pjm regional transmission expansion planning (rtep) … › static-assets › documents › ...dec...

PJM©2016

PJM Regional Transmission Expansion Planning

(RTEP) Process

IPSAC

December 9, 2016

PJM©2016 2

Links for Various Information related to PJM Planning

• Transmission Expansion Advisory Committee (TEAC)

• http://www.pjm.com/committees-and-groups/committees/teac.aspx

• Interregional Planning

• http://www.pjm.com/planning/interregional-planning.aspx

• Generation Deactivation

• http://www.pjm.com/planning/generation-deactivation.aspx

• Market Efficiency Latest Update

• http://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-

market-efficiency-update.ashx

• PJM RTEP Window # 1 Update (May 9, 2016 IPSAC)

• http://www.pjm.com/~/media/committees-groups/stakeholder-

meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashx

http://www.pjm.com/committees-and-groups/committees/teac.aspxhttp://www.pjm.com/committees-and-groups/committees/teac.aspxhttp://www.pjm.com/committees-and-groups/committees/teac.aspxhttp://www.pjm.com/committees-and-groups/committees/teac.aspxhttp://www.pjm.com/committees-and-groups/committees/teac.aspxhttp://www.pjm.com/committees-and-groups/committees/teac.aspxhttp://www.pjm.com/planning/interregional-planning.aspxhttp://www.pjm.com/planning/interregional-planning.aspxhttp://www.pjm.com/planning/interregional-planning.aspxhttp://www.pjm.com/planning/interregional-planning.aspxhttp://www.pjm.com/planning/generation-deactivation.aspxhttp://www.pjm.com/planning/generation-deactivation.aspxhttp://www.pjm.com/planning/generation-deactivation.aspxhttp://www.pjm.com/planning/generation-deactivation.aspxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/committees/teac/20161103/20161103-market-efficiency-update.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashxhttp://www.pjm.com/~/media/committees-groups/stakeholder-meetings/ipsac/20160509/20160509-item-02-pjm-rtep-process.ashx

PJM©2016

PJM RTEP Planning Cycles

PJM©2016 4

System Expansion Drivers for RTEP

PJM©2016 5

12-Month and 24-Month Reliability Planning Cycle

PJM©2016 6

12-Month and 24-Month Market Efficiency Cycle

PJM©2016 7

2016-2017 Market Efficiency Window Update

PJM©2016 8

2016-2017 Market Efficiency Cycle Timeline

Item Schedule

Long Term Proposal Window Nov 1, 2016 – Feb 22, 2017

Analysis of Proposed Solutions March 2017 - November 2017

Determination of Final Projects

December 2017

PJM©2016 9

Market Efficiency Update

• Market Efficiency cases were posted on 11/01/2016

– PROMOD cases, and supporting documentation were posted on Market Efficiency

Web page

• http://www.pjm.com/planning/rtep-development/market-efficiency.aspx

• Proposal window opened on November 1, 2016

• Proposal window will close on February 22, 2017

• Market Efficiency Questions

– Send to the RTEP e-mail distribution ([email protected]) with “Market Efficiency” in

the subject line header

http://www.pjm.com/planning/rtep-development/market-efficiency.aspxhttp://www.pjm.com/planning/rtep-development/market-efficiency.aspxhttp://www.pjm.com/planning/rtep-development/market-efficiency.aspxhttp://www.pjm.com/planning/rtep-development/market-efficiency.aspxhttp://www.pjm.com/planning/rtep-development/market-efficiency.aspxmailto:[email protected]

PJM©2016 10

Posted Files

• 2016/17 Market Efficiency Base Case

• Problem Statement and Recommended Congestion Drivers

• Base Congestion results

• Additional Files*

• Market Efficiency Benefit/Cost Evaluation Spreadsheet and Example

• Setup Instructions

* the ARR modeling files to be posted in the following days

PJM©2016 11

List of Long-Term Window Issues

Facilities Recommended for Proposal2021 Input Assumptions

with 2021 Topology2024 Input Assumptions

with 2021 Topology

Facility Name AREA TYPEFrequency

(Hours)

Market Congestion ($ Millions)

Frequency (Hours)

Market Congestion ($ Millions)

Notes/Potential Upgrade

Conastone to Graceton 230 kV BGE LINE 896 $55.1 931 $61.6

Graceton to Bagley 230 kV BGE LINE 1,131 $30.0 1,420 $43.5

Susqeuhanna to Harwood 230 kV PPL LINE 173 $3.7 193 $5.1

Bosserman to Olive 138 kV AEP LINE 5 $0.2 56 $1.7 Interregional Constraint

PJM©2016 12

Map of Long-Term Window Issues

PJM©2016 13

Susquehanna to Harwood (near NY Border)

• Area: PPL

• Voltage: 230 kV

• Market Congestion

– 2017 ($mill): 3.7

– 2021 ($mill): 5.1

PJM©2016 14

Generation Deactivation Notification

Update

PJM©2016 15

Generation Deactivation

PJM©2016 16

Deactivation Status (2016)

Unit(s)Transmission

Zone

Requested

Deactivation DatePJM Reliability Status

Pottstown LF (Moser) PECO 1/15/2016Reliability analysis complete. No impacts identified. Unit deactivated on

12/7/2015.

Perrvman 2 BGE 1/1/2016

Reliability analysis complete. One impact identified, resolved via an existing

baseline upgrade, which is expected to be completed by June 2017. Interim

operating measure identified and can be utilized until baseline upgrade

complete. Unit expected to deactivate as scheduled. Unit deactivated on

2/1/2016.

Fauquier County

LandfillDOM 2/29/2016

Reliability analysis complete. No impacts identified. 0 MW capacity; 2 MW

energy. Unit deactivated 1/31/2016

Avon Lake 7 ATSI 4/16/2016

Reliability analysis complete. Impacts identified, resolved via existing baseline

upgrades, which are not expected to be completed until 2018. Interim

operating measures identified and can be utilized until baseline upgrades

completed. Unit deactivated on 4/16/2016.

Dale 3 EKPC 4/16/2016

Reliability analysis complete. No impacts identified. Dale U3 requested, and

was granted, a compliance extension from Kentucky. Unit will now deactivate

on 4/16/16. Unit deactivated on 4/16/2016.

Dale 4 EKPC 4/16/2016

Reliability analysis complete. No impacts identified. Dale U4 requested, and

was granted, a compliance extension from Kentucky. Unit will now deactivate

on 4/16/16. Unit deactivated on 4/16/2016.

BL England Diesel(s)

{IC1, IC2, IC3, IC4}AE 5/31/2016

No reliability impacts - with request to transfer CIRs to Y1-001. On 01/15/2015

PJM received an updated deactivation notice from BL England stating diesel

units deactivation date moved out till May 31, 2016. Still will re-use diesel CIRs

for Y1-001. Unit deactivated on 5/31/2016.

PJM©2016 17

Deactivation Status (2016-17)

Unit(s)Transmission

Zone

Requested


Riverside 4 BGE 6/1/2016

Reliability analysis complete. No issues identified. On 4/17/2014 Riverside

submitted an updated deactivation notice with a new deactivation date of

6/1/2015. New reliability analysis complete. No issues identified. Gen owner

will keep unit operating until 6/1/2016. Unit deactivated on 6/1/2016.

Warren County

Landfill GeneratorJCPL 6/1/2016

Reliability analysis complete. No impacts identified. Unit deactivated on

6/1/2016.

Columbia Dam Hydro

(Columbia NJ)JCPL 11/18/2016

Reliability analysis complete. No impacts identified. Unit deactivated on

10/03/2016.

Rolling Hills (6 MW) ME 12/7/2016 Reliability analysis complete. No impacts identified.

Hudson Unit 2 (617.9

MW)PSE&G 6/1/2017 Reliability analysis underway.

Mercer Unit 1 (321


Mercer Unit 2 (320.3


Web link: http://www.pjm.com/~/media/planning/gen-retire/generator-deactivations.ashx

PJM©2016 18

Pending Deactivation Requests

Unit(s) Transmission ZoneRequested


Sewaren 1 PSEG11/1/2017

6/1/2018

PSEG re-use of Capacity Rights for a new generation project.

On 1/12/2016 an updated deactivation notice was provided

changing the deactivation date to 6/1/2018.


6/1/2018





6/1/2018





6/1/2018




Will County 4 ComEd5/31/2018

5/31/2020

Reliability analysis complete. Impacts identified and are expected

to be completed by May 2018. On 6/3/2016 an updated

deactivation notice was provided changing the deactivation date to

5/31/2020. New Reliability analysis complete. Impacts identified.

Upgrades expected to be completed by May 2020. Unit

expected to deactivate as scheduled.

Hopewell James

River CogenerationDOM 5/31/2017 Reliability analysis complete. No impacts identified.

Quad Cities

Nuclear

Generating Station

Unit 1

ComEd 6/1/2018 Reliability analysis complete. No impacts identified.

Quad Cities

Nuclear

Generating Station

Unit 2

ComEd 6/1/2018 Reliability analysis complete. No impacts identified.

PJM©2016 19

Pending Deactivation Requests

Unit(s) Transmission ZoneRequested


Bay Shore 1 ATSI 10/1/2020

Reliability analysis complete. Impacts identified and will be

resolved by existing baseline upgrades that are scheduled to be

completed in 2019.

W H Sammis 1 ATSI 5/31/2020



completed in 2019.




completed in 2019.




completed in 2019.




completed in 2019.

Harrisburg 4 CT PPL 11/17/2016 Reliability analysis complete. No impacts identified.

Hudson 2 PSEG 6/1/2017



completed by May 2018. Interim operating measures identified

and unit expected to deactivate as scheduled.

Crane 1 BGE 6/1/2018 Reliability analysis underway.

Crane 2 BGE 6/1/2018 Reliability analysis underway.

Crane GT1 BGE 11/18/2018 Reliability analysis underway.

PJM©2016

2016 RTEP Proposal Window #2

Updates and Recommendations

PJM©2016 21

2016 RTEP Proposal Window 2

• Scope:

– Baseline N-1 (thermal and voltage)

– Generation Deliverability and Common Mode Outage

– N-1-1 (thermal and voltage)

– Load Deliverability (thermal and voltage)

• Window Opened: 6/29/2016

• Window Closed: 7/29/2016

– Proposal definitions, simulation data and planning cost estimate due

PJM©2016 22


• 140 total flowgates

Year/Voltage Test/kV Level* 100kV - 200kV

230kV 345kV 500kV 765kV Total

2021 Summer

N-1 Thermal 1 2 3 N-1 High Voltage 0 N-1 Low Voltage 0 N-1 Voltage Drop 0 Gen. Deliverability & Common Mode Outage

76 9 13 3 1 102

Load Deliv Thermal 0 Load Deliv Voltage 0 N-1-1 Thermal 10 10 N-1-1 Low Voltage 2 2 N-1-1 Voltage Drop 2 18 20 N-1-1 Voltage Collapse 0 Total 91 27 15 3 1 137

*xfmr voltage class is categorized based on low side kV

PJM©2016 23

2016 RTEP Proposal Window 2 Violation Locations

PJM©2016 24


• 137 Flowgates Identified, 71 Flowgates Recommended for

proposals ( Remaining flowgates related to Retired Generators)

• 87 Proposals Received from 13 Entities addressing 12 TO Zones

– 46 Greenfield

• Cost Range $5M - $136.9M

– 41 Transmission Owner Upgrades

• Cost Range $0.03M - $125M

PJM©2016 25

2016 RTEP Proposal Window 2 Proposals

• Based on the work done to date proposals fall into the following high level categories

1. Recommendation

2. Retirement/At Risk related (reliability violations will be re-evaluated pending the status of the retirement/at risk generation)

3. Technical evaluation is on-going as necessary to develop a recommended solution

4. Overlap with Winter and Light Load violations that are posted in Window 3.

5. Retool analysis required due to system change

6. Canceled due to tie facilities limited by non PJM Transmission Owning entities

PJM©2016 26

2016 RTEP Proposal Window 2 Proposal locations

PJM©2016 27

Window 2 Proposals Recommended for Board Approval

Upgrade

IDProject Description

Project Cost

(million dollars)

Transmission

Owner

In-Service

Date

b2778 Add 2nd 345/138 kV transformer at Chamberlin substation 3.8 ATSI 6/2/2021

b2777 Reconductor the enitre Dequine - Eugene 345 kV circuit #1 22.19 AEP 6/1/2021

b2776 Reconductor the entire Dequine - Meadow Lake 345 kV circuit #2 6.6 AEP 6/1/2021

b2767Construct a new 345 kV breaker string with three (3) 345 kV breakers at Homer City and

move the North autotransformer connection to this new breaker string6.6 PENELEC 6/1/2021

b2766.2Upgrade substation equipment at Peach Bottom 500 kV to increase facility rating to 2826

MVA normal and 3525 MVA emergency4.3 PECO 6/1/2021

b2766.1Upgrade substation equipment at Conastone 500 kV to increase facility rating to 2826

MVA normal and 3525 MVA emergency2.7 BGE 6/1/2021

b2765Upgrade bus conductor at Gardners 115 kV substation; Upgrade bus conductor and

adjust CT ratios at Carlisle Pike 115 kV0.1 ME 6/1/2021

b2764Upgrade Fairview 138 kV breaker risers and disconnect leads; Replace 500 CU breaker

risers and 556 ACSR disconnect leads with 795 ACSR0.03 APS 6/1/2021

b2763Replace the breaker risers and wavetrap at Bredinville 138 kV substation on the Cabrey

Junction 138 kV terminal0.97 APS 6/1/2021

b2762Perform a Sag Study of Nagel - West Kingsport 138 kV line to increase the thermal rating

of the line0.1 AEP 6/1/2021

b2761.2Perform a Sag Study of the Hazard – Wooten 161 kV line to increase the thermal rating

of the line0 AEP 6/1/2021

b2761.1 Replace the Hazard 161/138 kV transformer 2.3 AEP 6/1/2021

b2760Perform a Sag Study of the Saltville - Tazewell 138 kV line to increase the thermal rating

of the line0.1 AEP 6/1/2021

PJM©2016 28

Window 2 Proposals Recommended for Board Approval

PJM©2016 29

PenElec Transmission Zone (Project near NYISO Border)

• Common Mode Outage (FG# 1026):

• The Homer City 345/230 kV transformer “S” is overloaded for a line fault stuck breaker contingency loss of the Homer City – Armstrong 345 kV circuit and Homer City 345/230 kV transformer #N.

• Alternatives considered:

– 2016_2-3B ($36 M)

– 2016_2-8G ($6.6 M)

– 2016_2-9D ($23 M)

• Recommendation:

– Construct a new 345kV breaker string with three (3) 345kV breakers at Homer City and move the North autotransformer connection to this new breaker string. (2016_2-8G)

• Estimated Project Cost: $ 6.6 M

• Required IS Date: 6/1/2021

PJM©2016 31


• Status: 30 Day Portion closed 10/31/2016, Final details due 11/15/2016

• Scope:

– 2016 RTEP Winter Analysis

• Baseline N-1 (thermal and Voltage)

• Generation Deliverability and Common Mode Outage

• N-1-1 (thermal and Voltage)

• Load Deliverability (thermal and voltage)

– 2016 RTEP Light Load Analysis

• Baseline N-1 (thermal and voltage)

• Generation Deliverability and Common Mode Outage

– Short Circuit Analysis

PJM©2016 32


• Timeline

– Window Opened: 9/30/2016

– Window Closed: 10/31/2016

• Proposal definitions, simulation data and planning cost estimate due

– Detailed Cost due: 11/15/2016

• Additional 15 days to develop and provide detailed cost data

• See the window documentation for additional information

PJM©2016 35


• 25 flowgates recommended for proposals

• 29 Proposals Received from 7 entities addressing 6 Target

Zones

– 17 Greenfield

– 12 Transmission Owner Upgrade

• Next Steps

– Begin Analysis

PJM©2016 37

15 Year Analysis Result for 2016 RTEP

2016 RTEP 15 Year Analysis - Single Contingency Result

Fr Bus Fr Name To Bus To Name CKT KVs Areas 100% Year Comment

220963 CONASTON 220961 NWEST326 1 230/230 BGE 2031

219110 GLOUCSTR_2 219755 CUTHBERT_4 1 230/230 PSEG 2025

243217 05DEQUIN 243878 05MEADOW 2 345/345 AEP 2021 2016 RTEP Window 2

200675 26E.TWANDA 200924 26CANYON 1 230/230 PenElec 2021 2016 RTEP Window 2

213922 RICHMOND 214012 WANEETA3 1 230/230 PECO 2031

219110 GLOUCSTR_2 219125 CAMDEN 1 230/230 PSEG 2030

200064 PCHBTM1S 200004 CNASTONE 1 500/500 BGE/PECO 2030

243221 05EUGENE 243217 05DEQUIN 1 345/345 AEP 2021 2016 RTEP Window 2

248001 06DEARB1 243233 05TANNER Z1 345/345 206/205 2025

PJM©2016 39


2016 RTEP 15 Year Analysis - Tower Contingency Result

Fr Bus Fr Name To Bus To Name CKT KVs Areas 100% Year

314085 6REMNGCT 314110 6ELK RUN 1 230/230 Dominion 2029

206314 28RED OAKA 918790 AA1-098 TAP 1 230/230 JCPL 2027

918790 AA1-098 TAP 206305 28RAR RVR 1 230/230 JCPL 2027

314110 6ELK RUN 314037 6GAINSVL 1 230/230 Dominion 2030

314067 6OCCOQUN 314068 6OX 1 230/230 Dominion 2030

PJM©2016 42

PenElec Transmission Zone Short Circuit:

• The Warren 115kV breakers are

overstressed.

Immediate Need:

• Due to the immediate need, the

timing required for an RTEP proposal

window is infeasible. As a result, the

local Transmission Owner will be the

Designated Entity.

Alternatives Considered:

• Due to the immediate need of the

project no alternatives were

considered

Proposed Solution:

• Replace the Warren 115kV breakers

(b2735 – b2739)

Estimated Project Cost: $1.15 M

Required IS Date: June 1, 2018

PJM©2016 43

PenElec Transmission Zone Short Circuit:

• The Hooversville 115kV breakers

‘Ralphton’ & ‘Statler Hill’ are

overstressed.

Immediate Need:

• Due to the immediate need, the timing

required for an RTEP proposal window

is infeasible. As a result, the local

Transmission Owner will be the

Designated Entity.


• Due to the immediate need of the

project no alternatives were considered

Proposed Solution:

• Revise the reclosing of the Hooversville

115 kV ‘Ralphton’ & ‘Statler Hill’

(b2740 - b2741)

Estimated Project Cost: $10 K per breaker

Required IS Date: June 1, 2018

PJM©2016 44

PenElec Transmission Zone

N-1 First Energy Planning Criteria (FERC Form 715):

• Voltage violation in the Tiffany 115 kV vicinity for several contingencies.

Immediate Need:

• Due to the time – sensitive nature and current issue this problem presents, PenElec (Local TO) will be the Designated Entity


• Do to the immediate need of the project, no alternative solution was considered.

Recommendation:

• Install 2 - 28 MVAR capacitors at Tiffany 115 kV substation. (B2748)

Estimated Project Cost: $ 2.5 M

Projected IS Date: 6/1/2017

PJM©2016 45

PSEG Transmission Area Short Circuit:

• The Bergen 138kV breakers “40P” and

“90P” are overstressed.

Immediate Need:

• Due to the immediate need, the timing required

for an RTEP proposal window is infeasible. As a

result, the local Transmission Owner will be the

Designated Entity.


• Due to the immediate need of the project

no alternatives were considered

Proposed Solution:

• Replace the Bergen 138kV breakers “40P”

and “90P”” with 80kA breakers (b2712 –

B2713)

• PSEG Fossil is responsible for 100% of the

cost allocation

Estimated Cost: $3.27 M per breaker

Required IS Date: 06/01/2018

pjm regional transmission expansion planning (rtep) … › static-assets › documents › ...dec...

Documents