run, remove its screening run, and remove the option for enhanced energy offers that incorporate amortized commitment costs in the incremental cost curves of quick-start resources used during the dispatch run; 2) Modify its pricing logic to allow the commitment costs of quick-start resources (including all such resources even if they have not registered as quick-start resources) to be reflected in prices, in both the day-ahead and real-time markets; 3) Include in the definition of quick-start resources a requirement that those resources have a minimum run time of one hour or less; 4) Allow for relaxation of all quick-start resources’ economic minimum operating limits by up to 100 percent, such that the resources are considered dispatchable from zero to their economic maximum operating limit for the purpose of setting prices; 5) Apply quick-start pricing treatment to both registered and unregistered quick-start resources; and 6) Include its quick-start pricing practices in its Tariff. SPP's compliance filing is due on December 31, 2019.

EL18-194 Nebraska Public Power District ("NPPD") Complaint Against Tri-State Generation and Transmission Association, Inc. ("Tri-State") and Southwest Power Pool, Inc. ("SPP") Concerning Inclusion of Costs in Tri-State's Annual Transmission Revenue Requirement ("ATRR") for Facilities Not

Commission action is pending on the request for rehearing of the order issued on December 20, 2018.

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Physically Connected to the SPP Transmission System

EL19-11 Complaint of the American Wind Energy Association ("AWEA") and the Wind Coalition (collectively, "Complainants") Regarding SPP's Financial Obligations of Withdrawing Members

On April 18, 2019, FERC issued an Order on Complaint, finding that SPP's membership exit fee, as applied to non-transmission owners, is unjust and unreasonable, and directing SPP to eliminate the membership exit fee for non-transmission owners.

SPP was directed to submit a compliance filing to remove the exit fee requirement for non-transmission owners.

On April 25, 2019, SPP filed a Motion for Extension of Time and Request for Expedited Ruling. SPP requested an extension to August 1, 2019 for submitting the compliance filing required by the order issued on April 18, 2019.

On May 1, 2019, FERC issued a Notice of Extension of Time, extending the due date for SPP to submit its compliance filing to August 1, 2019.

On May 20, 2019, SPP filed a Motion for Stay and Expedited Action, requesting that the Commission stay the effect of the April 18, 2019 order in this proceeding until such time as the Commission issues an order accepting a replacement exit fee formula.

On May 20, 2019, SPP filed a Request for Rehearing and Clarification of the Order on Complaint issued on April 18, 2019.

On May 20, 2019, the SPP Load Serving Entities filed a Request for Rehearing of the Order on Complaint issued on April 18, 2019.

On June 17, 2019, FERC issued an Order Granting Rehearings for Further Consideration of the order issued on April 18, 2019.

On July 2, 2019, FERC issued an order denying SPP's requested stay of the April 18, 2019 Order on Complaint and establishing a refund effective date of April 5, 2019.

On July 10, 2019, SPP Generation Market Participants filed an answer in response to the requests for rehearing.

EL19-62 Complaint of City Utilities of Springfield, Missouri ("CUS")

On April 12, 2019, CUS filed a Complaint alleging SPP's Highway/Byway cost allocation methodology produces an unintended consequence for CUS' pricing Zone under the Tariff. CUS requested that the

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Regarding Highway/Byway Cost Allocation Methodology

Commission enforce the adjustment mechanism in Section III.D.4 of Attachment J of the Tariff to remedy the unintended consequences produced in CUS' Zone between June 19, 2010 and the refund effective date established in this proceeding. CUS stated the Commission should require SPP to revise Section III.D.4 of Attachment J to automatically protect the benefit-deficient Zones from unintended consequences. On May 17, 2019, SPP filed its answer to the Complaint. On May 17, 2019, Xcel Energy Services Inc. (“Xcel Energy”) filed a Motion to Intervene and Comments in Opposition to Complaint. On May 17, 2019, Missouri Joint Municipal Electric Utility Commission filed Comments in Support of Complaint. On May 17, 2019, Sunflower Electric Power Corporation and Mid-Kansas Electric Company, Inc. filed Comments, requesting that if the Commission determines that a remedy is warranted for CUS’s Complaint, the Commission apply its cost causation principles and consider the impact on customers who would be affected by the reallocation, not only the impact on CUS. On May 17, 2019, Omaha Public Power District filed a Motion to Intervene and Comments. On May 17, 2019, the Missouri Public Service Commission filed Comments, requesting that FERC order SPP to commence a third Regional Cost Allocation Review. On June 3, 2019, CUS filed an answer in response to SPP's answer and Xcel Energy's Comments filed on May 17, 2019. On July 11, 2019, SPP filed an answer to certain answers and comments filed in this proceeding.

EL19-75 Complaint to Enforce Attachment Z2 of EDF Renewables, Inc., Enel Green Power North America, Inc., NextEra Energy Resources, LLC and Southern Power Company ("Complainants")

On May 9, 2019, Complainants filed a Complaint against SPP to adhere to Attachment Z2 of the Tariff. On June 12, 2019, City of Coffeyville, Kansas and City Utilities of Springfield, Missouri filed a Joint Motion to Intervene and Comments, stating that the Commission should dismiss the Complaint. On June 13, 2019, SPP filed an Answer to Complaint. On June 13, 2019, Golden Spread Electric Cooperative, Inc. filed a Motion to Dismiss Complaint.

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On June 13, 2019, Kansas Electric Power Cooperative, Inc. filed a limited protest in opposition to the Complaint. On June 13, 2019, Oklahoma Gas and Electric Company filed an answer in support of the Complaint. On June 13, 2019, Xcel Energy Services Inc. filed a Motion for Leave to Intervene and Protest of the Complaint. On June 13, 2019, Western Farmers Electric Cooperative filed Comments. On June 21, 2019, Dempsey Ridge Wind Farm, LLC filed a Motion to Intervene and Comments in support of the Complaint. On June 28, 2019, SPP filed a Motion for Stay of Refund Condition, to Hold Proceedings in Abeyance, and for Initiation of Settlement Procedures.

EL19-77 Oklahoma Gas and Electric Company's ("OG&E") Complaint Regarding Revenue Credits under the Sponsored Upgrade Agreement dated December 1, 2008

On May 24, 2019, OG&E filed a Complaint regarding SPP's contractual commitment to OG&E, under the Sponsored Upgrade Agreement dated December 1, 2008, to provide revenue credits for use of certain transmission facilities, which OG&E and its retail ratepayers funded and built at cost of over $200 million in reliance on that commitment in order to further the Commission's policy of encouraging construction of transmission capacity for the development of renewable resources, during a historical period of nearly six years through September, 2015. The Complaint also seeks enforcement of the provisions of SPP's Tariff, including Attachment Z2, that confirm OG&E's right to recovery and retention of revenue credits. The Complaint seeks 1) a ruling that SPP's forced unwinding of the revenue credit payments to OG&E would violate the provisions of the Sponsored Upgrade Agreement, improperly denying OG&E revenue credits for use of OG&E's transmission facilities during the historical period under the Agreement, and would likewise violate the terms of Attachment Z2 of SPP's Tariff entitling OG&E to such credits; and 2) an order directing that SPP not seek to refund or unwind those payments. On July 3, 2019, SPP filed an Answer to Complaint. On July 3, 2019, Golden Spread Electric Cooperative, Inc. filed a Motion to Dismiss Complaint. On July 3, 2019, Western Farmers Electric Cooperative filed Comments in support of the Complaint. On July 3, 2019, Xcel Energy Services Inc. filed a Motion to Intervene and Protest of the Complaint.

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On July 3, 2019, Kansas Electric Power Cooperative, Inc. filed a Protest in opposition to the Complaint. On June 28, 2019, SPP filed a Motion for Stay of Refund Condition, to Hold Proceedings in Abeyance, and for Initiation of Settlement Procedures.

ER19-477 Petition for Tariff Waiver of the 365-Day Limitation Period for Modifications to Settlement Statements Set Forth in Attachment AE, Section 10.1(3) to Ensure that Market-to-Market ("M2M") Settlements Involving SPP and the Midcontinent Independent System Operator, Inc. ("MISO") are Accurate

Commission action is pending.

ER19-1896 ER19-1895

Submission of Revisions to the Joint Operating Agreement between SPP and the Midcontinent Independent System Operator, Inc. ("MISO") to Enhance the Coordinated System Plan Process Midcontinent Independent System Operator, Inc.'s ("MISO") Submission of Revisions to the Joint Operating Agreement between SPP and MISO to Enhance the Coordinated System Plan Process

On May 17, 2019, SPP and MISO submitted revisions to Article IX to the Joint Operating Agreement between SPP and MISO to implement substantive changes to the Coordinated System Plan process. An effective date of July 17, 2019 was requested. On June 7, 2019, American Wind Energy Association, Clean Grid Alliance and Advanced Power Alliance filed a Motion to Intervene and Comments. On June 7, 2019, American Electric Power Service Corporation filed Supporting Comments. On June 7, 2019, the Organization of MISO States, Inc. filed a Notice of Intervention and Comments. On June 24, 2019, MISO filed an answer in response to comments filed in this proceeding.

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State Cases Docket Number Short Description Summary Kansas 17-SPPE-117-GIE 19-SPPE-384-CPL

In the Matter of a General Investigation for the Purpose of Investigating Whether Annual or Periodic Cost/Benefit Reporting by the SPP and Kansas Electric Utilities that Participate in SPP is in the Public Interest

On May 6, 2019, SPP, et al. filed a Joint Motion for Extension of Time requesting an additional 60 days to file responses to the order issued on March 19, 2019. On May 14, 2019, the Commission issued an Order Granting Joint Motion for Extension of Time, extending the date to August 13, 2019 to comply with the filings required by the order issued on March 19, 2019.

Texas 46901 --------------------------------------- United States District Court for the Northern District of Texas, Amarillo Division 2:17-CV-00043-J --------------------------------------- 181 District Court in and for Potter County, Texas 106111-B --------------------------------------- Third District of Texas, Court of Appeals

Joint Petition of Southwestern Public Service Company ("SPS") and Southwest Power Pool, Inc. ("SPP") for Declaratory Order Seeking Declaration as to Whether SPP May Designate Entities Other Than the Incumbent Texas Utility to Construct and Own Regionally-Funded Transmission Facilities Located in Texas but Providing Service Outside the Electric Reliability Council of Texas ("ERCOT") -------------------------------------- Southwestern Public Service Company (“SPS”), Plaintiff vs. Southwest Power Pool, Inc. (“SPP”), Defendant -------------------------------------- Southwestern Public Service Company (“SPS”), Plaintiff vs. Southwest Power Pool, Inc. (“SPP”), Defendant -------------------------------------- Entergy Texas, Inc.; Southwestern Public Service

The following activity occurred during the first quarter in Case No. 03-18-00666-CV: On June 21, 2019, Appellants filed a Motion to Dismiss for Mootness. On June 27, 2019, the PUCT filed its response to the Motion to Dismiss for Mootness. The PUCT stated it is unopposed to the relief requested in the motion. On June 28, 2019, Southwest Transmission, LLC, GridLiance High Plains LLC, and GridLiance Heartland LLC filed their Response in Opposition to Appellants' Motion to Dismiss, requesting that the court deny the motion.

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State Cases Docket Number Short Description Summary 03-18-00666-CV

Company; and Texas Industrial Energy Consumers (“Appellants”) v. Public Utility Commission of Texas (“PUCT”)

Texas 47898

Petition of East Texas Electric Cooperative, Inc. ("ETEC") to Transfer 35 MW of Load to the Electric Reliability Council of Texas, Inc. ("ERCOT")

On May 29, 2019, ETEC and the Public Utility Commission of Texas staff filed a Stipulation and Settlement Agreement. On May 29, 2019, Adrian Narvaez and Alicia Maloy filed Testimony in Support of Stipulation on behalf of the Public Utility Commission of Texas.

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Date Event Location

04/03/2019 –

04/04/2019

IRC RLC Congressional briefings and meetings with Members of

Congress and their staffs Washington, DC

05/08/2019 –

05/09/2019 Arkansas Chamber of Commerce meeting Washington, DC

05/21/2019 –

05/22/2019

IRC Joint Board Meeting and meetings with Members of Congress and

their staffs Washington, DC

06/04/2019 –

06/07/2019 Meetings with Members of Congress and their staffs Washington, DC

06/10/2019 –

06/13/2019 Western Governors Association Conference Vail, CO

06/13/2019 –

06/16/2019 The Energy Conference Biloxi, MS

06/25/2019 Meeting with the Colorado Governor Denver, CO

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CORPORATE METRICS metrics 2q2019.pdf · TMP270_23432 Eastern Oklahoma; TMP127_23359 Western...

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Transcript of CORPORATE METRICS metrics 2q2019.pdf · TMP270_23432 Eastern Oklahoma; TMP127_23359 Western...