ML 164175
^pepco
EP1132
701 Ninth Street, NW
Suite 1100, 10*^ Floor
A PHI Company
Washington, DC 20068
202 872-2318
Douglas E. Micheel
202 331-6767 Fax
Associate General Counsel
demicheel@pepcoholdings.com
February 13, 2015
Mr. David J. Collins
Executive Secretary
Public Service Commission of Maryland
William Donald Schaefer Tower
6 St. Paul Street, 16^ Floor
Baltimore, MD 21202-6808
Re: Case No. 9311
Dear Mr. Collins:
Enclosed please find an original and seventeen (17) copies (five three-hole punched) of
Potomac Electric Power Company's ("Pepco") Annual Report of the Grid Resiliency
Accelerated Priority Feeder Project. This report (provided as Attachment A) was directed by the
Commission to provide information that would allow the Commission to closely monitor the
success and effectiveness of the GRC program. Also included as Attachment B is an update to
Rider "GRC" - Grid Resiliency Charge (proposed, redlined and supporting documentation).
Rider "GRC" has been updated to reflect actual investments placed in service through December
2014 and forecasted investments for 2015 in accordance with Order No. 85724. Pepco requests
that the proposed Rider "GRC" become effective with Usage on and after March 15, 2015.
Please feel free to contact me if you have any questions regarding this matter.
Sincerely,
Douglas E. Micheel
DEM/mda
Enclosures
cc: All Parties of Record
Attachment A
2 pepco
A PHI Companij
Potomac Electric Power Company's
Annual Report of the Grid Resiliency
Accelerated Priority Feeder Project
February 13, 2015
Introduction
In accordance with Order No. 85724, Potomac Electric Power Company (Pepco or the
Company) submits its Annual Report for the 2014 Grid Resiliency Accelerated Priority Feeder
Program (GRC). Order No. 85724 directed Pepco to provide certain information that will allow
the Commission to closely monitor the success and effectiveness of the GRC feeder program.
The Commission directed that the Company provide: (1) the status of each project and respective
milestones completed; (2) actual money spent to date on each project and respective milestone;
(3) the reconciliation of projected costs and recoveries that includes a true-up calculation of overand under- recoveries; and (4) a proposed rate for the GRC for the subsequent year, including
bill impact estimates.
This document also includes a self-assessment with future plans to
improve the project's cost management.
2014 GRC Feeder Status
Twelve feeders were selected for the 2014 GRC work.
All of the projects were
completed by the end of 2014. The actuals were 22% higher than the estimated budget mostly
due to detailed field assessments during engineering design that resulted in scope changes.
Total Cost:
Estimated
Budget
$11,652,600
Actuals
$14,183,215
Variance
Vo Variance
(Estimated Cost vs.
Actuals)
(Estimated Cost vs.
Actuals)
$2,530,615
22%
1
Circuit: 14877
Substation: 24 - ROCKVILLE
General Description:
Maryland
County
Feeder
ID
Duty
Voltage
kV
Customers
Served
Mileage
Feeder Description
UG
OH
Total
Vicinity of Woodbum Rd. at Maple Ave.,
Baltimore
Montgomery
14877
Distribution
8.94
1522
13
7.68
16.62
Rd.
between
Edmonston
Rd.
and
Norbeck Rd. and Bauer Dr. between Norbeck Rd.
and Emory Ln., Rockville, MD. Approximately
96% of customers are residential and 4% are
commercial.
Redtand
Vnsihington
Grove
(^•BohfsrP
Creek
OenMod -
KegiODafPerk
S <9 Leisure
L™
World
Argyk
CoitfitryCkib
Rockvt
s
Aspen Mill
Daorson
Fflrm Park (
Wheaton-Glenmon
a
Proposed GRC Work Summary:
•
Replace 110 poles due to standards
• Replace or install 105 insulated down guys and 54 insulated head guys to improve pole
stability
•
•
Replace 54 head guys
Install one Automatic Circuit Recloser (ACR) to mitigate the impact of outages and facilitate
sectionalization
•
Replace or install 135 animal guards, preventing outages due to animal contact
•
Replace or install 47 lightning arrestors
• Replace approximately 2.1 miles ofprimary bare wire with tree wire in sections of the feeder
that have tree cover, decreasing the likelihood of tree related outages
• Upgrade approximately 3.3 miles of primary wire with 477 Automatic Circuit Sectionalizing
and Restoration (ACSR) to facilitate supplying customers from other feeders to restore their
service during emergency conditions
•
Replace approximately 4.2 miles of open wire secondary with triplex wire, decreasing the
likelihood of faults during storm conditions. Also replace 1,624 feet of secondary service
wire
•
Upgrade two gang operated switches
•
•
Replace 43 transformers
Replace 15 fuse cutouts
Milestones
Feeder
Milestones
14877
Task
Description
Design
Complete
Proposed
11/29/2013
Variance Comments
Actual
1/30/2014
Additional option to re-route feeder identified due to tree
proximity and an unsuccessful atten^t to obtain a tree removal
permit. This issue was identified during the review process. In
addition there was a delay in the peer review and approval of the
project.
Permitting
Complete
Release to
12/27/2013
4/14/2014
12/30/2013
4/15/2014
Complete
Delays in permits caused delays in construction release
milestone.
Construction
Constmction
There was a delay in applying for permits.
12/30/2014 12/30/2014
Completed GRC Work:
•
•
•
•
Installed or replaced 7,995 feet of primary tree wire
Replaced 2,918 feet of primary bare wire
Replaced 29,870 feet of mainline secondary
Replaced 1,076 feet of secondary service
•
Installed one ACR
•
•
•
•
•
Replaced 118 poles
Replaced 106 crossarms
Replaced two gang switches
Replaced 103 fuse cutouts
Replaced 52 transformers, 39 lightning arrestors, and 500 animal guards
Budget and Actuals:
Estimated
Budget
$1,558,900
Actuals
$2,021,315
Variance
(Estimated Cost vs. Actuals)
$462,415
% Variance
(Estimated Cost vs.
Actuals)
30%
Variance Explanation:
The variance was attributed to additional poles, transformers, fuse cutouts and mainline
secondary wires based upon detailed design field review. Subsequent review by Construction
personnel also found additional poles and equipment that needed to be replaced.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting fi-om outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, vegetation accounted for 29% of the outages, equipment failures 19%, and
weather 16%.
Installation of tree wires will decrease the likelihood of tree related outages.
Installation of secondary triplex wires will decrease the likelihood of faults during storm
conditions due to its higher strength and improve restoration time. Installation of a recloser will
mitigate the impact of outages and facilitate sectionalization of sustained faults thus minimizing
the number of customers interrupted. All of the facility upgrades will improve the overall
reliability of this feeder.
Circuit: 15232
Substation: 118-QUINCE ORCHARD
General Description:
Feeder
ID
15232
Maryland
County
Montgomery
Duty
Voltage
Customers
kV
Served
Distribution
Mileage
Feeder Description
UO
41.52
1159
13
OH
15.52
Total
57.04
Feeder 15232 serves the general vicinity
of Jones Lane between Turkey Foot Rd.
and Damestown Rd., Damestown, MD.
Approximately 94% of customers are
residential and 6% are commercial.
wasn
<VSohferP
Darnesto^wi
North
Polomac
wg Pm^
Local Par
V
Obfrt
Travi ah
V
j
^
^
Poromac
,
^
Community
tteighborhood Part
Proposed GRC Work Summary:
•
Replace approximately 1,017 feet of primary wire with All ACSR to meet Pepco's current
standards and facilitate supplying customers from other feeders to restore their service during
emergency conditions
•
Replace approximately 177 feet of open wire secondary with 4/0 triplex to meet Pepco's
current standards
•
Replace one transformer, one fuse cutout, and two animal guards
•
•
Install one insulated down guy to improve pole stability
Install one ACR to mitigate the impact of outages and facilitate sectionalization
Milestones
Feeder
Milestones
15232
Task
Description
Design
Proposed
Actual
Variance Comments
11/15/2013
12/9/2013
Review and revisions to multiple jobs took longer than expected.
12/13/2013
1/3/2014
12/16/2013
1/8/2014
11/3/2014
5/10/2014
Complete
Permitting
Complete
Release to
Construction
Constmction
Last permit actuallyreceived 12/2/13. Tasks were not completed
until job was released.
Needed to wait until 2014 to release as GRC not funded in 2013,
actually readv 12/20/13.
Complete
Completed GRC Work:
•
•
•
•
Installed or replaced 94 feet of primary tree wire
Replaced 768 feet of primary bare wire
Replaced 498 feet of mainline secondary
Replaced nine poles and 11 crossarms
•
Installed one ACR
•
Replaced 14 fuse cutouts
•
Replaced four lightning arrestors, and 22 animal guards
Budget and Actuals:
Estimated
Budget
$111,500
Actuals
$171,847
Variance
(Estimated Cost vs. Actuals)
$60,347
% Variance
(Estimated Cost vs.
Actuals)
54%
Variance Explanation:
The project needed more labor hours than originallyplanned due to traffic control and vegetation
management.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting from outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, vegetation accounted for 65% of the outages and weather 15%. Installation
of a recloser will mitigate the impact of outages and facilitate sectionalization of sustained faults
thus minimizing the number of customers interrupted. Installation of secondary triplex wires
will decrease the likelihood of faults during storm conditions due to its higher strength and
improve restoration time. All of the facility upgrades will improve the overall reliability of this
feeder. Also, during the past two years, Pepco has completed reliability enhancement work on
this feeder totaling over $1M.
Substation: 169 - ROSSMOOR SOUTH
Circuit: 14908
General Description:
Maryland
County
Feeder
ID
Duty
Montgomery
14908
EHstribution
Voltage
Customers
kV
Served
13
1559
Mileage
Feeder Description
UG
20.88
OH
7.11
Total
27.99
Feeder 14908 serves the general vicinity of BelPre Rd. from Connecticut Ave. to Layhill Rd.,
Layhill from Bel-Pre Rd. to Cherter Mill Rd., and
Argyle Club Rd. from Layhill Rd. to Longmead
Crossing and Normandy Crossing Dr., Layhill,
MD. Approximately 91% of customers are
residential and 9% are commercial.
lvior
s
u
tyOub
tsiP®
S
- f
Ar^yle
coonuyciubi
eel PreRd
g
S v»(nmore
Proposed GRC Work Summary:
•
Replace approximately 2.9 miles of primary wire with 477 ACSR to facihtate supplying
customers from other feeders to restore their service during emergency conditions
•
Replace approximately two miles of primary bare wire with tree wire in sections of the
feeder that are exposed to tree cover, decreasing the likelihood of tree related outages
•
•
Replace approximately 1.7 miles of open wire secondary and 475 feet of open wire
secondary services in various locations with triplex wire, decreasing the likelihood of faults
during storm conditions
Replace 43 poles and associated equipment
• Replace or install 58 insulated down guys and seven insulated head guys to improve pole
stability
•
•
•
Replace 43 transformers
Replace 51 fuse cutouts
Replace or install 90 animal guards
•
•
Replace or install 60 lightning arrestors
Upgrade two gang operated switches
Milestones
Feeder
Milestones
14908
Task
Description
Design
Complete
Pei'iiiitting
Complete
Release to
Proposed
Actual
11/22/2013
1/23/2014
12/20/2013
2/28/2014
12/23/2013
3/5/2014
Construction
Variance Comments
Designs were completed by 10/1/2013, but there were delays in
review and approval
Delay in design review cascaded to peiniit application delays.
Delays in permits caused delays in construction release
milestone.
Construction
Complete
12/15/2014 10/13/2014
Completed GRC Work:
•
•
•
•
Installed or replaced 16,772 feet of primary tree wire
Installed or replaced 26,931 feet of primary bare wire
Replaced 12,280 feet of mainline secondary
Replaced 2,719 feet of secondary service wire
•
Replaced 63 poles, 30 crossarms, seven gang switches, 127 fuse cutouts
•
Replaced 27 transformers, one capacitor, 90 lightning arrestors, and 301 animal guards
Budget and Actuals:
Estimated
Budget
$1,296,000
Actuals
$1,777,539
Variance
®/o Variance
(Estimated Cost vs.
Actuals)
(Estimated Cost vs.
Actuals)
$481,539
37%
Variance Explanation:
The variance was driven by material costs. Subsequent review by Construction personnel found
additional poles and equipment needed to be replaced. The additional work was approved by
Engineering. In some cases these additions were proposed while the work was being conducted,
but Engineering was notified for approval before the additional work was performed.
10
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting from outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, vegetation accounted for 62% of the outages and weather 24%. Installation
of tree wires will decrease the likelihood of tree related outages. Installation of secondary triplex
wires will decrease the likelihood of faults during storm conditions due to its higher strength and
improve restoration time. All of the facility upgrades will improve the overall reliability of this
feeder.
11
Circuit: 14945
Substation: 154 -WOOD ACRES
General Description:
Feeder
ID
Maryland
County
Duty
Voltage
Customers
kV
Served
Mileage
Feeder Description
UG
OH
Total
Feeder 14945 serves customers in vicinity of
Massachusetts Ave. from Avalon Dr. to Duvall
14945
Montgomery
Distribution
621
13
0.94
8.57
9.51
Dr. and adjacent streets in Bethesda, MD,
Approximately 91% of customers are residential
and 9% customers are commercial.
a.«Wt
Cab»nJann
WOOMCfej
Park
a
c
®
CfiudeWocrc
CiMiUlFam)
OoMi-Av,
Proposed GRC Work Summary:
•
•
•
•
•
•
•
•
Replace approximately 3.1 miles of tree wire or bare wire with 477 ACSR tree wire
Replace approximately one mile of open wire secondary with triplex wire
Replace 380 feet of secondary service wire
Upgrade three gang switches
Install one ACR to mitigate outages, facilitating sectionalization, and improve the reliability
of the feeder in both storm and blue sky conditions
Replace three poles
Replace or install 18 insulated down guys to provide pole stability
Replace 16 fuses, 30 animal guards, and 23 lightning arresters
12
Milestones
Feeder
Milestones
14945
Task
Description
Design
Complete
Proposed
Variance Comments
Actual
11/15/2013 12/20/2013
This feeder was originaly under the CEMI feeder program which
needed to be redisgned as a GRC feeder. This caused some
issues with reworking some of the original work requests (WR)
and well as adding the new to the existing work. This made the
design more complicated.
Peiiuitting
Complete
12/13/2013
2/14/2014
Allpermits exceptArmy Corps for WR 3400945 received by
12/13/13. Army Corps permitting was more rigorous than in the
past. Tasks were not completed in WMIS until job was released.
ArmyCorps pemiit received 2/13/14. Job was put out to bid
prior to receiving Army Corps pemiit.
Release to
12/16/2013
2/14/2014
Constmction
Araiy Corps permitfor WR 3400945 held up releaseof project.
Project was put out to bid 1/17/14 and awarded 1/31/14 withthe
caveat that WR 3400945 not begin until Army Corps permit
received.
Constmction
11/3/2014
7/9/2014
Complete
Completed GRC Work:
•
•
•
•
Installed or replaced 22,286 feet of primary tree wire
Replaced 4,260 feet of primary bare wire
Replaced 11,932 feet of mainline secondary
Replaced 1,304 feet of secondary service
•
Replaced 32 poles and 89 crossarms
•
Installed one ACR
•
Replaced one gang switch and 57 fuse cutouts
•
Replaced seven transformers, 27 lightning arresters, and 112 animal guards
Budget and Actuals:
Estimated
Budget
$1,087,100
Actuals
$1,342,541
Variance
(Estimated Cost vs. Actuals)
$255,441
13
% Variance
(Estimated Cost vs.
Actuals)
23%
Variance Explanation:
The cost variance was driven by labor, specifically tree trimming charges, and additional
materials that were identified during detailed design which were greater than the estimated
budget. Additional work was also identified during construction which was approved by
engineering.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting fi^om outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, weather accounted for 36% of the outages and vegetation 29%. Installation
of tree wires will decrease the likelihood of tree related outages. Installation of secondary triplex
wires will decrease the likelihood of faults during storm conditions due to its higher strength and
improve restoration time. Installation of a recloser will mitigate the impact of outages and
facilitate sectionalization of sustained faults thus minimizing the number of customers
interrupted. All of the facility upgrades will improve the overall reliability of this feeder.
Further, this feeder is part of the Potomac - Wood Acres - Longwood - Bethesda Automated
Service Restoration (ASR) scheme, which will allow for rapid isolation and restoration,
minimizing the number of customers impacted by outages.
14
Circuit: 15251
Substation: 119 - EMORY GROVE
General Description:
Maryland
County
Feeder
ID
Voltage
Duty
Customers
Served
kV
Mileage
Feeder Description
UG
OH
Total
Vicinity of Emory Grove Rd. between
Strawberry Knoll RD. and Grover Rd. and
15251
Montgomery
1933
13
[>istribution
19.39
4.46
23.85
Goshen
Rd.
between
Odenhal
Ave.
and
Centerway
Rd.,
Gaithersburg,
MD..
Approximately 93% of customers are residential
and 7% are commercial.
•'it.
%
Blue Masti'
5
Golf^iSw
if--' Mom
Iviiiage
«)
®
AgncfjIiKtral
History
ithersfourg
(HE)-
Red land
Wflshinator
Cto/^
•\
/
OerwoocI
CUD
fiwormlFsrk
.
^
^•9BK^^ y
\
Proposed GRC Work Summary:
•
Replace approximately 3,830 feet of single phase lateral #4 copper bare wire with 1/0 tree
wire to meet current Pepco standards for conductor size and reduce the likelihood of tree
related outages
•
Replace approximately 2,051 feet of mainline open wire secondary with triplex wire,
decreasing the likelihood of faults during storm conditions
•
Replace five poles
• Replace or install 21 insulated down guys and one insulated head guyfor pole stability
• Replace two transformers due to their age and not meeting Pepco's current standards
•
Replace eight fiises
•
Replace or install nine animal guards
15
Milestones
Feeder
Milestones
15251
Task
Description
Design
Complete
Permitting
Complete
Release to
Proposed
Actual
11/15/2013
3/31/2014
12/13/2013
4/8/2014
12/16/2013
4/9/2014
Constmction
Constmction
Complete
Variance Comments
Designs were completed by 8/27/2013, but there were delays in
review and approvaL
There was a delay in applying for permits. Duration for permit
review and approval averaged 7-8 weeks.
Delays in permits caused delays in construction release
milestone.
11/3/2014
7/22/2014
Completed GRC work Summary:
•
•
•
•
•
Installed or replaced 4,395 feet of primary tree wire
Replaced 11,059 feet of primary bare wire
Replaced 2,055 feet of mainline secondary wire
Replaced seven poles, 16 crossarms, and 11 fuse cutouts,
Replaced two transformers, 34 lightning arrestors, and 94 animal guards
Budget and Actuals:
Estimated Budget
Actuals
$371,000
$528,009
Variance
(Estimated Cost vs. Actuals)
$157,009
% Variance
(Estimated Cost vs. Actuals)
42%
Variance Explanation:
Additional work was identified by construction personnel upon detailed review of the feeder. An
additional six poles were replaced which were not in the original scope. There were also more
than anticipated hours needed for Traffic Control, which led to the variance in labor.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting from outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, weather accounted for 39% of the outages, vegetation 24%, and equipment
failures 10%. Installation of tree wires will decrease the likelihood of tree related outages.
Installation of secondary triplex wires will decrease the likelihood of faults during storm
conditions due to its higher strength and improve restoration time. All of the facility upgrades
will improve the overall reliability of this feeder.
16
Substation: 156-LINDEN
Circuit: 14272
General Description:
Feeder
ID
14272
Maryland
County
Montgomery
Duty
Distribution
Voltage
kV
Customers
Served
1623
13
Mileage
Feeder Description
UG
3.17
OH
9.63
Total
12.80
Feeder 14272 serves the Vicinities of Gamer Ave.,
Brunswick Ave., Eccleston St., Forest Glen Rd.,
Silver Spring,
MD.
Approximately
98% of customers are
residential and 2% are commercial.
y
as)
SihwSpnng
sa
Proposed GRC Work Summary:
•
Install or replace nine poles to current standards. Replace one insulated head guy to improve
•
pole stability
Install two ACRs to mitigate the impact of outages and facilitate sectionalization
•
•
Replace or install 12 animal guards, preventing outages due to animal contact
Install or replace five transformers
•
Replace approximately 631 feet of primary bare wire with tree wire in sections of the feeder
that have tree cover, decreasing the likelihood of tree related outages
•
Replace approximately 261 feet of primary wire with 477 ACSR bare wire to meet Pepco's
current standards and facilitate supplying customers from other feeders to restore their
service during emergency condition
17
Milestones
Feeder
Milestones
14272
Task
Description
Design
Proposed
Actual
11/29/2013
1/7/2014
12/27/2013
1/7/2014
Delay in design review cascaded to peiinit application delays.
12/30/2013
1/9/2014
Peer reviewand approvals took longer than anticipated.
10/6/2014
4/15/2014
Complete
Permitting
Complete
Release to
Variance Comments
Design completed on 9/18/2013, but review and approval was
delayed.
Construction
Construction
Complete
Completed GRC work Summary:
•
•
•
•
•
Installed or replaced 3,174 feet of primary tree wire
Replaced 274 feet of primary bare wire
Replaced 11 poles
Replaced four crossarms, two ACRs, and 14 fuse cutouts
Replaced nine transformers, two lightning arrestors, and 28 animal guards
Budget and Actuals:
Estimated
Budget
$110,300
Actuals
$148,731
Variance
(Estimated Cost vs. Actuals)
$38,431
®/o Variance
(Estimated Cost vs.
Actuals)
35%
Variance Explanation:
Pre-construction inspection by Construction personnel identified additional spans of wire and
poles that needed to be replaced. This additional work was approved by Engineering.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting from outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, vegetation accounted for 40% of the outages and weather 36%. Installation
of tree wire will decrease the likelihood of tree related outages. The installation of reclosers will
mitigate the impact of outages and facilitate sectionalization of sustained faults thus minimizing
the number of customers interrupted. All of the facility upgrades will improve the overall
reliability of this feeder.
18
Circuit: 14452
Substation: 26 —FOUR CORNERS
General Description:
Maryland
County
Feeder
ID
14452
Duty
Montgomery
Distribution
Voltage
Customers
kV
Served
1224
13
Mileage
Feeder Description
UG
0.77
OH
10.72
Total
11.49
Feeder 14452 serves the vicinity of University
Blvd. at Indian Spring Dr. and Colesville Rd.
between Brewster Ave. and Spring St., Silver
spring, MD. Approximately 97% of customers
are residential and 3% are commercial.
heflton
'%•
'%
-a
Ave
KempW
^
3rT^iVC«ier«i
«nacost(»/V>
T
Genera/ Getry
IVcig#i&i?rfic?od ♦
Park
Siigo
Creek Park
h?reiiO ;n
j:
Sligo Creek
Golf Course
O,
/M4.
Silver Spring
Proposed GRC Work Summary:
•
Replace approximately 3.4 miles of primary wire with 477 ACSR to meet Pepco's current
standards and facilitate supplying customers from other feeders to restore their service during
emergency conditions
•
Replace approximately 2.4 miles of open wire secondary with triplex wire, decreasing the
likelihood of faults during storm conditions. 204 feet of secondary service wire will also be
•
replaced
Replace 58 poles
• Replace or install 31 insulated down guys and 28 insulated head guys to improve pole
stability
• Upgrade eight switches. Several of these switches serve as feeder ties to allow service
restoration via an alternate feeder
•
•
Replace 20 transformers
Replace 27 fuse cutouts
19
Milestones
Feeder
Milestones
14452
Task
Description
Design
Proposed
Actual
11/22/2013
1/23/2014
12/20/2013
4/28/2014
12/23/2013
4/28/2014
Complete
Permitting
Complete
Release to
Construction
Variance Comments
Review and approval took longer than expected.
Cascaded delay and Montgomery County permit averaged
around 5 weeks for approval
Delays in permAs caus^ delays in construction release
milestone.
Constmction
Complete
12/15/2014 12/15/2014
Completed GRC work Summary:
•
•
•
•
•
•
Installed or replaced 8,796 feet of primary tree wire
Replaced 22,777 feet of primary bare wire
Replaced 47,889 feet of mainline secondary
Replaced 10,843 of secondary service
Replaced 128 poles, 127 crossarms, two ACRs, six gang switches, and 129 fuse cutouts
Replaced 23 transformers, 129 lightning arrestors, and 332 animal guards
Budget and Actuals:
Variance
Estimated
Actuals
Budget
$2,710,000
$2,570,187
(Estimated Cost vs.
Actuals)
($139,813)
% Variance
(Estimated Cost vs.
Actuals)
-5%
Variance Explanation:
Additional work was based upon review by Construction personnel and the added work was
approved by Engineering. However, the actual labor cost was lower than proposed due to
favorable bids.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting fi-om outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, weather accounted for 47% of the outages and vegetation 37%. Installation
of tree wires will decrease the likelihood of tree related outages. Installation of secondary triplex
wires will decrease the likelihood of faults during storm conditions due to its higher strength and
improve restoration time. Installation of reclosers will mitigate the impact of outages and
20
facilitate sectionalization of sustained faults thus minimizing the number of customers
interrupted. All of the facility upgrades will improve the overall reliability of this feeder.
21
Circuit: 14240
Substation: 155 - CRAIN HIGHWAY
General Description:
Maryland
County
Feeder
ID
Duty
Prince Georges
14240
Distribution
Voltage
kV
Customers
Served
1066
13
Mileage
Feeder Description
UG
28.62
OH
17.28
Total
45.90
Feeder 14240 serves the Vicinity of Grain
Highway between Sturdee Dr. and Cross Rd.,
and Frank Tippett Rd. between Grain
Highway and Rosaryville Rd., Upper
Marlboro, MD. Approximately 92% of
customers
are
residential
and
8%
are
commercial.
^
*
•
^
• HydeFwW •;?
:
\1
•.• • '"--ft
Ro»anrviBei'H #
ClinloA
jif'.:'
'"it
'» '^r' //
S
P«tuxe
Croom
River
, : Oi»tWRh»m
Oankirk
B(an<tywir
CedsrvHk
^ Charles
.f
1 SD -i;-
Proposed GRC Work Summary:
•
89 poles will be replaced as part of equipment replacements on the poles including wire
•
replacements
About 2.5 miles of bare wire single phase primary will be replaced with larger size wires per
•
the current Pepco standards to ensure switching capabilities in the event of an outage
Replace 840 feet of tree wire along Grain Highway where the risk for tree limbs falling on
the wires is higher
•
Replace about a mile of mainline Open-Wire Secondary wire with triplex wires which has
hi^er strength and a higher chance of withstanding tree related outages with tree limbs
falling on them
•
Replace 1,834 feet of secondary service wire will be replaced with triplex service wires
22
Milestones
Feeder
Milestones
14240
Task
Proposed
Actual
Design
Complete
11/15/2013
11/6/2013
Permitting
Complete
12/13/2013
12/3/2013
12/16/2013
1/28/2014
11/3/2014
6/16/2014
Description
Release to
Variance Comments
Peer review and approvals took longer than antic^ated.
Constmction
Constmction
Complete
Completed GRC work Summary:
• Installed or replaced 6,579 feet of primary tree wire
• Replaced 23,641 feet of primary bare wire
• Replaced 9,668 feet of mainline secondary
• Replaced 1,000 feet of secondary service
• Replaced 90 poles, 60 crossarms, and 66 fuse cutouts; and,
•
Replaced 33 transformers, 34 lightning arrestors, 25 animal guards, and one ACR
Budget and Actuals:
Estimated
Budget
$850,900
Actuals
$1,596,232
Variance
% Variance
(Estimated Cost vs.
Actuals)
(Estimated Cost vs.
Actuals)
$745,332
88%
Variance Explanation:
This project required more poles and equipment that needed replacement than originally
anticipated. Detailed field review found additional areas where wires needed to be upgraded.
There were areas where bare wire was originally planned for which was replaced with tree wire
construction.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting from outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, vegetation accounted for 36% of the outages, equipment failures 31%, and
weather 17%.
Installation of tree wires will decrease the likeUhood of tree related outages.
Installation of secondary triplex wires will decrease the likelihood of faults during storm
conditions due to its higher strength and improve restoration time. Installation of a recloser will
23
mitigate the impact of outages and facilitate sectionalization of sustained faults thus minimizing
the number of customers interrupted. All of the facility upgrades will improve the overall
reliability of this feeder.
24
Circuit: 14943
Substation: 154 -WOOD ACRES
General Description:
Feeder
ID
14943
Maryland
County
Montgomery
Duty
Distribution
Voltage
Customers
kV
Served
13
1283
Mileage
Feeder Description
UG
7.62
OH
10.82
Total
18.44
Feeder 14943 serves vicinity of Mac Arthur Blvd.
From Walhounding Rd. to Vendome Dr.,
Bethesda, MD. Approximately 94% of customers
are residential and 6% customers are commercial.
^ )• '
/X
'f'
•
ivmlSarPmt
Proposed GRC Work Summary:
•
Replace approximately 1.8 miles of primary bare wire with primary tree wire to prevent tree
related outages
•
Replace approximately 2.2 miles of open wire secondary with triplex wire, decreasing the
likelihood of faults during storm conditions
•
Replace 728 feet of bare wire and 497 feet of secondary service wire to meet current Pepco
standards
•
Replace 89 poles
•
Replace or install 33 insulated head guys and 43 insulated dovm guys to provide pole
•
stability
Replace 36 transformers
•
Upgrade two gang operated switches and two manually operated switches. These switches
serve as feeder ties to allow service restoration via a backup feeder
•
Replace 85 fuses, 54 lightning arresters, and 143 animal guards to meet current Pepco
standards and increase system reliability
25
Milestones
Feeder
Milestones
14943
Task
Description
Design
Complete
Permitting
Complete
Release to
Proposed
11/15/2013 12/20/2013
12/13/2013
1/21/2014
This feeder was originafya CEMI feeder which needed to be
redesigned as a GRC feeder. This caused some issues with
reworking some of the original WRs and well as adding the new
to the existingwork. This made the design more complicated.
Last permit actually received 12/14/13. Army Corps permiting
was more rigorous than in the past. Tasks were not completed in
WMIS until iob was released.
12/16/2013
1/21/2014
11/3/2014
11/25/2014
Construction
Delays in permits caused delays in constmction release
milestone.
Construction
Complete
Variance Comments
Actual
Completed GRC work Summary:
•
•
•
•
•
•
Installed and replaced 10,651 feet of primary tree wire
Replaced 1,418 feet of primary bare wire
Replaced 11,694 feet of mainline secondary
Replaced 3,700 feet of secondary service
Replaced 117 poles, 55 crossarms, four gang switches, and 114 fuse cutouts
Replaced 45 transformers, 70 lightning arrestors, and 108 animal guards
Budget and Actuals:
Estimated
Actuals
Budget
$1,304,750
$991,100
Variance
(Estimated Cost vs. Actuals)
$313,650
% Variance
(Estimated Cost vs.
Actuals)
32%
Variance Explanation:
Additional poles and transformers were identified during the detailed design and construction
phases that drove the variance.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting fi-om outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, vegetation accounted for 45% of the outages, weather 21%, and equipment
failures 18%.
Installation of tree wires will decrease the likelihood of tree related outages.
26
Installation of secondary triplex wires will decrease the likelihood of faults during storm
conditions due to its hi^er strength and improve restoration time. All of the facility upgrades
will improve the overall reliability of this feeder. Further, this feeder is part of the Potomac Wood Acres - Longwood - Bethesda Automated Service Restoration (ASR) scheme, which will
allow for rapid restoration of customers impacted by outages.
27
Substation: 192 - LONGWOOD
Circuit: 15115
General Description:
ID
Maryland
County
15115
Montgomery
Feeder
Duty
Voltage
Customers
kV
Served
13
1150
Mileage
Feeder Desolptlon
UG
OH
Total
17.26
3.94
21.2
General vicinity of Seven Locks Rd., Democracy
EMstributioa
Blvd.,
Bells
Mill
Rd.,
Bethesda,
MD.
Approximately 98% of customers are residential
and 2% are commercial.
"oniroj,. Rd
Mont/oss f
Trnen Woods
I oca( Pgjjj
Cabin John
BegiomlPark '
Us
Is Road
Course
ft),
8»/cli _
Branch Parit
Democrse/e/M
uemoc/acKe^,-
eai)it«k8<
McCrdlis
Gardens
Proposed GRC Work Summary:
•
•
•
•
•
•
Install approximately 1,375 feet of three phase All ACSR primary tree wire, 660 feet of
lateral three phase 1/0 tree wire, 2,764 feet of lateral single phase 1/0 tree wire, and 1,578
feet of lateral 1/0 bare wire to meet current Pepco conductor size standards and facilitate
supplying customers from other feeders during emergency conditions
Replace approximately 582 feet of mainline open wire secondary with triplex wire,
decreasing the likelihood of faults during storm conditions
Replace a total of 15 poles
Replace or install 28 insulated down guys and six insulated head guys
Replace seven transformers
Replace or install 71 animal guards and 18 lightning arrestors
28
Milestones
Feeder
Milestones
15115
Task
Description
Design
Complete
Pemiitting
Proposed
Actual
Variance Comments
11/15/2013
12/9/2013
One of the jobs became cormpt in WMIS and needed to be
redone. Also revisions to jobs required. Lateral job originallyput
on hold then reactivated causing delays in design and permitting.
12/13/2013
1/3/2014
12/16/2013
1/8/2014
11/3/2014
5/10/2014
see above
Complete
Release to
actuallv ready 12/20/13.
Constniction
Construction
Needed to wait til 2014 to release as GRC not funded in 2013,
Complete
Completed GRC work Summary:
•
•
•
•
•
•
Installed or replaced 7,559 feet of primary tree wire
Replaced 7,597 feet of primary bare wire
Replaced 611 feet of mainline secondary
Replaced 1,218 feet of secondary service
Replaced 11 poles, four crossarms, and 39 fuse cutouts
Replaced four transformers, nine lightning arrestors, and 82 animal guards
Budget and Actuals:
Estimated
Actuals
Budget
$131,500
$366,207
Variance
(Estimated Cost vs. Actuals)
$234,707
% Variance
(Estimated Cost vs.
Actuals)
178%
Variance Explanation:
The cost variance was driven by material, specifically conductor upgrades. Additional areas
were identified for upgrades by construction upon review of the feeder. This work was approved
by engineering.
Anticipated Benefits:
Thebenefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting from outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, weather accounted for 36% of the outages and equipment failures 36%.
Installation of tree wires will decrease the likelihood of tree related outages.
Installation of
secondary triplex wires will decrease the likelihood of faults during storm conditions due to its
29
higher strength. All of the facility upgrades will improve the overall reliability of this feeder.
Further, this feeder is part of the Potomac - Wood Acres - Longwood - Bethesda Automated
Service Restoration (ASR) scheme, which will allow for rapid restoration of customers impacted
by outages.
30
Substation: 156 - LINDEN
Circuit: 14271
General Description:
Feeder
ID
Maryland
County
Duty
Voltage
Customers
kV
Served
Mileage
Feeder Description
UG
OH
Total
Feeder 14271 serves the Vicinity of Lyttonsville
Rd. between Brookeville Rd. and Grubb Rd. and
14271
Montgomery
Distribution
13
1346
2.79
9.94
12.73
Grubb Rd. between East-West Highway and
Western Ave., Chevy Chase, MD, Approximately
91% of customers are residential and 9% are
commercial.
Silver Spring
Otmibr
Wood*
Proposed GRC Work Summary:
•
Install or replace 112 poles
•
Replace or install 85 insulated down guys and 61 insulated head guys to improve pole
stability
•
•
•
•
•
Install one ACR to mitigate the impact of outages and facilitate sectionalization
Upgrade one gang operated switch
Replace or install 46 animal guards, preventing outages due to animal contact
Replace or install 16 lightning arrestors, preventing outages due to lightning
Replace approximately 3.5 miles of primary bare wire with tree wire in sections of the feeder
that have tree cover, decreasing the likelihood of tree related outages
•
Replace approximately 3.9 miles of open wire secondary with triplex wire, decreasing the
likelihood of faults during storm conditions. 1.4 miles of secondary service wire will also be
replaced
Replace approximately 2,149 feet of primary wire with 477 ACSR bare wire
Install or replace 27 transformers
•
•
•
Replace 67 fuse cutouts
31
Milestones
Feeder
Milestones
14271
Task
Description
Design
Complete
Permitting
Complete
Release to
Proposed
Actual
11/29/2013
1/7/2014
12/27/2013
1/7/2014
12/30/2013
1/9/2014
Variance Comments
delayed.
Permits were actually obtained on 12/20/2013, but the processing
of the permit was delayed in the office.
Delays in permits caused delays in constmction release
milestone.
Constmction
Constmction
Complete
Design completed on 10/8/2013, but review and approval was
10/6/2014
4/15/2014
Completed GRC Work Summary:
• Installed or replaced 166 feet of primary tree wire
• Replaced 15,881 feet of primary bare wire
• Replaced 613 feet of mainline secondary
• Replaced four poles, 29 crossarms, one ACR, and 30 fiise cutouts
•
Replaced 10 transformers, two lightning arrestors, and 50 animal guards
Budget and Actuals:
Estimated
Budget
$579,000
Actuals
$263,918
Variance
% Variance
(Estimated Cost vs.
(Estimated Cost vs.
Actuals)
Actuals)
($315,082)
-54%
Variance Explanation:
The original estimate for this feeder was based on a high level review of the feeder. It had also
included work that was planned in the District of Columbia which was later removed from the
design.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting from outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, vegetation accounted for 31% of the outages and weather 26%. Installation
of a recloser will mitigate the impact of outages and facilitate sectionalization of sustained faults
thus minimizing the number of customers interrupted. Installation of secondary triplex wires will
decrease the likelihood of faults during storm conditions due to its higher strength and improve
32
restoration time. Installation of tree wires will decrease the likelihood of tree related outages.
All of the facility upgrades will improve the overall reliability of this feeder.
33
Substation: 44 - COLESVILLE
Circuit: 15030
General Description:
Maryland
County
Feeder
ID
Montgomery
15030
Duty
Distribution
Voltage
Customers
kV
Served
13
1408
Mileage
Feeder Description
UG
10.42
OH
11.07
Total
21.49
Feeder 15030 serves customers in vicinity of
Randolph Rd. from New Hampshire Ave. to
Middlevale Lane and Briggs Rd. from Middlevale
Lane to
Hathaway Dr., Wheaton
MD.
Approximately 95% customers are residential and
5% customers are commercial.
Country Club
kspen Hill
Wheaton-Glenmoni *
V
®
Nenhf
'wheaton
leOak
QHislngioa
Proposed GRC Work Summary.
•
•
Replace 5.6 miles of primary wire with All ACSR wire to meet Pepco's current standards
and facilitate supplying customers from other feeders to restore their service during
emergency conditions
Replace 2.8 miles of primary wire with 477 ACSR tree wire to meet Pepco's current
standards, prevent tree related outages and facilitate supplying customers from other feeders
to restore their service during emergency conditions
•
Replace 6.5 miles of open wire secondary with triplex wire, decreasing the likelihood of
•
faults during storm conditions. 225 feet of secondary service wire will also be replaced to
meet current Pepco standards
Replace 63 poles
Replace or install 31 insulated head guys and 180 insulated down guys to provide pole
stability
Replace 28 transformers
•
Upgrade one gang operated switch. This switch serves as feeder tie to allow service
•
restoration via a backup feeder
Replace 62 fuses, 76 lighting arresters, and 172 animal guards to meet current Pepco
standards and increase system reliability both in storm and blue sky conditions
•
•
34
Milestones
Feeder
Milestones
15030
Task
Description
Design
Proposed
Actual
11/29/2013
1/22/2014
12/27/2013
1/23/2014
Complete
Release to
Designs were completed by 10/9/2013, but there were delays in
review and approval
Complete
Permitting
Variance Comments
There was a delay in applying for permits. Permits received on
1/22/2014.
12/30/2013
2/5/2014
12/30/2014
8/8/2014
Peer reviewand approvals took longer than antic^ated.
Construction
Construction
Complete
Completed GRC Work Summary:
•
•
•
•
•
Installed or replaced 18,593 feet of primary tree wire
Replaced 38,379 feet of primary bare wire
Replaced 36,388 feet of mainline secondary
Replaced 3,079 feet of secondary service
Replaced 90 poles, 53 crossarms, one gang switch, and 128 fuse cutouts
• Replaced 30 transformers, 67 lightning arrestors, and 151 animal guards
Budget and Actuals:
Variance
Estimated Budget
Actuals
$1,855,300
$2,091,937
(Estimated Cost vs. Actuals)
$236,637
%Variance
(Estimated Cost vs. Actuals)
13%
Variance Explanation:
Additional Verizon poles as well as extra Pepco poles were identified by construction that
needed to be replaced during the pre-construction inspection of the locations. This in turn caused
the increase in the number of poles, cross arms, fuse cutouts and feet of wire which had to be
replaced. In addition, the labor cost was lowerdue to favorable bids.
Anticipated Benefits:
The benefits, both annual and overall, include the reduction of customer service interruptions and
restoration time resulting fi-om outages related to weather, vegetation, and equipment failures,
thus improving system reliability and customer satisfaction. During the outage review period
2010 through 2012, vegetation accounted for 47% of the outages and weather 35%. Installation
of tree wire will decrease the likelihood of tree related outages. Installation of secondary triplex
wires will decrease the likelihood of faults during storm conditions due to its higher strength and
35
1
improve restoration time. All of the facility upgrades will improve the overall reliability of this
feeder. Also, during the past two years, Pepco has completed a Selective Undergrounding
project on this feeder as part of the REP totaling approximately $3.7M.
36
Lessons Learned
Pepco continues to be engaged in self-assessment and lessons learned activities to better mitigate
budget and design variances. A number of opportunities for improvement have been identified
so far, including:
•
Steps taken to prevent variances in actual cost versus planned cost from reoccurring in
the future
o Variances will be reviewed on a monthly basis at a Work Order level. Project costs
will be compared against remaining hours to ensure that the spending is on target,
o
Additional cost items were added to the 2015 estimates based on actual cost items
incurred on previous projects.
o Added scrutiny on material credits. Project close review will have enhanced review
of material credits and issues prior to close.
o The change order process and construction review process summarized in the bullet
point below will also have an impact on controlling the costs.
• Steps taken to prevent design modification from approved work to actual work performed
o Implemented Joint Constructability Review with Construction, Vegetation
Management and Engineering. Required changes will be identified during the review
and the estimate modified before the scope and costs are finalized.
o Any additional unavoidable changes will be greatly minimized with a strict change
order process that involves approval from Engineering and approval from the Project
Sponsor if above a certain percentage limit. This process is already in place but will
be enhanced to include the Project Sponsor.
•
Justification of any costs different from costs for similar work detailed in the Annual
Reliability Compliance Report filed April 1, 2014.
o
Costs for similar work remain the same.
variations in bid price.
37
Any changes, if any will be due to
Attachment B
PROPOSED
y
pepco
A PHI Company
Electric-P.S.C. Md. No. 1
MD
One Hundred and Eighth Revised Page No. 1
RATE SCHEDULES
FOR
ELECTRIC SERVICE
IN
MARYLAND
POTOMAC ELECTRIC POWER COMPANY
pepco
RATES AND REGULATORY PRACTICES GROUP
Date of issue; February 13, 2015
Date Effective: Usage on and after March 15, 2015
21 popoo
A PHI Compon«j
mmp.
Electhc-P.S.C. Md. No. 1
One Hundred and Eighth Revised Page No. 2
TABLE OF CONTENTS
RATE SCHEDULES
RESIDENTIAL SERVICE-SCHEDULE "R"
Rage 3- 3.1
TIME METERED RESIDENTIAL SERVICE-SCHEDULE"R-TM"
Page 4- 4.1
GENERAL SERVICE - SCHEDULE "GS"
Page 5 - 5.1
TEMPORARY SERVICE-SCHEDULE "T"
Page 6- 6.1
TIME METERED MEDIUM GENERAL SERVICE - LOW VOLTAGE - TYPE II
SCHEDULE "MGTLV11"
Page 7- 7.2
TIME METERED MEDIUM GENERAL SERVICE - LOW VOLTAGE - TYPE II A
SCHEDULE "MGT LV II A" {THIS SCHEDULE HAS BEEN DELETED)
Page 7.3 - 7.5
TIME METERED MEDIUM GENERAL SERVICE - LOW VOLTAGE - TYPE III
SCHEDULE "MGT LV 111"
Page 7.6 - 7.8
TIME METERED MEDIUM GENERAL SERVICE - PRIMARY SERVICE - TYPE II
SCHEDULE "MGT 3A 11"
Page 8- 8.2
TIME METERED MEDIUM GENERAL SERVICE - PRIMARY SERVICE - TYPE II A
SCHEDULE "MGT 3AII A" (THIS SCHEDULE HAS BEEN DELETED)
Page 8.2- 8.5
TIME METERED MEDIUM GENERAL SERVICE - PRIMARY SERVICE - TYPE III
SCHEDULE "MGT 3A III"
Page 8.6 - 8.8
TIME METERED GENERAL SERVICE - LOW VOLTAGE -
SCHEDULE "GT LV
Page 9- 9.2
TIME METERED GENERAL SERVICE - PRIMARY SERVICE -
SCHEDULE "GT 3A"
Page 10 - 10.2
TIME METERED GENERAL SERVICE - HIGH VOLTAGE -
SCHEDULE "GT 3B"
Page 11 -11.2
TIME METERED RAPID TRANSIT SERVICE - SCHEDULE "TM-RT'
Page 12 -12.1
ELECTRIC VEHICLE SERVICE - SCHEDULE "EV"
Page 13-131
(THIS SCHEDULE IS CLOSED TO NEW CUSTOMERS)
OUTDOOR LIGHTING SERVICE - SCHEDULE "OL"
Page 14-14.1
STREET LIGHTING SERVICE - SCHEDULE "SL"
Page 15 -15.1
SERVICING STREET LIGHTS SERVED FROM OVERHEAD LINES -
SCHEDULE "SSL-OH"
Page 16-16.2
SERVICING STREET LIGHTS SERVED FROM UNDERGROUND
LINES - SCHEDULE "SSL-UG"
Date of Issue; February 13. 2015
Page 17 -17.2
Date Effective: Usage on and after March 15. 2015
19 popco
A PHI Compomj
Electric-P.S.C. Md. No. 1
IvID
One Hundred and Eighth Revised Page No. 2.1
SERVICING STREET LIGHTS SERVED FROM OVERHEAD LINES-
SCHEDULE "SSL-OH-LED"
Page 17.3-17.5
SERVICING STREET LIGHTS SERVED FROM UNDERGROUND LINES-
SCHEDULE "SSL-UG-LED"
Page 17.6-17.8
TELECOMMUNICATIONS NETWORK SERVICE - SCHEDULE "TN"
Page 18 -18.1
COGENERATION AND SMALL POWER PRODUCTION INTERCONNECTION
SERVICE - SCHEDULE "CG-SPP" PURCHASE OF POWER
Page 19-19.4
STANDBY SERVICE - SCHEDULE "S"
Page 20 - 20.1
PLUG-IN VEHICLE CHARGING - EXPERIMENTAL - SCHEDULE "PIV"
Page 21 - 21.1
RESIDENTIAL SERVICE - EXPERIMENTAL PLUG-IN VEHICLE CHARGING -
SCHEDULE "R-PIV"
Page 22-22.1
RESERVED FOR FUTURE USE
Page 23 - 26
RIDERS
MARKET PRICE SERVICE - RIDER "MPS"
Page 27 - 27 1
(THIS RIDER HAS BEEN DELETED)
UNIVERSAL SERVICE CHARGE RECOVERY - RIDER "USC"
Page 28
GENERATION PROCUREMENT CREDIT - RIDER "GPC"
Page 29 - 29.1
(THIS RIDER HAS BEEN DELETED)
EXPERIMENTAL RESIDENTIAL ELECTRIC VEHICLE SERVICE -
RIDER "R-EV"
Page 30
EXPERIMENTAL RESIDENTIAL TIME-OF-USE ELECTRIC VEHICLE
SERVICE - RIDER "R-TM-EV
Page 30.2
NET ENERGY METERING "NEM"
Page 31 -31.3
EXPERIMENTAL CONJUNTIVE BILLING SERVICE- RIDER "CBS"
Page 32 - 32.1
(THIS RIDER HAS BEEN DELETED)
TELECOMMUNICATION NETWORK CHARGE - RIDER "SL-TN"
Page 33
POWER FACTOR-RIDER "PF"
Page 34
THERMAL ENERGY STORAGE SERVICE - RIDER "TS"
Page 35
DELIVERY TAX SURCHARGE - RIDER "DT"
Page 36
MONTGOMERY COUNTY SURCHARGE - RIDER "MCS"
Page 37
MARYLAND ENVIRONMENTAL SURCHARGE - RIDER "MES"
Page 38
Date of Issue: February 13, 2015
Date Effective: Usage on and after March 15, 2015
popoo
A PHI Compcmij
mmp.
Electric-P.S.C. Md. No. 1
Seventy-Fifth Revised Page No. 2.2
TEMPORARY TAX COMPLIANCE SURCHARGE - RIDER "TTCS"
Page 39
(THIS RIDER HAS BEEN DELETED)
OPTIONAL METER EQUIPMENT RELATED SERVICES - RIDER "OMRS"
Pages 40-40.2
EXCESS FACILITIES - RIDER "EF"
Page 41
DIVESTITURE SHARING CREDIT - RIDER "DS"
Page 42
(THIS RIDER HAS BEEN DELETED)
STANDARD OFFER SERVICE - RIDER "SOS"
Page 43-43.6
ADMINISTRATIVE CREDIT - RIDER "AC"
Page 44
SOS PHASE IN CREDIT/DEFERRED COST ADJUSTMENT-RIDER "SOS PIC/DCA".
Page 45 - 45 1
(THIS RIDER HAS BEEN DELETED)
RESERVED DELIVERY CAPACITY SERVICE - RIDER "RDCS"
Page 46 - 46.1
BILL STABILIZATION ADJUSTMENT - RIDER "BSA"
Page 47 - 47.1
EMPOWER MD CHARGE - RIDER "E-MD"
Page48-48.1
RESIDENTIAL DIRECT LOAD CONTROL - RIDER "R-DLC"
Page 49 - 49.1
RGGI RATE CREDIT - RIDER "RRC"
Page 50
MASTER-METERED DIRECT LOAD CONTROL-RIDER "MM-DLC"
Page 51-51.1
AGGREGATE NET ENERGY METERING - RIDER "ANEM"
Page 52 - 52.4
NON-RESIDENTIAL DIRECT LOAD CONTROL - RIDER "NR-DLC"
Page 53
DEMAND RESOURCE SURCHARGE - RIDER "DRS"
Page 54 - 54.1
DYNAMIC PRICING - PEAK ENERGY SAVINGS CREDIT - RIDER "DP"
Page 55 - 55.1
GRID RESILIENCY CHARGE - RIDER "GRC"
Page 56- 56.1
Date of Issue; February 13, 2015
Date Effective: Usage on and after March 15, 2015
Q popoo
A PHI Compcn«j
Electric-P.S.C. Md. No. 1
MD
First Revised Page No. 56
GRID RESILIENCY CHARGE RIDER - RIDER "GRC"
APPLICABILITY
The Distribution Charges billed under the Schedules "R", "R-TM", "GS", "T", "MGT LV M", "MOT LV III"
"MOT 3A II", "MGT 3A III", "GT LV, "GT 3A", "GT 3B", "TM-RT', "SL", "OL", "EV and "TN" shall be
subject to the Grid Resiliency Charge as specified in the terms of this Rider. The Grid Resiliency Charge
provides for collection of the monthly charges and rates set forth.
The Grid Resiliency Charge is specifically intended to recover approved expenditures determined to be
incremental to those required to meet Maryland electric distribution reliability standards specified in the
Maryland Service Quality and Reliability Standards and undertaken in an accelerated timeframe with
respect to the baseline planning levels,
DETERMINATION OF CHARGE
The Grid Resiliency Charge will be based on revenue requirements calculated using projected annual
expenditures. The revenue requirement will include the following items and adjustments:
1. Return on incremental accelerated capital expenditures placed into service during the period at
the authorized rate of return.
2. Recovery of incremental accelerated capital expenditures placed into service during the period
through depreciation expense.
3. incremental accelerated operating and maintenance expenses.
4. Reconciliation of the deferred balance on an annual basis, (See "Adjustmentto Charge")
5. The Grid Resiliency Charge is currently expected to remain in effect for approximately three years
beginning in January 2014, and thereafter will continue in effect until the completion of the first
rate case filed after all of approved grid resiliency-related projects are placed into service.
MONTHLY CHARGES AND RATES:
Rate Schedule
Effective March 15. 2015
$0.00016
per kwhr
"R"
"GT LV"
"GT 3A"
"GT 3B"
"TM-RT"
$0.0405
$0.0375
$0.0435
$0.0286
$0.0192
$16,56
"SL"
"TN"
$0.00011
$0.00012
per
per
per
per
per
per
per
per
per
per
$0.01
$0.01
$0.02
per lamp per month
per lamp per month
"R-TM"
"GS", "T", "EV"
"MGT LVII", "MGT LVIII"
"MGT 3Air, "MGT 3AIII"
$0.00016
$0.00017
kwhr
kwhr
kw of maximum demand
kw of maximum demand
kw of maximum demand
kw of maximum demand
kw of maximum demand
month per delivery point
kwhr
kwhr
"OL"
Mecurv Vaoor
175 Watt
250 Watt
400 Watt
High Pressure Sodium
100 Watt
150 Watt
250 Watt
Date of Issue:
$0.01
$0.01
$0.01
February 13, 2015
per lamp per month
per lamp per month
per lamp per month
per lamp per month
Date Effective;
Usage on and after
March 15, 2015
01 pepco
A PHI Company
^mw-%
Electric-P.S.C. Md. No. 1
^ ^
First Revised Page No. 56.1
ADJUSTMENT TO CHARGE
The Grid Resiliency Charge is subject to deferred accounting. A monthly over/under recovery calculation
will be performed based on actual revenues received under Grid Resiliency Charge Rider and the actual
revenue requirement in each month, and the over/under recovery will be tracked as a deferred balance.
Interest on this balance will be calculated monthly using the Company's short term debt rate. The interest
rate will be reset each month. The deferred balance will be reconciled on an annual basis.
Date of Issue:
February 13, 2015
Date Effective: Usage on and after
March 15, 2016
REDLINE
A PHI CompCTM^
Electric-P.S.C. Md. No. 1
MD
One Hundred and Eighth Soventh Revised Page No. 1
RATE SCHEDULES
FOR
ELECTRIC SERVICE
IN
MARYLAND
POTOMAC ELECTRIC POWER COMPANY
pepco
RATES AND REGULATORY PRACTICES GROUP
Date of Issue: February 13
2015
Date Effective: Usage on and after
March 15. February 9, 2015
popoo
A PHI CompOTHJ
Electric-P.S.C. Md. No. 1
iViU
One Hundred and Eighth Sovonth Revised Page No. 2
TABLE OF CONTENTS
RATE SCHEDULES
RESIDENTIAL SERVICE-SCHEDULE"R"
Page 3- 3.1
TIME METERED RESIDENTIAL SERVICE-SCHEDULE "R-TM"
Page 4- 4.1
GENERAL SERVICE-SCHEDULE"GS"
Page 5- 5.1
TEMPORARY SERVICE - SCHEDULE "T"
Page 6 - 6.1
TIME METERED MEDIUM GENERAL SERVICE - LOW VOLTAGE - TYPE II
SCHEDULE "MGTLVir
Page 7- 7.2
TIME METERED MEDIUM GENERAL SERVICE - LOW VOLTAGE - TYPE II A
SCHEDULE "MGT LVII A" {THIS SCHEDULE HAS BEEN DELETED)
Page 7.3 - 7.5
TIME METERED MEDIUM GENERAL SERVICE - LOW VOLTAGE - TYPE III
SCHEDULE "MGT LV III"
Page 7.6 - 7.8
TIME METERED MEDIUM GENERAL SERVICE - PRIMARY SERVICE - TYPE II
SCHEDULE "MGT 3A II"
Page 8- 8.2
TIME METERED MEDIUM GENERAL SERVICE - PRIMARY SERVICE - TYPE It A
SCHEDULE "MGT 3AII A" (THIS SCHEDULE HAS BEEN DELETED)
Page 8.2 - 8.5
TIME METERED MEDIUM GENERAL SERVICE - PRIMARY SERVICE - TYPE III
SCHEDULE "MGT 3A III"
Page 8.6 - 8.8
TIME METERED GENERAL SERVICE - LOW VOLTAGE -
SCHEDULE "GTLV
Page 9- 9.2
TIME METERED GENERAL SERVICE - PRIMARY SERVICE -
SCHEDULE "GT 3A"
Page 10 -10.2
TIME METERED GENERAL SERVICE - HIGH VOLTAGE -
SCHEDULE "GT 38"
Page 11 -11.2
TIME METERED RAPID TRANSIT SERVICE - SCHEDULE "TM-RT'
Page 12 - 12.1
ELECTRIC VEHICLE SERVICE - SCHEDULE "EV
Page 13-131
(THIS SCHEDULE IS CLOSED TO NEW CUSTOMERS)
OUTDOOR LIGHTING SERVICE - SCHEDULE "OL"
Page 14 -14.1
STREET LIGHTING SERVICE - SCHEDULE "SL"
Page 15 -15.1
SERVICING STREET LIGHTS SERVED FROM OVERHEAD LINES -
SCHEDULE "SSL-OH"
Page 16 -16.2
SERVICING STREET LIGHTS SERVED FROM UNDERGROUND
LINES - SCHEDULE "SSL-UG"
Date of Issue: February 13 §, 2015
Page 17 -17.2
Date Effective: Usage on and after
March 15. February 9, 2015
51 pepoo
A PHI Compontj
Electric--P.S.C. Md. No. 1
IViD
One Hundred and Eighth SGVonth Revised Page No. 2.1
SERVICING STREET LIGHTS SERVED FROM OVERHEAD LINES -
SCHEDULE "SSL-OH-LED"
Page 17.3 - 17.5
SERVICING STREET LIGHTS SERVED FROM UNDERGROUND LINES-
SCHEDULE "SSL-UG-LED"
Page 17.6 -17.8
TELECOMMUNICATIONS NETWORK SERVICE - SCHEDULE "TN"
Page 18 -18.1
COGENERATION AND SMALL POWER PRODUCTION INTERCONNECTION
SERVICE - SCHEDULE "CG-SPP" PURCHASE OF POWER
Page 19 -19.4
STANDBY SERVICE - SCHEDULE "S"
Page 20 - 20.1
PLUG-IN VEHICLE CHARGING - EXPERIMENTAL - SCHEDULE "PIV
Page 21-21.1
RESIDENTIAL SERVICE - EXPERIMENTAL PLUG-IN VEHICLE CHARGING -
SCHEDULE "R-PIV"
Page 22 - 22.1
RESERVED FOR FUTURE USE
Page 23 - 26
RIDERS
MARKET PRICE SERVICE - RIDER "MPS"
(THIS RIDER HAS BEEN DELETED)
Page 27 - 27.1
UNIVERSAL SERVICE CHARGE RECOVERY - RIDER "USC"
Page 28
GENERATION PROCUREMENT CREDIT - RIDER "GPC"
Page 29 - 29.1
(THIS RIDER HAS BEEN DELETED)
EXPERIMENTAL RESIDENTIAL ELECTRIC VEHICLE SERVICE -
RIDER "R-EV
Page 30
EXPERIMENTAL RESIDENTIAL TIME-OF-USE ELECTRIC VEHICLE
SERVICE - RIDER "R-TM-EV
Page 30.2
NET ENERGY METERING "NEM"
Page 31 -31.3
EXPERIMENTAL CONJUNTIVE BILLING SERVICE ~ RIDER "CBS"
Page 32 - 32.1
(THIS RIDER HAS BEEN DELETED)
TELECOMMUNICATION NETWORK CHARGE - RIDER "SL-TN"
Page 33
POWER FACTOR-RIDER "PF"
Page 34
THERMAL ENERGY STORAGE SERVICE - RIDER "TS"
Page 35
DELIVERY TAX SURCHARGE - RIDER "DT"
Page 36
MONTGOMERY COUNTY SURCHARGE - RIDER "MCS"
Page 37
MARYLAND ENVIRONMENTAL SURCHARGE - RIDER "MES"
Page 38
Date of Issue; February 13 §, 2015
Date Effective: Usage on and after
March 15. February 0. 2015
^pepoo
A PHI Compamj
Electric-P.S.C. Md, No. 1
IVID
Seventy-Fifth Fourth Revised Page No. 2.2
TEMPORARY TAX COMPLIANCE SURCHARGE - RIDER "TTCS"
Page 39
(THIS RIDER HAS BEEN DELETED)
OPTIONAL METER EQUIPMENT RELATED SERVICES - RIDER "OMRS"
Pages 40 - 40.2
EXCESS FACILITIES - RIDER "EF"
Page 41
DIVESTITURE SHARING CREDIT - RIDER "DS"
Page 42
(THIS RIDER HAS BEEN DELETED)
STANDARD OFFER SERVICE - RIDER "SOS"
Page 43 - 43.6
ADMINISTRATIVE CREDIT - RIDER "AC
Page 44
SOS PHASE IN CREDIT/DEFERRED COST ADJUSTMENT-RIDER "SOS PIC/DCA".
Page 45 - 45.1
(THIS RIDER HAS BEEN DELETED)
RESERVED DELIVERY CAPACITY SERVICE - RIDER "RDCS"
Page 46 - 46.1
BILL STABILIZATION ADJUSTMENT - RIDER "BSA"
Page 47 - 47.1
EMPOWER MD CHARGE - RIDER "E-MD"
Page 48 - 48.1
RESIDENTIAL DIRECT LOAD CONTROL- RIDER "R-DLC"
Page 49 - 49.1
RGGi RATE CREDIT- RIDER "RRC"
Page 50
MASTER-METERED DIRECT LOAD CONTROL - RIDER "MM-DLC"
Page 51 - 51.1
AGGREGATE NET ENERGY METERING - RIDER "ANEM"
Page 52 - 52.4
NON-RESIDENTIAL DIRECT LOAD CONTROL - RIDER "NR-DLC
Page 53
DEMAND RESOURCE SURCHARGE - RIDER "DRS"
Page 54 - 54.1
DYNAMIC PRICING - PEAK ENERGY SAVINGS CREDIT- RIDER "DP"
Page 55 - 55.1
GRID RESILIENCY CHARGE - RIDER "GRC"
Page 56 - 56.1
Date of Issue; February 13 §, 2015
Date Effective: Usage on and after
March 15. February 0, 2015
^
popco
A PHI CompoTHj
Electric--P,S.C. Md. No. 1
MD
First Revised Original Page No. 56
GRID RESILIENCY CHARGE RIDER - RIDER "GRC"
APPLICABILITY
The Distribution Charges billed under the Schedules "R", "R-TM", "GS", "T", "MGT LV 11", "MOT LV III",
"MOT 3A II", "MGT 3A HI". "GT LV", "GT 3A", "GT 3B", "TM-RT", "SL". "OL", "EV" and "TN" shall be
subject to the Grid Resiliency Charge as specified in the terms of this Rider. The Grid Resiliency Charge
provides for collection of the monthly charges and rates set forth.
The Grid Resiliency Charge is specifically Intended to recover approved expenditures determined to be
incremental to those required to meet Maryland electric disthbution reliability standards specified in the
Maryland Service Quality and Reliability Standards and undertaken in an accelerated timeframe with
respect to the baseline planning levels.
DETERMINATION OF CHARGE
The Grid Resiliency Charge will be based on revenue requirements calculated using projected annual
expenditures. The revenue requirement will include the following items and adjustments:
1. Return on incremental accelerated capital expenditures placed into service during the period at
the authorized rate of return,
2. Recovery of incremental accelerated capital expenditures placed into service during the period
3.
4.
through depreciation expense.
Incremental accelerated operating and maintenance expenses.
Reconciliation of the deferred balance on an annual basis. (See "Adjustment to Charge")
5. The Grid Resiliency Charge is currently expected to remain In effect for approximately three years
beginning in January 2014, and thereafter will continue in effect until the completion of the first
rate case filed after all of approved grid resiliency-related projects are placed into service.
MONTHLY CHARGES AND RATES:
Effective March 15. 2015
Rate Schedule
January 1, 201*1
"GT 3A"
"GT SB"
$0.0435
$0.0286
$0.0192
06 per kwhr
04 per kwhr
05 per kwhr
per kw of maximum
457 per kw of maximum
443 per kw of maximum
00§-per kw of maximum
066 per kw of maximum
"TM-RT"
"SL"
$ 16.56
§r02 per month per delivery point
$0.00011
"R"
"R-TM"
"GS", "T", "EV"
"MGT LV II", "MGT LV III"
"MGT 3A II", "MGT 3A III"
"GT LV
$0.00016
$0.00016
$0.00017
$0.0405
$0.0375
$0.00012
"TN"
"OL"
demand
demand
demand
demand
demand
04 per kwhr
04 per kwhr
Mecurv Vaoor
$0.01
00
$0.01
$0.02
per lamp per month
per lamp per month
04
per lamp per month
100 Watt
$0.01
QQ
150 Watt
250 Watt
$0.01
$0.01
per lamp per month
per lamp per month
per lamp per month
175 Watt
250 Watt
400 Watt
High Pressure Sodium
Date of Issue:
February 13. 2015 August 1, 2013
Date Effective; Usage on and after
March 15. 2015 January 1. 2014
A PHI CorrtpoTHj
Electric-P.S.C. Md. No. 1
MD
First Revised Original Page No, 56.1
ADJUSTMENT TO CHARGE
The Ghd Resiliency Charge is subject to deferred accounting. A monthly over/under recovery calculation
will be performed based on actual revenues received under Grid Resiliency Charge Rider and the actual
revenue requirement in each month, and the over/under recovery will be tracked as a deferred balance.
Interest on this balance will be calculated monthly using the Company's short term debt rate. The Interest
rate will be reset each month. The deferred balance will be reconciled on an annual basis.
Date of Issue;
February 13. 2015 August 1. 2013
Date Effective: Usage on and after
March 15. 2015
Schedules 1 through 6
Schedule 1
Pepco MD
Development of Grid Resiliency Charge Revenue Requirements
Jan-14
Rate Base:
Feb-14
Gross Plant
S
.
s
8,074
Accumulated Depredation
9
•
$
Defeired Taxes
S
-
$
6
13
NOLC Adjustment
S
•
$
$
8,067
$
9
9
Net Rate Base
Operating Income:
Oper. & Maint.
Depreciation
Jun-14
Sep-14
Aug-14
Jul-U
Oct-14
Nov-14
S 70,816
$ 153,055
$ 1.663.969
S 1,891.122
$ 4,505,600
$ 5,009,719
$ 6,033.057
$ 8,318,125
S
8,811,919
S
S
$
S
$
$
$
$
$
$
$
S
$
$
S
$
$
S
50,629
102,072
(13) $
69
139
(139) $
$ 70,748
9
S
9
6
$
(4) S
$
S
63
$
(39) S
Subtotal
$
SIT-Current
$
-
FIT-Currerrt
Deferred Taxes - before NOLC
$
-
9
$
-
9
(16) 9
13
(153) s
Required Oper. Inc.
Return Required
Revenue Requirement
$
$
-
9
(0) 9
•
9
26
$
251
S
$
'
$
43
S
424
43
9
424
.
(499) $
-
6
9
247
499
$ 152,808
-
$
$
May-14
Apr-14
Mar-14
63
126
-
1.688
3.403
(3.403) $
$ 1,662.281
9
178
9
178
9
(112) $
(435) $
.
1,440
1,440
4.505
9,083
(9.083) $
9.574
19.301
(19.301) $
17,099
34,473
(34,473) $
$ 1.886.617
$ 4,496.026
$ 4.992,619
9
$
S
$
9
9
(903) 9
(3,514) 9
.
2,818
2,818
9
(1.766) 9
(6,873) 9
5,681
-
5,068
$
5,068
9
(3,139) 9
(12,217) 9
10,218
-
(52.063) $
37.150
74.898
(74.898) $
$ 6.007.233
$ 8,280J74
$
9
S
s
$
$
7,525
9
7,525
9
(4,661) 9
(18,144) 9
•
8,725
8,725
s
(5,404) 9
(21,035) S
17,590
$
(7,016) $
(27,311) $
22,835
(102.072) $
8,761,290
-
13,478
13.478
(132,617)
$ 10.4S0.Q6S_
$
$
$
(8.353) $
(32,515) $
27,174
65,779
132,617
15,151
(9,395)
(36,570)
30.545
9
5,770
9
11,283
9
20,238
S
30,087
9
34,879
s
45,306
9
54,038
9
60.916
$
1,205
$
9,772
9
19,107
9
34,586
$
51,408
9
59.596
s
77,405
$
92,293
9
103.996
$
1.205
$
9,772
9
19,107
9
34,586
9
51.408
S
59,596
9
77.405
S
92.293
S
103,996
(8)
(72) 9
9
(140) 9
9
(69) 9
9
(108) 9
(125) S
(166) 9
$
-
15,151
711
(3) 9
9
$
$
$
2,904
360
S
.
11,326
11,326
S 10,515.844
$
$
9
15,172
25,824
52,063
Dec-14
(216) 9
(270)
Income Statement Check
Revenue
$
9
Oper. & Maint.
$
9
Depreciation & Amorlizaton
9
Other Taxes
$
$
Interest Expense
9
Net income before Taxes
9
Inconne Tax - Current
Income Tax - Defered
9
9
Earnings
Return on Equity per WACC
•
9
1
9
9
27
$
216
9
9
10
9
9
100
9
9
9
9
$
284
$
2,307
9
252
9
715
9
5.808
9
9
-
6
26
S
-
9
63
9
178
1,440
-
2,818
9
9
9
-
5,068
9
423
9
766
9
4,510
11,356
9
9
7,659
21,093
$
$
9
-
7.525
1.139
11.386
31,357
9
9
9
9
9
-
$
•
-
8,725
9
11,326
9
1,320
9
9
1,715
17.146
9
13,200
36,351
9
13.478
2.045
20.451
9
47.218
9
56.319
9
9
9
-
15,151
2,304
23,054
63,488
(1.705) $
(2.516) $
(2.918) 9
9
10.218
$
15,172
9
17.590
9
22.835
9
27.174
9
30,545
3,464
9
6.772
9
9
21.679
21.679
9
9
33,587
9
37,862
9
18,701
18,701
9
6,772
12.579
12.579
28,160
9
9
9
9
3,464
28,160
9
33,587
9
37,862
8,635
9
16,891
9
30,384
S
45,115
9
52,304
$
67,901
$
80,803
9
90,827
9
277.675
9
58.489
s
56,869
9
52,387
S
43,889
$
42.055
9
50.216
(1.205) 9
(9,772) 9
258,568
9
23,903
$
5.461
9
(7.209) 9
(468) 9
(1.672) 9
(11,444) 9
247,124
9
271,026
$
276.487
9
269,278
(279) 9
(997) 9
(6.825) 9
147,378
9
161,633
9
164.890
9
160,591
(24) 9
13
9
126
$
t
9
•
$
$
15
9
150
15
9
150
MACRS
$
•
9
38
9
375
GRC BiNings
$
•
9
GRC Defenal
$
•
9
(43) 9
(424) $
Cumulative Deferral
9
-
$
(43) 9
Cumulative Deferral Net of Tax
9
•
$
(26) 9
-
(71) $
(560) 9
360
$
2.904
9
427
9
427
$
$
S
1,070
$
s
9
-
-
(1.097) 9
(3.777) 9
9
9
5.681
(2) 9
$
9
$
.
9
9
•
-
$
-
(4.442) 9
(4,920)
$
394,344
131,745
(33,516) $
(50,238) $
(53,779) $
9
235.762
S
185,524
$
131,745
9
140,602
S
110,642
$
78,569
= Cumu)a6ve Balance x (1-Composite Tax Rate)
Short Temi Debt Rate
Interest
= Average Net of Tax B^nce x Monthly Interest Rate
0.28%
0.27%
-
0.25%
$
(0.03) $
0.00%
-
0.00%
0.00%
$
-
i
-
0.00%
9
-
0.00%
$
-
0.00%
0.00%
$
-
$
-
0.00%
$
0.46%
36.27
9
36.24
Schedule 2
Peoco MD
Developmenc of GrWResiliency Charge Revenue Requirements
Jan-15
Oec-14
Gross Plant
Accumulated Depreciation
Deferred Taxes
NOLC Adjustment
Net Rate Base
Operate IrKome:
C^>er.& MainL
Depreciation
Subtotal
SIT-Current
FIT-Current
Deferred Taxes - before NOLC
$ 14,200,376
s
$
$
$
s
s
Required Oper. Inc
Return Required
$
Revenue Requirement
$
Revenue
Oper. & Maim
Depreciation &Anwrbzation
Other Taxes
Interest Expense
Net income txtfore Tans
s
$
S
s
s
s
$
-
$
$
18,224 s
18,224 s
(10,272) $
(39,985) s
31,003
S 14.200.376
S
s
$
s
s
$
(10,634) s
(41,391) s
31,003 s
(2.797) s
89.464 $
s
166,898
$
287,632
s
s
-
-
18.224
$
18.224
s
18.224
s
18.224
•
(10,630) s
(41,377) s
31,003
$
(2,780) s
s
s
s
(10,626) s
(41,363) $
(41.348) s
31,003
$
(2.762) s
31,003
s
(2,746) s
-
18,224
18.224
S 14.200,376
s
18.224
s
18.224
(10,619) s
(41,334) s
31,003
-
s
%
(2,727) s
$
s
s
s
(10,616) %
(41,320) $
31,003
Sep-15
AuQ-15
JU-1S
14.200,376
193,346 S
211,570
175,122 S
318,635 s
349,638 s
380,640
(380.6401
(318,635) s
(349.6381 s
14.025.254 s 14.007.030 s 13.988.806
14.200,376
$
s
(10.623) $
$
(2,709) s
•
18,224
18,224
(10,612)
(41,306)
31,003
(2.692)
S 15,501.716
231.464
S
414.486
s
$
s
(414.485) s
15.270.262 s
s
s
s
$
s
$
s
$
89,232
s
89,117
$
89.001
$
86,886
$
s
148.278
s
148,110
$
147.942
s
147.774
s
s
$
148,446
S
148,278
S
148,110
$
147.942
S
147,774
S
s
147,606
s
18.224
18.224
s
18.224
3,270
33.595
92.518
$
-
$
-
s
s
3,289
s
3,286
33,814
93,120
$
$
S
s
18,224
s
-
S
-
s
s
-
s
s
18,224
3,281
S
s
16.224
3,278
s
3.274
$
33,770
92,999
s
33.726
s
33,682
s
33.639
s
92.879
s
92,758
$
92,638
s
s
6,534
31,003
s
6.485
s
6,437
s
s
31.003
s
31,003
s
6.388
31,003
$
88.770
147.606
•
Oc»-15
S 15.501.716
s
$
89.348
148.446
s
s
$
s
18.224
3,292
33,867
93,240
s
(287.632)
14.043.477
18,224
148,614
81.184
.
s
256.629 s
(256.629) s
14,061.701 $
18,224
131,808
18.224
2,920
29.480
(225.626) s
s
S
18,224
$
s
S
JufvIS
S 14,200,376
18,224
148.614
s
225,626
s 14.079.925
$
(1.031) s
77,896 s
131.808 $
-
120.461
$ 14.200,376
S
138,675
.
Mav-15
AOf-15
Iblar-IS
Fet>-1S
14,200,376
84,003 S
102,227
S
163,620 s
194,623
s
$
(132.617) $
(163,620) s
M94.6231
S 10.450.065 s 14.116,373 s 14.098.149
S 10,615.844
S
65,779
$
132.617
•
19,894
33,844
s
$
166.134
S
s
(2.307) s
92.776
155.134
s
$
s
19,894 s
(11,456) s
(44,590) s
-
$
$
S
S
s
s
19.894
3.437
35,111
96,692
6,339
31.003
s
s
5,183
$
33,844
s
s
$
$
$
Oec-15
s
251,358
s
448.329
$
(448.3291
15250.368
-
19,894
19,894
s
s
s
s
s
(11,580) $
(45.076) s
33.844
$
(2,918) s
96,776
s
160.945
160,945
-
19,894
3,566
36.625
100.861
15,501,716
271,251
482,173
$ 22.939,758
300,691
S
s
632,256
(482.173) $
16.230.464 $
s
$
s
(11,576) s
(45,061) s
33.844 s
(532.256)
22,639,067
-
•
19,894
29,439
19,894
29,439
(2.899) s
50,083
(786)
120.078
$
s
s
204,S62 S 1.849.981
S
160,762
S
204.662
$
-
S
•
s
s
19.894
3,562
36.677
100.730
s
29.439
4.532
46.443
125.147
6.866
33.844
s
s
6,813
33,844
s
$
50,083
$
S
s
s
s
Income Tax - Current
$
1,765
6,631
31,003
s
$
s
31,003
s
s
6,683
$
31,003
s
Earnings
Retum on Equity per WACO
s
48,416
48,416
s
i
55,606
55,534
66,634
s
55,319
$
55.175
s
57,665
55,319
s
s
55,175
s
67,666
60.151
60,073
s
$
74,635
s
s
s
60,073
55.391
s
s
60,151
s
55J247
55.247
s
$
56,462
55.462
66.391
66.606
s
$
s
s
hlACRS
s
95,035
s
95,035
s
95,036
s
95.036
s
95.036
s
95.035
s
95.035
s
95.035
s
103.744
s
103.744
s
103.744
s
153,523
s
234.911
96.650
160.762
Income Tax - Deferred
s
$
(16,416)
(63,893)
429
74,635
Potomac Electric Power Company - Maryland
201S Grid Rasihency Charga Rate Design
Distrbution Oemattd/Energy Revenue Requvwnents - per Case No 9336 CompliarKe Filing
TOTAL
Proposed Oemand/Energy Charge Recovery
S
347.386.371
S
157.973.647
$
24.786.570
S
15.466.865
S
97.087.372
S
1,742.925
S
22.279.015
S
2,842.908
S 20.377,007
S
841,277
$
131.999
$
82.368
$
517,032
$
9,282
$
118.645
$
15,140
$
(1,078)
S
S
2.812.454
S
1.614,853
$
402.954
108,516 S
(7,726) $
14,978
$
8.599
$
2.146
has been updated
Revenue Allocation; Grid Resiliency Ctwrge
Revenue Requirements
Forecasted 2015 6RC Revenue Reqwrement (Schedule 2}
1,849.981
(131,708)
2014 GRC Oeferrtf Plus Interest (SctwcMe 1)
Total Revenue Requirement
1.718.273
Rate Ctass Revenue Requirement
Priofity Feeders
$
$
Total Reverwe Requirement
$
(S9.894) $
(9.398) $
S
$
.
781.383
$
122.602
$
(5.864) $
(36,810) $
$
$
.
76.504
$
480,222
$
(661) $
-
8.621
$
S
(8.447) $
-
110.198
$
.
S
$
14.062
$
.
100.791
$
$
(1.066) $
(612) $
$
$
-
13.911
$
7,987
$
(153)
-
1.993
Class Bilino Determinants aid Rtte Calculation
11.849,574
Demand (kW) Max
$0.0405
Demand (S/kW) Max
Eiwrgy (kWh)
4.981.972,755
754,683,821
$0.00018
$0 00016
aHing
Estimated
GRC Rate
Determinants
Energy*
($/kVWi)
Energy ($/kWhO
Service Claseificalion-Outdoor LigMing T'OL*) Rate Design
Proposed
Proposed
Proposed
Rate
Revenue •lamp per monlft)
3
175 watt
5.767
4,238,745
$0.00017 s
721
S
0.01
4
250 watt
5.281
5.545,050
$0.00017 $
943
s
0.01
400 watt
20.826
34.987.680
$0.00017 $
5.948
s
0.02
44,771,475
s
7,611
S
* Estmated Ertergy 3 Lamp Size in Wetls/1000 x Number of Lamps x 4200 hours
733,937
$0.0192
3.620,769
$0.0286
840
$16.56
$0.00011
Electric Vehilce Service S^dute EV
Distribution
$0.0435
69,608.486
Outdoor Uifhtine Service Schedule OL
2
2.532.069
S0.00017
Temporary Service Schedule T
Delivery Service
$0.0375
442.948,878
* GS-LV includes:
1
230.016
16,548,355
$0.00012
Schedule 4
Page 1 of 2
Month
Month
Month
1
2
3
Jan-14
Feb-14
Mar-14
Month
Month
4
Apr-14
Month
6
7
Jun-14
Jti-14
Month
Month
Month
S
May-14
8
9
Aug-14
Sep-14
Month
Month
Month
10
11
12
Oct-14
Nov-14
Dec-14
Exoendlture and ClosinfLSchedule
S
CWIP Beginning Balance
U264
696.053
15 23
14986
541,550
15 23
15114
1,062.416
15 23
14240
207,902
13 20
15023
662,147
13 20
15253
214,193
430,000
13 20
1,184,870
659,487
1,625,254
1.022,579
172,484
16 23
14288
15047
14270
15048
14048
14913 $
15
7.095 S
179,468 $
563,996 $ 1,761,476
S 4.631,922
S 5,220,053
$ 5.564,683
S 4,369,313
S 5,063.523 S 5,083,846 S 4,609,915
$ 5,276,096
S
S
571,784
S
1.419.108
S 1,198.328
S
S
22
15
22
16
23
15
23
13 20
$
Capex
172.392
$
392.583
$ 1.260,223
S 2.952,665
2,099.044
1,043,662
S 1,811.137
S 1.159.975
112,361
7.63*
AFUDC
$
Closings
CWIP Ending Balance
S
>
8,074
179.488 $
563,996
•
82.239
S
1,510,914
$
227,154
$
2.614.477
$
504,119
$
1,023.336
8 2.285.068
$
493.794
$ 1.703.925
S 1,761,476
$
62.743
$ 4.631.922
$
S
5,220,053
S 5,564,683
$
4,369.313
S 5,063.523
$
5,083,846
S 4,609,915
$ 5.276,096
S 3.684.532
S
$
178
$
1,440
i
S
5,068
i
<
Book Duraclrtlon
k/lontf)
Priorttv Feeder
Depreciation Rate
1.54%
1
2
10.361428
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
6
63
2.818
7,625
Schedule 4
Page 2 of 2
Month
Month
Month
Month
Month
Month
Month
Month
Month
Month
Month 1
Month
13
14
15
16
17
18
19
20
21
22
23
Jao-IS
Feb-15
Mar-15
Apr-15
May-is
Jun-15
JU-15
Aug-15
Sap-15
Oci-15
Nov-15
24I
Oec-15
FnpamflturB and Closing Sctiwlule
HI
•
CWIP Be^nlng Balance
s
14264 S
14986 $
15114 S
696.053
541,550
1,062,416
15
23
15
23
15
23
14246 S
207.902
662,147
214,193
430.000
13
20
13
20
$
s
$
$
s
13
20
s
15
22
s
15047 S 1,184,870
14270 $
659,487
15046 $ 1,625,254
14046 S 1,022,579
14913 S
172,464
16
23
$
$
s
s
s
$
$
15023 $
152S3 S
14288 S
16 22
16 23
15 23
13 20
C^)ex
7.63%
AFUDC
Closings
CWIP Endhg Balance
-
29,700
94,592
30,599
S
$
s
$
s
25,988
s
i
82,768
s
s
26.774
s
571
$
s
s
s
$
s
$
s
$ 3.684.532
180,103
s
s
.
-
-
.
.
24.641
179,532
$
S
-
.
s
-
s
s
-
-
-
-
-
21,561
157,091
1,645
$
s
s
s
$
$
$
s
s
336,638
$
$
S
S
s
77,339
60,172
i
i
$
77,339
60,172
S
$
77,339
60,172
118,046
25.988
82.766
26.774
53,750
$
118,046
$
118,0^
$
118,046
s
25,988
$
25,988
s
25,986
s
82,768
26,774
s
s
82,768
26,774
53,750
148.109
82,436
s
$
82,768
26.774
53.750
148.109
203,157
s
s
s
s
s
1,013,720
16,123
$
s
3,058,732
.
82,436
•
113,620
21,561
662,454
4,260
.
1.005,553
$
$
s
s
$
s
$
s
s
s
$
113,620
21,561
1,013,720
9,616
.
2,028,889
s
s
82,436
203,157
113,620
21.561
s
s
$
s
s
$
$
53,750
148,109
82.436
203,157
113,620
21.561
s
1.013.720
«
22.671
s
.
s
77,339
$
S
60,172
$
118,046
s
S
77,339
60,172
$
S
$
$
s
s
s
$
s
s
26,774
$
$
s
$
$
$
s
s
53,750
148,109
$
.
25,988
82,768
82,436
203,157
$
$
S
77,339
60,172
S
$
77,339
60,172
118,046
25.988
82,768
26.r7A
S
118.046
53,750
148,109
82,436
s
$
$
$
53,750
$
148.109
82,436
-
-
113.620
203,157
113,620
$
$
s
21.561
$
21.561
s
1,013.720
29.261
$
i
1.013.720
$
s
856,629
33.793
$
s
5,776.798
.
4,095,123
$
5.138,103
$
s
.
6.187,716
77,339
s
$
s
60,172
118,046
-
$
•
s
s
s
35.6S3
S
203,157
113,620
-
1,301.3^
s
s
s
$
$
$
$
-
•
53.750
148,109
82.436
203,157
113,620
s
856,629
$
39,454
$
i
6,672,681
.
$
S
s
$
s
s
$
s
s
s
$
$
s
$
$
$
s
77,339
60,172
$
$
$
-
118.046
S
-
.
-
-
-
148,109
s
s
i
$
i
-
-
-
-
-
-
-
-
203,157
s
113.620
-
$
-
720.443
$
44,719
s
.
7,438,042
.
s
$
-
-
-
7.438.042
-
Book Deoraclatlon
IMonth
Priortty Fewters
Depredation Rate
1.54%
10.361428
S
2
10
10
10
10
10
10
$
$
10
10
10
s
10
10
10
3
S1
81
81
81
81
81
S
81
81
81
S
81
81
81
1
4
106
106
106
106
106
106
S
106
106
106
1,939
1,939
1,939
1.939
1.939
1,939
1.939
$
1,939
1,939
1.939
292
292
292
292
292
$
S
i
106
1.939
106
1.939
292
106
5
6
292
292
292
292
292
292
7
3.355
3,355
3,355
3,355
3,355
3,355
S
3,355
3.355
3.355
3,355
8
647
647
647
647
647
647
$
647
647
647
647
3.355
647
9
1,313
1,313
1,313
1,313
1,313
2,933
2,933
2,933
1.313
2,933
1.313
2,933
1,313
2,933
1,313
2,933
$
$
1.313
10
1,313
2,933
2,933
2,933
S
11
634
634
634
12
2,187
4,728
2,187
4.728
2,187
4,728
13
S
S
634
634
634
2,187
4,728
2,187
4,728
2,187
4,728
S
S
3,355
647
1,313
2.933
2.933
634
634
634
634
634
634
2,187
2,187
2,187
4,728
4,728
4,728
2,187
4,728
2.187
4,728
2,187
4,728
1,670
1,670
1.670
1,670
S
S
s
$
$
s
$
14
15
16
17
18
19
20
-
21
$
s
22
23
•
$
18.224
$
24
s
25
s
18.224
t
18.224
$
18.224
$
18.224
>
18.224
$
18.224
$
18.224
$
19.894
$
19.894
S
19,894
$
29.439
schedules
Pepco MD
Weighted
Capital Structure
Weight
Rate
Bate
Long Term Debt
51.11%
5.96%
3.05%
48.89%
9.36%
Common Stock
Total
100.00%
4.58%
7.63%
EfrecfiveJ(^4.2014
Weighted
Capital Structure
WeiaM
Rate
Rate
Long Term Debt
50.82%
5.66%
2.88%
49.18%
9.62%
Common Stock
Total
100.00%
4.73%
7.61%
Schedule 6
Pepco MD
Revenue Conversion Factor
(2)
(1)
(3)
Line
Particulars
No.
1
Factor
Tax Rates
2
Federal Income Tax
0.35000
3
State Income Tax
0.08250
4
5
6
Gross Receipts Tax
Regulatory Tax
0.02000
0.002154
7
8
9
Conversion Factor
Revenue Increase
10
Gross Receipts Tax
Regulatory Tax
0.02000
0.00000
12
0.00215
0.00000
13
Total Other Tax
0.02215
0.00000
15
State Taxable Income
0.97785
1.00000
16
State Income Tax
0.08067
0.08250
18
Federal Taxable Income
0.89717
0.91750
19
Federal Income Tax
0.31401
0.32113
Total Additional Taxes
0.41684
0.40363
Increase in Earnings (1 - additional taxes)
0.58316
0.59638
Revenue Conversion Factor {1/lncr in Earnings)
1.71479
1.67680
11
14
17
20
21
22
23
24
25
CERTIFICATE OF SERVICE
I hereby certify that on behalf of Potomac Electric Power Company, the forgoing Annual
Report of the Grid Resiliency Accelerated Priority Feeder Project was sent by hand delivery,
postage prepaid and/or electronic mail on this 13^ day of February 2015 to the below-listed
parties in Case No. 9311.
Public Service Commission
Leslie M. Romine, Esq.
Maryland Public Service Commission
6 St. Paul Street, 16th Floor
Baltimore, MD 21202
6 St. Paul Street, 17th Floor
Baltimore, MD 21202
E-mail: agarafalo@psc.state.md.us
E-mail: lromine@Dsc.state.md.us
Heather R. Cameron
Frann G. Francis Esq.
Apartment and Office Building Association
of Metropolitan Washington
Annette B. Garofalo
Office of General Counsel
U.S. General Services Administration
1275 First Street, NE
Washington, DC 20417
Email: heather.cameron@gsa.gov
1050 17th Street, N.W., Suite 300
Washington, D.C. 20036
Gregory T. Simmons
Office of People's Coimsel
Anne L. Johnson
6 St. Paul Street, Suite 2102
Baltimore, MD 21202
6 St. Paul Street, Suite 2102
Baltimore, MD 21202
E-mail: GregorvS@opc.state.md.us
E-mail: annei@opc.state.md.us
Michael A. Dean
Ronald Herzfeld
Office of People's Counsel
Public Service Commission
Office of People's Counsel
6 St. Paul Street, 16th Floor
6 St. Paul Street, Suite 2102
Bahimore, MD 21202
Baltimore, MD 21202
E-mail: mdean@psc.state.md.us
Cynthia B. Walters
Mayor and Council of Rockville
111 Maryland Avenue, 3rd Floor
E-mail: ronh@.opc.state.md.us
Lloyd J. Spivak, Esq.
Public Service Commission
Rockville, MD 20850
6 St. Paul Street, 16th Floor
Baltimore, MD 21202
E-mail: cwaters@,rockvillemd.gov
E-mail: lspivak@psc.state.md.us
Payman Tehrani
Mayor and Council of Rockville
111 Maryland Avenue, 3'^'^ Floor
Debra Yerg Daniel
Mayor and Council of Rockville
111 Maryland Avenue, 3rd Floor
Rockville, MD 20850
Rockville, MD 20850
Email: ptehrani@rockvillemd.eov
E-mail: ddaniel@.rockvillemd.gov
Norman Knopf
William Leibovici
Town of Somerset
Law Office of William Leibovici
401 East Jefferson Street, Suite 206
Rockville, MD 20850
Baltimore, MD 21239-1320
802 Oak Hill Court
Email: knopf@knopf-brown.com
Jeffrey Slavin
Catherine Pickar
Town of Somerset
Town of Somerset
4510 Cumberland Avenue
4915 Dorset Avenue
Chevy Chase, MD 20815
Email: mavor@townofsomerset.com
Chevy Chase, MD 20185
Email: cpickar@townofsomerset.com
Daniel W. Hurson
Brent A. Bolea
c/o Maryland Energy Administration
c/o Maryland Energy Administration
60 West Street. Suite 300
60 West Street. Suite 300
Annapolis, MD 21401
Annapolis, MD 21401
Email: dhurson@energv.state.md.us
Email: bbolea@,energv.state.md.us
Abbe Lynn Milstein, Esq.
Rockville, MD 20852
Claire Morisset. Esq.
2421 Seminary Road
Silver Spring, MD 20910
Email: Powerupmontco@gmail.com
Email: clairemdc@verizon.net
N. Lynn Board
City Attorney
Robert Loube, Ph.D
11704 Ibsen Drive
10601 Cavalier Drive
31 S. Summit Avenue
Silver Spring, MD 20901
Gaithersburg, MD 20877
Email: lboard@gaithersburgmd.gov
Email: bobioube@,earthlink.net
Lisa Brennan, Esquire
Montgomery County, Maryland
John P. Markovs, Esquire
Montgomery County, Maryland
101 Monroe Street, Third Floor
101 Monroe Street, Third Floor
Rockville, MD 20850
Rockville, MD 20850
Email:
lisa.brennan@.montgomervcountvmd.gov
iohn •markovs@montgomervcountvmd.gov
Bion C. Ostrander
Ralph Smhh
Ostrander Consulting
1121 S. W. Chetopa Trail
Topeka, KS 66615-1408
Larkin & Associates PLLC
E-mail: bionostrander@cox.net
E-mail: RSmithLA@aol.com
15728 Farmington Road
Livonia, MI 48154
Dawn Bisdorf
Larkin & Associates PLLC 15728
Farmington Road
Livonia, MI 48154
E-mail: Dawn.Bisdorf@gmail.com
Douglas E. Micheel