The Narragansett Electric Company d/b/a National Grid · Substation Modelling Substation assets are kept in the Cascade system but ... 514.02 RTB Distribution ESB DB & RAC Software

The Narragansett Electric Company d/b/a National Grid INVESTIGATION AS TO THE PROPRIETY OF PROPOSED TARIFF CHANGES Appendices and Workpapers of: Power Sector Transformation Panel Book 3 of 3 REDACTED November 27, 2017 Submitted to: Rhode Island Public Utilities Commission RIPUC Docket No. 4770 Submitted by:

W

orkpaper 3.1

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770

Witness: Sheridan

Workpaper 3.1,

Modern Grid Costs

Rhode Island Only Deployment Scenario

1


Workpaper 3.1 - Modern Grid Costs for Rhode Island Only Deployment Scenario

Page 1 of 15

WORKPAPER 3.1 – MODERN GRID COSTS FOR RHODE ISLAND ONLY DEPLOYMENT

SCENARIO

While National Grid’s affiliates in both Massachusetts and New York have proposed similar grid modernization projects, these plans have not yet been approved by the applicable regulatory agencies. Therefore the Company is presenting two scenarios of deployment: a Rhode Island only deployment scenario presented in Workpaper 3.1 and a multi-jurisdiction deployment scenario presented in Workpaper 3.2. It should be noted that the Company is presenting only the multi-jurisdiction deployment scenario for the DSCADA and ADMS project.1

1. SYSTEM DATA PORTAL

2. FEEDER MONITORING SENSORS

3. CONTROL CENTER ENHANCEMENTS

3.1 DSCADA AND ADMS

See Workpaper 3.2 – Modern Grid Costs for Multi‐Jurisdiction Deployment Scenario.

1 The Company operates a common distribution control center for its Rhode Island and Massachusetts operations, so a coordinated deployment with Massachusetts is the only feasible and cost effective deployment option.

System Data Portal Cash FlowDescription FY19 FY20 FY21 FY22 FY23

Data Portal ‐ Labor

Capital ‐$ ‐$ ‐$ ‐$ ‐$

Expense 69,000$ 690,000$ 690,000$ 690,000$ ‐$

Data Portal ‐ Website Setup & Hosting

Capital ‐$ ‐$ ‐$ ‐$ ‐$

Expense 10,000$ 10,000$ 10,000$ 10,000$ ‐$

Feeder Monitoring Sensors Cash FlowDescription FY19 FY20 FY21 FY22 FY23

Rhode Island Deployment 0% 20% 20% 20% 20%

Circuits 0 26 26 26 26

Sensors Unit Cost Count Total Cost

Feeder Monitor / Sensors (Installed Cost) 16,700$ 133 2,221,100$ ‐$ 434,200$ 434,200$ 434,200$ 434,200$

Communications Equipment 800$ 133 106,400$ ‐$ 20,800$ 20,800$ 20,800$ 20,800$

Capex ‐ Total 17,500$ 2,327,500$ ‐$ 455,000$ 455,000$ 455,000$ 455,000$

Opex ‐$ ‐$ 5,000$ 10,000$

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3.2 REMOTE TERMINAL UNIT (RTU) SEPARATION

3.3 GIS DATA ENHANCEMENT (IS)

RTU Separation Cash FlowDescription FY19 FY20 FY21 FY22 FY23


RTU Separation Unit Cost Count Total Cost

New RTU 374,000$ 3 1,122,000$ ‐$ 373,626$ 623,832$ 124,542$ ‐$

RTU Reconfiguration 10,000$ 59 590,000$ ‐$ 196,470$ 328,040$ 65,490$ ‐$

Capex ‐ Total 1,712,000$ ‐$ 570,096$ 951,872$ 190,032$ ‐$

Opex ‐$ 60,000$ 60,000$ 60,000$ ‐$

GIS Data Enchancement Cash Flow ($M)

Yr 1 Yr 2 Yr 3 Yr 4 Yr 5

Description Category Type FY 19 FY 20 FY 21 FY 22 FY 23

512.01 Cost of Internal Resources Opex Labor 2.44$ ‐$ ‐$ ‐$ ‐$

512.02 Cost of Project Management Opex Labor 0.61$ ‐$ ‐$ ‐$ ‐$

Total 3.05$ ‐$ ‐$ ‐$ ‐$

GIS Data Enchancement Calculations

Description / Calculation Type Category Value ($M)

Number of Internal Resources 11

x Months in a year 12

x Working Days per month 21

x Working Hours per day 8

x FTE Internal Hourly IS Rate 100.00$

x Implementation Duration 1.0

512.01 = Cost of Internal Resources Labor Opex 2.22$

Cost of Internal Resources 2.22$

x Project Management Percentage 25%

512.02 = Cost of Project Management Labor Opex 0.55$

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3.4 GIS DATA ENHANCEMENT (NON-IS)

GIS Data Enhancment (Non‐IS) Cash Flow ($M)Description FY19 FY20 FY21 FY22 FY23


Capex ‐ Total ‐$ ‐$ ‐$ ‐$ ‐$

Opex ‐$ ‐$ 1.03$ 1.03$ 1.03$

GIS Data Enhancement (Non‐IS) Calculations

Project Element Description RI Estimate

DG

This effort will focus on the DG data model and functionality in GIS to ensure that

the system will be capable of supplying the information required by DSIP

investments. Beyond the system review and development, full population of DG

locations and attributes will be completed.

$32,778

General Data Collection

This effort is focused on improving data quality of existing data through leveraging

issues found during model builds, operating knowledge and known areas of

concern. The intent of this effort is to eliminate errors related to network

topology, attribute level inconsistencies and to apply additional system

validations to drive improved data quality moving forward.

$1,060,102

New Attributes

Will be made available and where it will be stored will be developed and

migration or creation of this data will be completed. Additionally, validations and

cross system keys will be established to drive quality and synchronization.

$454,365

Networks

To address known needs related to modelling downtown GIS networks this effort

would focus on creating an underground focused data model, population of

available data (including potential field checks) and integration of inspections

with GIS for enhancing data quality moving forward.

$845,169

Secondary

GIS currently does not fully model secondary systems. This effort would be a

multi‐year effort to fully populate the system. Additional considerations will be

updating connect model export techniques to get the data to downstream

systems, including ADMS.

$481,865

Substation Modelling

Substation assets are kept in the Cascade system but only peripherally modelled

in GIS. This effort would interface these systems – creating a GIS substation data

model that incorporates network connectivity considerations between

Transmission and Distribution to provide data that will be used to inform ADMS

and load flow planning models

$93,737

Connected Model Export

This effort will seek to replace or enhance current capabilities utilized to export

information from GIS to downstream systems including CYME, OMS and ADMS.

The current process is highly customized but very use specific and does not meet

emerging and future needs.

$114,751

Opex ‐ Total $3,082,767

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4. OPERATIONAL DATA MANAGEMENT

4.1 ENTERPRISE SERVICE BUS (ESB)

ESB Cash Flow ($M)


# Description Category Type FY 19 FY 20 FY 21 FY 22 FY 23

514.01 CAPEX Distribution ESB DB & RAC Software Capex NonLabor ‐$ 1.55$ ‐$ ‐$ ‐$

514.02 RTB Distribution ESB DB & RAC Software RTB NonLabor ‐$ ‐$ 0.08$ 0.08$ ‐$

514.03 Refresh Distribution ESB DB & RAC Software Capex NonLabor ‐$ ‐$ ‐$ ‐$ ‐$

514.04 CAPEX Distribution ESB MiddleWare Capex NonLabor ‐$ ‐$ 3.48$ ‐$ ‐$

514.05 RTB Distribution ESB MiddleWare RTB NonLabor ‐$ ‐$ ‐$ 0.18$ ‐$

514.06 Refresh Distribution ESB MiddleWare Capex NonLabor ‐$ ‐$ ‐$ ‐$ ‐$

514.07 CAPEX Distribution ESB SW/MW Installation Capex Labor ‐$ 1.71$ 1.71$ ‐$ ‐$

514.08 OPEX Distribution ESB SW/MW Installation Opex Labor ‐$ 0.28$ 0.28$ ‐$ ‐$

514.09 RTB Distribution ESB SW/MW Support RTB Labor ‐$ ‐$ 0.30$ 0.60$ ‐$

514.10 Refresh Distribution ESB SW/MW Capex Labor ‐$ ‐$ ‐$ ‐$ ‐$

514.11 RTB Cloud & Managed Services RTB NonLabor ‐$ 0.16$ 0.16$ 0.16$ ‐$

514.12 CAPEX Comprehensive Integration Services Capex Labor ‐$ 2.24$ 3.73$ 1.49$ ‐$

514.13 OPEX Comprehensive Integration Services Opex Labor ‐$ 0.36$ 0.60$ 0.24$ ‐$

514.14 RTB Comprehensive Integration Services RTB Labor ‐$ ‐$ 0.53$ 0.79$ ‐$

Total ‐$ 6.30$ 10.87$ 3.54$ ‐$

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ESB Calculations

Description/Calculation Category Type Value ($M)

DB & RAC Total License Cost before May'17 1,191,754$

514.01 = CAPEX Distribution ESB DB & RAC Software Capex NonLabor 1.19$

DB & RAC Annual S&M 79,054$

514.02 = RTB Distribution ESB DB & RAC Software RTB NonLabor 0.08$


x ESB refresh cost reduction 50%

514.03 = Refresh Distribution ESB DB & RAC Software Capex NonLabor 0.60$

MW Total License Cost before Nov'17 2,674,031$

514.04 = CAPEX Distribution ESB MiddleWare Capex NonLabor 2.67$

MW Annual S&M 177,378$

514.05 = RTB Distribution ESB MiddleWare RTB NonLabor 0.18$



514.06 = Refresh Distribution ESB MiddleWare Capex NonLabor 1.34$

Total Labor CAPEX Cost Estimate 2,856,000$

514.07 = CAPEX Distribution ESB SW/MW Installation Capex Labor 2.86$

Total Labor OPEX Cost Estimate 504,000$

514.08 = OPEX Distribution ESB SW/MW Installation Opex Labor 0.50$

RTB Labor Costs 600,000$

514.09 = RTB Distribution ESB SW/MW Support RTB Labor 0.60$

CAPEX Distribution ESB SW/MW Installation 2.86$

+ OPEX Distribution ESB SW/MW Installation 0.50$


514.10 = Refresh Distribution ESB SW/MW Capex Labor 1.68$

Monthly Cloud Costs w/Managed Service included 13,486$


514.11 = RTB Cloud & Managed Services RTB NonLabor 0.16$

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4.2 DATA MANAGEMENT AND ANALYTICS

ESB Calculations


Total Hours for Large Integrations 11520

+

Total Hours for Medium Integrations 18640

+

Total Hours for Small Integrations 32880

= Total Hours for ALL Integrations 63040

Total External Costs 6.05$

+

Total Internal Costs 1.26$

= Total ESB Costs 7.31$

Total ESB Costs 7.31$

x CAPEX Allocations 85%

514.12 = CAPEX Comprehensive Integration Services Capex Labor 6.22$


x OPEX Allocations 15%

514.13 = OPEX Comprehensive Integration Services Opex Labor 1.10$


x System Maintenance Costs % 10%

= Total YOY System Maintenance Cost 0.73$

+ Platform Support from ESB/CIM 0.22$

514.14 = RTB Comprehensive Integration Services RTB Labor 0.95$

Data Lake Cloud Hosting Cash Flow ($M)

Yr ‐1 Yr ‐2 Yr ‐3 Yr ‐4 Yr ‐5

# Description Category Type

FY19 FY20 FY21 FY22 FY23

517.01 CAPEX Development Data Lake Opex NonLabor ‐$ 0.02$ 0.02$ 0.02$ 0.02$

517.02 CAPEX QA Data Lake Opex NonLabor ‐$ 0.04$ 0.04$ 0.04$ 0.04$

517.03 CAPEX Production Data Lake Opex NonLabor ‐$ 0.14$ 0.33$ 0.51$ 0.60$

517.04 CAPEX Dashboard Environment Opex NonLabor ‐$ 0.32$ 0.32$ 0.32$ 0.32$

517.05 RTB Platform Maintenance & Support RTB Labor ‐$ ‐$ 0.50$ 0.75$ 0.75$

517.06 CAPEX Platform Setup Capex Labor ‐$ 1.39$ ‐$ ‐$ ‐$

517.07 OPEX Platform Design Opex Labor ‐$ 0.32$ ‐$ ‐$ ‐$

Total ‐$ 2.24$ 1.21$ 1.64$ 1.73$

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Data Lake Cloud Hosting Calculations

Description/Calculation Type Category Value ($M)

Development Data Nodes 29,940$

+ Development Master Nodes 18,626$

+ Development Edge Nodes 10,241$

517.01 = CAPEX Development Data Lake NonLabor Opex 0.02$

QA Data Nodes 72,046$

+ QA Master Nodes 29,526$

+ QA Edge Nodes 18,626$

517.02 = CAPEX QA Data Lake NonLabor Opex 0.04$

Production Data Nodes 882,196$

+ Production Master Nodes 32,196$

+ Production Edge Nodes 19,979$

x Number of Production DR Envts. 2

+ Production Archival Storage 16,080

517.03 = CAPEX Production Data Lake NonLabor Opex 0.63$

Number of Production DR Envts. 2

x Production Dashboard Environment 81,584$

+ Development Dashboard Environment 63,092$

+ QA Dashboard Environment 63,092$

517.04 = CAPEX Dashboard Environment NonLabor Opex 0.29$

Platform Maintenance & Support 750,000$

517.05 = RTB Platform Maintenance & Support Labor RTB 0.75$

Platform Build 1,210,000$

x Capex Platform Support 80%

x Travel 20%

517.06 = CAPEX Platform Setup Labor Capex 1.16$


x Opex Platform Support 20%

x Travel 20%

517.07 = OPEX Platform Design Labor Opex 0.29$

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PI Historian Cash Flow ($M)

Yr ‐ 1 Yr ‐ 2 Yr ‐ 3 Yr ‐ 4 Yr ‐ 5

# Description Category Type FY19 FY20 FY21 FY22 FY23

515.02 OPEX PI Historian EA License Opex NonLabor ‐$ ‐$ 2.00$ 2.00$ ‐$

515.04 CAPEX Server Costing Capex NonLabor ‐$ 0.08$ ‐$ ‐$ ‐$ 515.05 CAPEX Hardware Installation Cost Capex NonLabor ‐$ 0.05$ ‐$ ‐$ ‐$

515.06 RTB Hardware Support Cost RTB Labor ‐$ 0.03$ 0.03$ 0.03$ 0.03$

515.07 RTB Backup Storage Cost ‐ PI Servers RTB NonLabor ‐$ 0.02$ 0.02$ 0.02$ 0.02$

515.08 CAPEX Application Installation Cost Capex Labor ‐$ 0.32$ ‐$ ‐$ ‐$

515.09 RTB Application Maintenance & Support RTB Labor ‐$ ‐$ ‐$ ‐$ ‐$

Total ‐$ 0.50$ 2.05$ 2.05$ 0.05$

PI Historian Calculations


PI EA License Cost Opex 2,000,000$

515.02 = OPEX PI Historian EA License NonLabor Opex 2.00$

Total Number of Servers 8

x Hardware Cost per Server 10,000$

515.04 = CAPEX Server Costing NonLabor Capex 0.08$

Installation Cost per Server (CSC) 6,364$

x Total Number of Servers 8

515.05 = CAPEX Hardware Installation Cost NonLabor Capex 0.05$

Annual Server Support Cost (CSC Gold Support) 3,673$

x Total Number of Servers 8

515.06 = RTB Hardware Support Cost Labor RTB 0.03$

Cost per GB 0

x Number of Storage Backups (CSC) 2

x PI Storage (GBs) 3,000$


x Servers that require storage backup (PI) 2

515.07 = RTB Backup Storage Cost ‐ PI Servers NonLabor RTB 0.02$

Development Hours 2665

x FTE Internal Hourly IS Rate 100$

Total Development Hours 0.27$

+ Travel 20%

515.08 = CAPEX Application Installation Cost Labor Capex 0.32$

PI Historian (Maintenance & Support) FTE 1


x Working Days per Month 21

x Working Hours per Day 8


515.09 = RTB Application Maintenance & Support Labor RTB 0.20$

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Page 9 of 15

Information Management Cloud Analytics Cash Flow ($M)



516.01 Utility Data Model License Capex NonLabor ‐$ ‐$ ‐$ ‐$ 0.48$

516.02 Utility Data Model License Support Opex NonLabor ‐$ ‐$ ‐$ ‐$ ‐$

516.03 Information Management License Capex NonLabor ‐$ 0.43$ ‐$ ‐$ ‐$

516.04 Information Management License Support Opex NonLabor ‐$ ‐$ 0.07$ 0.07$ 0.07$

516.05 Data Governance License Capex NonLabor ‐$ 0.10$ ‐$ ‐$ ‐$

516.06 Data Governance License Support Opex NonLabor ‐$ 0.08$ 0.08$ 0.08$ 0.08$

516.07 Data Quality Development Capex Labor ‐$ 0.49$ 1.21$ 0.73$ ‐$

516.08 Data Ingestion Development Capex Labor ‐$ 1.28$ 3.21$ 1.92$ ‐$

516.09 Dashboard Development Capex Labor ‐$ 0.11$ 0.28$ 0.17$ ‐$

516.1 CAPEX Platform Design & Development Capex Labor ‐$ 0.23$ 0.58$ 0.35$ ‐$

516.11 Platform Support & Maintenance RTB Labor ‐$ ‐$ 1.18$ 1.42$ 1.78$

516.12 CAPEX Visualization License Cost Capex NonLabor ‐$ 1.90$ ‐$ ‐$ ‐$

516.13 Opex Visualization License Cost Opex NonLabor ‐$ 0.02$ ‐$ ‐$ ‐$

516.14 CAPEX IS Visualization License Cost Capex NonLabor ‐$ 0.18$ 0.15$ 0.15$ 0.15$

516.15 Opex IS Visualization License Cost Opex NonLabor ‐$ ‐$ 0.01$ 0.01$ 0.01$

Total ‐$ 4.84$ 6.77$ 4.90$ 2.57$

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Information Management Cloud Analytics Calculations

Description/Calculation Category Type Value

Utility Data Model License 366,746.48$

516.01 = Utility Data Model License Capex NonLabor 0.37$

Utility Data Model License Support 73,349.30$

516.02 = Utility Data Model License Support Opex NonLabor 0.07$

Information Management License 331,457.37$

516.03 = Information Management License Capex NonLabor 0.33$

Information Management License Support 66,291.47$

516.04 = Information Management License Support Opex NonLabor 0.07$

Data Governance License 77,142.00$

516.05 = Data Governance License Capex NonLabor 0.08$

Data Governance License Support 77,142.00$

516.06 = Data Governance License Support Opex NonLabor 0.08$

Data Quality Dev Hours 16857

x FTE External (subcontractor; non‐specialist) Hourly IS Rate 100$

x Travel 20%

516.07 = Data Quality Development Capex Labor 2.02$

ETL Dev Hours 44547


x Travel 20%

516.08 = Data Ingestion Development Capex Labor 5.35$

Dashboard Dev Hours 3851


x Travel 20%

516.09 = Dashboard Development Capex Labor 0.46$

Platform Development Effort 1,198,000$

x Capex Allocation 80%

516.10 = CAPEX Platform Design & Development Capex Labor 0.96$

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5. TELECOMMUNICATIONS


Description/Calculation Category Type Value


x Opex Allocation 20%

516.16 = OPEX Platform Design & Development Opex Labor 0.24$

Platform Support & Maintenance 1,782,000$

516.11 = Platform Support & Maintenance RTB Labor 1.78$

Visualization License ‐ Business 7,934,000$

NY Cost Factor 18%

516.12 = CAPEX Visualization License Cost Capex NonLabor 1.46$

Visualization License Maintenance ‐ Business 115,000$

NY Cost Factor 18%

516.13 = Opex Visualization License Cost Opex NonLabor 0.02$

Tableau Desktop License 1,999$

+ Tableau Server License 1,000$

+ Alteryx Designer License 5,195$

x Number of Licenses 10

+

Alteryx Server License 58,500$

x Number of Alteryx Servers 1

516.14 = CAPEX IS Visualization License Cost Capex NonLabor 0.14$




x Tableau Server Maintenace Cost 25%

516.15 = Opex IS Visualization License Cost Opex NonLabor 0.01$

Telecom Non‐Inflated Cash Flow ($M)



513.08 CAPEX Corporate Backbone Expansion Capex NonLabor ‐$ 0.06$ 0.03$ 0.03$ ‐$

513.09 RTB Corpate Backbone Expansion RTB NonLabor ‐$ ‐$ 0.18$ 0.27$ 0.36$

513.10 CAPEX IT/OT Backbone Expansion Capex NonLabor ‐$ 0.15$ 0.07$ 0.07$ ‐$

513.11 RTB IT/OT Backbone Expansion RTB NonLabor ‐$ ‐$ 1.62$ 2.43$ 3.24$

513.12 CAPEX IT/OT Mesh Network Backhaul Capex NonLabor ‐$ 0.10$ 0.05$ 0.05$ ‐$

513.13 RTB IT/OT Mesh Network Backhaul RTB NonLabor ‐$ ‐$ 0.15$ 0.23$ 0.30$

Total ‐$ 0.30$ 2.10$ 3.08$ 3.90$

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Telecom Calculations


SCI Implementation Cost 60,000$

+

Data Center Bandwidth Increase Cost 16,500$

x Number of circuits 2

513.08 = CAPEX Corporate Backbone Expansion Capex NonLabor 0.09$

Monthly SCI Service Cost 4,000$

x 0 0

+

Monthly Data Center Bandwidth Increase 15,000$



513.09 = RTB Corpate Backbone Expansion RTB NonLabor 0.36$

POPs Bandwidth Implementation cost 30,000$

x Number of Locations (POPs) 6

+

CSC Data Center Bandwidth cost 22,500$

x Number of connections 2

513.10 = CAPEX IT/OT Backbone Expansion Capex NonLabor 0.23$

Monthly cost of POP bandwidth 35,000$



+

Monthly cost of CSC bandwidth 30,000$



513.11 = RTB IT/OT Backbone Expansion RTB NonLabor 3.24$

Wireless gateway planning and configuration 50,000$

+

Stand up of wireless gateway 75,000$

x Number of gateways 1

+

Set up of CSC bandwidth and VRFs 25,000$

x Number of data center links 1

513.12 = CAPEX IT/OT Mesh Network Backhaul Capex NonLabor 0.15$

Monthly cost of wireless gateway 20,000$



+

Monthly cost of CSC data center link increase 5,000$



513.13 = RTB IT/OT Mesh Network Backhaul RTB NonLabor 0.30$

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6. CYBERSECURITY

SUMMARY ALL COSTS,

$1,000sSPENDING TYPE FY19 FY20 FY21 FY22 FY23

600 CAPEX $0 $13,844 $6,734 $4,427 $0

601 OPEX $0 $6,564 $2,685 $1,914 $0

602 RTB $0 $1,807 $1,539 $1,421 $1,927

603 CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $12,330

604 OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $33 $1,728

GRAND TOTAL $0 $22,216 $10,958 $7,795 $15,984

B_NETWORK SECURITY

SERVICESSPENDING TYPE FY19 FY20 FY21 FY22 FY23

600B CAPEX $0 $3,120 $1,442 $953 $0

601B OPEX $0 $427 $197 $130 $0

602B RTB $0 $446 $250 $193 $699

603B CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $1,532

604B OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $3,993 $1,889 $1,276 $2,232

C_DATA SECURITY


600C CAPEX $0 $656 $302 $199 $0

601C OPEX $0 $427 $197 $130 $0

602C RTB $0 $138 $108 $83 $83

603C CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $671

604C OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,221 $607 $412 $754

D_IDENTITY AND ACCESS

MANAGEMENSPENDING TYPE FY19 FY20 FY21 FY22 FY23

600D CAPEX $0 $4,214 $1,940 $1,281 $0

601D OPEX $0 $427 $197 $130 $0

602D RTB $0 $131 $131 $131 $131

603D CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $3,004

604D OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $1,568

TOTAL $0 $4,772 $2,268 $1,542 $4,703

E_THREAT AND

VULNERABILITY MANASPENDING TYPE FY19 FY20 FY21 FY22 FY23

600E CAPEX $0 $1,074 $494 $326 $0

601E OPEX $0 $427 $197 $130 $0

602E RTB $0 $83 $83 $83 $83

603E CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $1,456

604E OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,583 $774 $539 $1,538

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F_SECURITY OPERATIONS

CENTER SESPENDING TYPE FY19 FY20 FY21 FY22 FY23

600F CAPEX $0 $1,277 $588 $388 $0

601F OPEX $0 $427 $197 $130 $0

602F RTB $0 $89 $89 $89 $89

603F CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $624

604F OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $7 $7

TOTAL $0 $1,793 $873 $614 $719

G_HOST & ENDPOINT

SECURITY SERVSPENDING TYPE FY19 FY20 FY21 FY22 FY23

600G CAPEX $0 $523 $250 $170 $0

601G OPEX $0 $441 $210 $130 $0

602G RTB $0 $83 $83 $83 $83

603G CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $483

604G OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,047 $543 $383 $566

H_SECURITY POLICY

MANAGEMENT SESPENDING TYPE FY19 FY20 FY21 FY22 FY23

600H CAPEX $0 $523 $250 $170 $0

601H OPEX $0 $441 $210 $130 $0

602H RTB $0 $83 $83 $83 $83

603H CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $483

604H OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,047 $543 $383 $566

I_CRYPTOGRAPHY


600I CAPEX $0 $510 $235 $155 $0

601I OPEX $0 $427 $197 $130 $0

602I RTB $0 $162 $119 $83 $83

603I CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $503

604I OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $26 $153

TOTAL $0 $1,099 $551 $394 $740

J_CHANGE &

CONFIGURATION

MANAGE

SPENDING TYPE FY19 FY20 FY21 FY22 FY23

600J CAPEX $0 $257 $118 $78 $0

601J OPEX $0 $427 $197 $130 $0

602J RTB $0 $83 $83 $83 $83

603J CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $454

604J OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $767 $398 $291 $537

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K_SECURITY AWARENESS

& TRAININGSPENDING TYPE FY19 FY20 FY21 FY22 FY23

600K CAPEX $0 $0 $0 $0 $0

601K OPEX $0 $449 $152 $152 $0

602K RTB $0 $177 $177 $177 $177

603K CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

604K OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $626 $329 $329 $177

L_APPLICATION SECURITY


600L CAPEX $0 $969 $446 $295 $0

601L OPEX $0 $633 $91 $29 $0

602L RTB $0 $83 $83 $83 $83

603L CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $1,063

604L OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,686 $620 $407 $1,146

M_THIRD PARTY

ASSURANCE MANAGEMSPENDING TYPE FY19 FY20 FY21 FY22 FY23

600M CAPEX $0 $0 $0 $0 $0

601M OPEX $0 $753 $0 $565 $0

602M RTB $0 $83 $83 $83 $83

603M CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

604M OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $836 $83 $648 $83

N_REMOTE ACCESS


600N CAPEX $0 $720 $668 $411 $0

601N OPEX $0 $295 $458 $0 $0

602N RTB $0 $83 $83 $83 $83

603N CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $2,057

604N OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,097 $1,210 $494 $2,140

O_PRIVACY SERVICES SPENDING TYPE FY19 FY20 FY21 FY22 FY23

600O CAPEX $0 $0 $0 $0 $0

601O OPEX $0 $565 $188 $0 $0

602O RTB $0 $83 $83 $83 $83

603O CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

604O OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $648 $271 $83 $83

16

Workpaper 3.2


Witness: Sheridan

Workpaper 3.2

Modern Grid Costs for Multi-Jurisdiction Deployment Scenario

17


Workpaper 3.2 - Modern Grid Costs for Multi-Jurisdiction Deployment Scenario

Page 1 of 17

1

WORKPAPER 3.2 – MODERN GRID COSTS FOR MULTI-JURISDICTION DEPLOYMENT SCENARIO

While National Grid’s affiliates in both Massachusetts and New York have proposed similar grid modernization projects, these plans have not yet been approved by the applicable regulatory agencies. Therefore the Company is presenting two scenarios of deployment: a Rhode Island only deployment scenario presented in Workpaper 3.1 and a multi-jurisdiction deployment scenario presented in Workpaper 3.2. As can be seen in Table 1.1, many of the proposed Grid Modernization projects support multiple operating companies and significant cost synergies can be realized if these investments are coordinated across the operating companies.

Table 1.1: Grid Modernization Multi-Jurisdiction Deployment Cost Allocations

Total multi-jurisdiction project cost calculations are presented below. The Rhode Island portion of these costs can be obtained by multiplying these total multi-jurisdiction costs by the relevant Rhode Island Allocation factor presented in Table 1.1 above.

1. SYSTEM DATA PORTAL

No cost synergies can be realized for this project, so multi-jurisdiction deployment is not proposed. See Workpaper 3.1 – Modern Grid Costs for Rhode Island Only Deployment Scenario for project cost details.

2. FEEDER MONITORING SENSORS


New York Massachusetts Rhode Island

System Data Portal* x 512,318 100%Feeder Monitoring Sensors* x 512,318 100%Control Center Enhancements*

DSCADA & ADMS x 1,372,573 512,318 27%

RTU Separation x 512,318 100%GIS Data Enhancement (IS) x x 1,718,053 1,372,573 512,318 14%

GIS Data Enhancement (BR) x 512,318 100%Operational Data Management

Enterprise Service Bus x x 2,357,546 790,721 25%

Data Lake x x 2,357,546 790,721 25%

PI Historian x x 2,357,546 790,721 25%

Advanced Analytics x x 2,357,546 790,721 25%

Telecommunications x x 2,357,546 790,721 25%

Cybersecurity x x 2,357,546 790,721 25%

*Impacts electric customers only

National Grid Customers ImpactedRI AllocationGrid Modernization Project

RI-Only Scenario

Multi-Jursidiction

Scenario

18



Page 2 of 17

2

3. CONTROL CENTER ENHANCEMENTS

3.1 DSCADA AND ADMS

DSCADA and ADMS Cash Flow ($M)



509.01 Total Cost of IS Resources Labor Capex ‐$ 4.14$ 6.89$ 2.76$ ‐$

509.02 Total Cost of Business Resources Labor Capex ‐$ 1.77$ 2.95$ 1.18$ ‐$

509.03 Data Readiness Labor Capex ‐$ 0.09$ 0.15$ 0.06$ ‐$

509.04 Change Management Cost Labor Capex ‐$ ‐$ 0.10$ 0.15$ ‐$

509.05 Training Resources Labor Opex ‐$ ‐$ 0.33$ 0.49$ ‐$

509.06 Requirements Development (IS) Labor Opex 0.32$ ‐$ ‐$ ‐$ ‐$

509.07 Vendor Implementation Services Labor Capex ‐$ 1.44$ 1.08$ 1.08$ ‐$

509.08 Vendor Costs: Hardware and Software NonLabor Capex ‐$ 1.79$ 1.34$ 1.34$ ‐$

509.12 Requirements Development (Business) Labor Opex 1.28$ ‐$ ‐$ ‐$ ‐$ Total 1.60$ 9.23$ 12.85$ 7.06$ ‐$

19



Page 3 of 17

3

DSCADA and ADMS Calculations

Description / Calculation Type Category Value

Number of Internal IS Resources 4





x Implementation Duration 3

= Cost of IS Internal Resources 2.42$

Number of External IS Resources 5

x FTE External Daily IS Rate 250$

Months in a year 12

Working Days per month 21



= Cost of IS External Resources 7.56$

Cost of IS External Resources 7.56$

x Travel 20%

= Travel Costs for IS External Resources 1.51$

Cost of IS Internal Resources 2.42$

+ Travel Costs for IS External Resources 1.51$

+ Cost of IS External Resources 7.56$

509.01 = Total Cost of IS Resources Labor Capex 11.49$

Number of Internal Business Resources 5



x Working Hours per day 8x FTE Internal Hourly IS Rate 100


= Cost of Internal Business Resources 3.02$

Number of External Business Resources 1

x FTE External Daily IS Rate 250$





= Cost of Business SI Resources 1.51$

Cost of Business SI Resources 1.51$

x Travel 20%

= Travel Costs for External Business Resources 0.30$

Cost of Internal Business Resources 3.02$

+ Cost of Business SI Resources 1.51$

+ Travel Costs for External Business Resources 0.30$

+ Travel for Internal Business Resources 0.08$

509.02 = Total Cost of Business Resources Labor Capex 4.92$

20



Page 4 of 17

4

3.2 REMOTE TERMINAL UNIT (RTU) SEPARATION


DSCADA and ADMS Calculations

Description / Calculation Type Category Value (Total in $M)

Number of Field Devices 1248

x Data Readiness effort per Device 2.0

x Average Loaded Internal Hourly Rate 100$

509.03 = Data Readiness Labor Capex 0.25$

Change Management Cost 208,000.00

509.04 = Change Management Cost Labor Capex 0.21$

Training 749,000.00$

509.05 = Training Resources Labor Opex 0.75$

IS Resources Allocation 20%

Requirements Development 1,450,000.00$

509.06 = Requirements Development (IS) Labor Opex 0.29$

Vendor Implementation Services 3,000,000.00$

509.07 = Vendor Implementation Services Labor Capex 3.00$

Hardware Costs 3,120,000.00$

= Technology: Hardware 3.12$

+ 12‐month Warranty license fees 0.32$

509.08 = Vendor Costs: Hardware and Software NonLabor Capex 3.44$

Business Resources Allocation 80%

Requirements Development 1,450,000.00$

509.12 = Requirements Development (Business) Labor Opex 1.16$

21

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22



Page 6 of 17

6

4. OPERATIONAL DATA MANAGEMENT

4.1 ENTERPRISE SERVICE BUS (ESB)

ESB Cash Flow ($M)



514.01 CAPEX Distribution ESB DB & RAC SoftwaCapex NonLabor ‐$ 4.26$ ‐$ ‐$ ‐$

514.02 RTB Distribution ESB DB & RAC Software RTB NonLabor ‐$ ‐$ 0.31$ 0.31$ ‐$

514.03 Refresh Distribution ESB DB & RAC SoftwCapex NonLabor ‐$ ‐$ ‐$ ‐$ ‐$

514.04 CAPEX Distribution ESB MiddleWare Capex NonLabor ‐$ ‐$ 9.56$ ‐$ ‐$

514.05 RTB Distribution ESB MiddleWare RTB NonLabor ‐$ ‐$ ‐$ 0.71$ ‐$

514.06 Refresh Distribution ESB MiddleWare Capex NonLabor ‐$ ‐$ ‐$ ‐$ ‐$

514.07 CAPEX Distribution ESB SW/MW Installa Capex Labor ‐$ 1.71$ 1.71$ ‐$ ‐$

514.08 OPEX Distribution ESB SW/MW InstallatiOpex Labor ‐$ 0.28$ 0.28$ ‐$ ‐$

514.09 RTB Distribution ESB SW/MW Support RTB Labor ‐$ ‐$ 0.30$ 0.60$ ‐$

514.10 Refresh Distribution ESB SW/MW Capex Labor ‐$ ‐$ ‐$ ‐$ ‐$

514.11 RTB Cloud & Managed Services RTB NonLabor ‐$ 0.45$ 0.45$ 0.45$ ‐$

514.12 CAPEX Comprehensive Integration ServiCapex Labor ‐$ 2.24$ 3.73$ 1.49$ ‐$

514.13 OPEX Comprehensive Integration ServicOpex Labor ‐$ 0.36$ 0.60$ 0.24$ ‐$

514.14 RTB Comprehensive Integration Service RTB Labor ‐$ ‐$ 0.53$ 0.79$ ‐$

Total ‐$ 9.30$ 17.48$ 4.59$ ‐$

23



Page 7 of 17

7

ESB Calculations



514.01 = CAPEX Distribution ESB DB & RAC Software Capex NonLabor 3.28$

DB & RAC Annual S&M 314,753$

514.02 = RTB Distribution ESB DB & RAC Software RTB NonLabor 0.31$



514.03 = Refresh Distribution ESB DB & RAC Software Capex NonLabor 1.64$


514.04 = CAPEX Distribution ESB MiddleWare Capex NonLabor 7.36$

MW Annual S&M 706,235$

514.05 = RTB Distribution ESB MiddleWare RTB NonLabor 0.71$



514.06 = Refresh Distribution ESB MiddleWare Capex NonLabor 3.68$

Total Labor CAPEX Cost Estimate 2,856,000$

514.07 = CAPEX Distribution ESB SW/MW Installation Capex Labor 2.86$

Total Labor OPEX Cost Estimate 504,000$

514.08 = OPEX Distribution ESB SW/MW Installation Opex Labor 0.50$

RTB Labor Costs 600,000$

514.09 = RTB Distribution ESB SW/MW Support RTB Labor 0.60$

CAPEX Distribution ESB SW/MW Installation 2.86$

+ OPEX Distribution ESB SW/MW Installation 0.50$


514.10 = Refresh Distribution ESB SW/MW Capex Labor 1.68$

Monthly Cloud Costs w/Managed Service included 37,103$


514.11 = RTB Cloud & Managed Services RTB NonLabor 0.45$

24



Page 8 of 17

8

4.2 DATA MANAGEMENT AND ANALYTICS

ESB Calculations


Total Hours for Large Integrations 11520

+

Total Hours for Medium Integrations 18640

+

Total Hours for Small Integrations 32880

= Total Hours for ALL Integrations 63040

Total External Costs 6.05$

+

Total Internal Costs 1.26$

= Total ESB Costs 7.31$


x CAPEX Allocations 85%

514.12 = CAPEX Comprehensive Integration Services Capex Labor 6.22$


x OPEX Allocations 15%

514.13 = OPEX Comprehensive Integration Services Opex Labor 1.10$


x System Maintenance Costs % 10%

= Total YOY System Maintenance Cost 0.73$

+ Platform Support from ESB/CIM 0.22$

514.14 = RTB Comprehensive Integration Services RTB Labor 0.95$

Cloud Hosting Cash Flow ($M)

Yr ‐1 Yr ‐2 Yr ‐3 Yr ‐4 Yr ‐5

# Description Category Type

FY19 FY20 FY21 FY22 FY23

517.01 CAPEX Development Data Lake Opex NonLabor ‐$ 0.09$ 0.09$ 0.09$ 0.09$

517.02 CAPEX QA Data Lake Opex NonLabor ‐$ 0.18$ 0.18$ 0.18$ 0.18$

517.03 CAPEX Production Data Lake Opex NonLabor ‐$ 0.55$ 1.30$ 2.02$ 2.38$

517.04 CAPEX Dashboard Environment Opex NonLabor ‐$ 0.32$ 0.32$ 0.32$ 0.32$

517.05 RTB Platform Maintenance & Support RTB Labor ‐$ ‐$ 0.50$ 0.75$ 0.75$

517.06 CAPEX Platform Setup Capex Labor ‐$ 1.39$ ‐$ ‐$ ‐$

517.07 OPEX Platform Design Opex Labor ‐$ 0.32$ ‐$ ‐$ ‐$

Total ‐$ 2.85$ 2.39$ 3.35$ 3.71$

25



Page 9 of 17

9

Data Lake Cloud Hosting Calculations


Development Data Nodes 29,940$

+ Development Master Nodes 18,626$

+ Development Edge Nodes 10,241$

517.01 = CAPEX Development Data Lake NonLabor Opex 0.08$

QA Data Nodes 72,046$

+ QA Master Nodes 29,526$

+ QA Edge Nodes 18,626$

517.02 = CAPEX QA Data Lake NonLabor Opex 0.16$

Production Data Nodes 882,196$

+ Production Master Nodes 32,196$

+ Production Edge Nodes 19,979$

x Number of Production DR Envts. 2

+ Production Archival Storage 16,080

517.03 = CAPEX Production Data Lake NonLabor Opex 2.52$

Number of Production DR Envts. 2

x Production Dashboard Environment 81,584$

+ Development Dashboard Environment 63,092$

+ QA Dashboard Environment 63,092$

517.04 = CAPEX Dashboard Environment NonLabor Opex 0.29$

Platform Maintenance & Support 750,000$

517.05 = RTB Platform Maintenance & Support Labor RTB 0.75$


x Capex Platform Support 80%

x Travel 20%

517.06 = CAPEX Platform Setup Labor Capex 1.16$


x Opex Platform Support 20%

x Travel 20%

517.07 = OPEX Platform Design Labor Opex 0.29$

26

10

THE

E NARRAGAN

Workpaper 3.2Ju

NSETT ELECTd/b/a NRIPUC

2 - Modern Griurisdiction Dep

TRIC COMPANATIONAL GRC Docket No. 4id Costs for Mployment Scen

Page 10 o

ANY RID

4770 ulti-

nario of 17

27



Page 11 of 17

11

Information Management Cloud Analytics Cash Flow ($M)



516.01 Utility Data Model License Capex NonLabor ‐$ ‐$ ‐$ ‐$ 1.90$

516.02 Utility Data Model License Support Opex NonLabor ‐$ ‐$ ‐$ ‐$ ‐$

516.03 Information Management License Capex NonLabor ‐$ 1.72$ ‐$ ‐$ ‐$

516.04 Information Management License Support Opex NonLabor ‐$ ‐$ 0.29$ 0.29$ 0.29$

516.05 Data Governance License Capex NonLabor ‐$ 0.40$ ‐$ ‐$ ‐$

516.06 Data Governance License Support Opex NonLabor ‐$ 0.34$ 0.34$ 0.34$ 0.34$

516.07 Data Quality Development Capex Labor ‐$ 0.49$ 1.21$ 0.73$ ‐$

516.08 Data Ingestion Development Capex Labor ‐$ 1.28$ 3.21$ 1.92$ ‐$

516.09 Dashboard Development Capex Labor ‐$ 0.11$ 0.28$ 0.17$ ‐$

516.1 CAPEX Platform Design & Development Capex Labor ‐$ 0.23$ 0.58$ 0.35$ ‐$

516.11 Platform Support & Maintenance RTB Labor ‐$ ‐$ 1.18$ 1.42$ 1.78$

516.12 CAPEX Visualization License Cost Capex NonLabor ‐$ 7.58$ ‐$ ‐$ ‐$

516.13 Opex Visualization License Cost Opex NonLabor ‐$ 0.09$ ‐$ ‐$ ‐$

516.14 CAPEX IS Visualization License Cost Capex NonLabor ‐$ 0.73$ 0.58$ 0.58$ 0.58$

516.15 Opex IS Visualization License Cost Opex NonLabor ‐$ ‐$ 0.03$ 0.03$ 0.03$

Total ‐$ 12.96$ 7.70$ 5.83$ 4.92$

28



Page 12 of 17

12



Utility Data Model License 1,460,206.48$

516.01 = Utility Data Model License Capex NonLabor 1.46$

Utility Data Model License Support 292,041.30$

516.02 = Utility Data Model License Support Opex NonLabor 0.29$

Information Management License 1,319,702.37$

516.03 = Information Management License Capex NonLabor 1.32$

Information Management License Support 263,940.47$

516.04 = Information Management License Support Opex NonLabor 0.26$

Data Governance License 307,142.00$

516.05 = Data Governance License Capex NonLabor 0.31$

Data Governance License Support 307,142.00$

516.06 = Data Governance License Support Opex NonLabor 0.31$

Data Quality Dev Hours 16857


x Travel 20%

516.07 = Data Quality Development Capex Labor 2.02$

ETL Dev Hours 44547


x Travel 20%

516.08 = Data Ingestion Development Capex Labor 5.35$

Dashboard Dev Hours 3851


x Travel 20%

516.09 = Dashboard Development Capex Labor 0.46$


x Capex Allocation 80%

516.10 = CAPEX Platform Design & Development Capex Labor 0.96$

29



Page 13 of 17

13

5. TELECOMMUNICATIONS




x Opex Allocation 20%

516.16 = OPEX Platform Design & Development Opex Labor 0.24$

Platform Support & Maintenance 1,782,000$

516.11 = Platform Support & Maintenance RTB Labor 1.78$

Visualization License ‐ Business 7,934,000$

NY Cost Factor 73%

516.12 = CAPEX Visualization License Cost Capex NonLabor 5.83$

Visualization License Maintenance ‐ Business 115,000$

NY Cost Factor 73%

516.13 = Opex Visualization License Cost Opex NonLabor 0.08$



+ Alteryx Designer License 5,195$


+

Alteryx Server License 58,500$

x Number of Alteryx Servers 4

516.14 = CAPEX IS Visualization License Cost Capex NonLabor 0.56$




x Tableau Server Maintenace Cost 25%

516.15 = Opex IS Visualization License Cost Opex NonLabor 0.03$

Telecom Non‐Inflated Cash Flow ($M)



513.08 CAPEX Corporate Backbone Expansion Capex NonLabor ‐$ 0.10$ 0.05$ 0.05$ ‐$

513.09 RTB Corpate Backbone Expansion RTB NonLabor ‐$ ‐$ 0.54$ 0.81$ 1.08$

513.10 CAPEX IT/OT Backbone Expansion Capex NonLabor ‐$ 0.15$ 0.07$ 0.07$ ‐$

513.11 RTB IT/OT Backbone Expansion RTB NonLabor ‐$ ‐$ 1.62$ 2.43$ 3.24$

513.12 CAPEX IT/OT Mesh Network Backhaul Capex NonLabor ‐$ 0.23$ 0.11$ 0.11$ ‐$

513.13 RTB IT/OT Mesh Network Backhaul RTB NonLabor ‐$ ‐$ 0.45$ 0.68$ 0.90$

Total ‐$ 0.48$ 2.85$ 4.15$ 5.22$

30



Page 14 of 17

14

Telecom Calculations


SCI Implementation Cost 60,000$

+

Data Center Bandwidth Increase Cost 16,500$


513.08 = CAPEX Corporate Backbone Expansion Capex NonLabor 0.16$

Monthly SCI Service Cost 4,000$

x 0 0

+

Monthly Data Center Bandwidth Increase 15,000$



513.09 = RTB Corpate Backbone Expansion RTB NonLabor 1.08$

POPs Bandwidth Implementation cost 30,000$


+

CSC Data Center Bandwidth cost 22,500$


513.10 = CAPEX IT/OT Backbone Expansion Capex NonLabor 0.23$

Monthly cost of POP bandwidth 35,000$



+

Monthly cost of CSC bandwidth 30,000$



513.11 = RTB IT/OT Backbone Expansion RTB NonLabor 3.24$

Wireless gateway planning and configuration 50,000$

+

Stand up of wireless gateway 75,000$


+

Set up of CSC bandwidth and VRFs 25,000$


513.12 = CAPEX IT/OT Mesh Network Backhaul Capex NonLabor 0.35$

Monthly cost of wireless gateway 20,000$



+

Monthly cost of CSC data center link increase 5,000$



513.13 = RTB IT/OT Mesh Network Backhaul RTB NonLabor 0.90$

31



Page 15 of 17

15

6. CYBERSECURITY

SUMMARY ALL COSTS,

$1,000sSPENDING TYPE FY19 FY20 FY21 FY22 FY23

600 CAPEX $0 $15,758 $7,667 $5,077 $0

601 OPEX $0 $6,647 $2,768 $1,914 $0

602 RTB $0 $2,993 $2,163 $1,882 $3,909

603 CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $12,910

604 OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $33 $1,728

GRAND TOTAL $0 $25,398 $12,598 $8,906 $18,547

B_NETWORK SECURITY


600B CAPEX $0 $4,802 $2,216 $1,464 $0

601B OPEX $0 $427 $197 $130 $0

602B RTB $0 $1,488 $730 $510 $2,538

603B CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $1,603

604B OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $6,716 $3,142 $2,103 $4,140

C_DATA SECURITY


600C CAPEX $0 $699 $322 $212 $0

601C OPEX $0 $427 $197 $130 $0

602C RTB $0 $138 $108 $83 $83

603C CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $747

604C OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,264 $626 $425 $830

D_IDENTITY AND ACCESS

MANAGEMENSPENDING TYPE FY18 FY19 FY20 FY21 FY22

600D CAPEX $0 $4,214 $1,940 $1,281 $0

601D OPEX $0 $427 $197 $130 $0

602D RTB $0 $276 $276 $276 $276

603D CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $3,004

604D OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $1,568

TOTAL $0 $4,917 $2,412 $1,687 $4,848

E_THREAT AND

VULNERABILITY MANASPENDING TYPE FY18 FY19 FY20 FY21 FY22

600E CAPEX $0 $1,074 $494 $326 $0

601E OPEX $0 $427 $197 $130 $0

602E RTB $0 $83 $83 $83 $83

603E CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $1,456

604E OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,583 $774 $539 $1,538

32



Page 16 of 17

16

F_SECURITY OPERATIONS

CENTER SESPENDING TYPE FY18 FY19 FY20 FY21 FY22

600F CAPEX $0 $1,326 $610 $403 $0

601F OPEX $0 $427 $197 $130 $0

602F RTB $0 $89 $89 $89 $89

603F CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $656

604F OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $7 $7

TOTAL $0 $1,842 $896 $628 $752

G_HOST & ENDPOINT

SECURITY SERVSPENDING TYPE FY18 FY19 FY20 FY21 FY22

600G CAPEX $0 $572 $298 $219 $0

601G OPEX $0 $482 $251 $130 $0

602G RTB $0 $83 $83 $83 $83

603G CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $531

604G OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,136 $632 $432 $614

H_SECURITY POLICY

MANAGEMENT SESPENDING TYPE FY18 FY19 FY20 FY21 FY22

600H CAPEX $0 $572 $298 $219 $0

601H OPEX $0 $482 $251 $130 $0

602H RTB $0 $83 $83 $83 $83

603H CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $531

604H OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,136 $632 $432 $614

I_CRYPTOGRAPHY


600I CAPEX $0 $510 $235 $155 $0

601I OPEX $0 $427 $197 $130 $0

602I RTB $0 $162 $119 $83 $83

603I CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $730

604I OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $26 $153

TOTAL $0 $1,099 $551 $394 $966

J_CHANGE &

CONFIGURATION

MANAGE

SPENDING TYPE FY18 FY19 FY20 FY21 FY22

600J CAPEX $0 $302 $139 $92 $0

601J OPEX $0 $427 $197 $130 $0

602J RTB $0 $83 $83 $83 $83

603J CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $532

604J OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $811 $418 $304 $615

33



Page 17 of 17

17

K_SECURITY AWARENESS

& TRAININGSPENDING TYPE FY18 FY19 FY20 FY21 FY22

600K CAPEX $0 $0 $0 $0 $0

601K OPEX $0 $449 $152 $152 $0

602K RTB $0 $177 $177 $177 $177

603K CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

604K OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $626 $329 $329 $177

L_APPLICATION SECURITY


600L CAPEX $0 $969 $446 $295 $0

601L OPEX $0 $633 $91 $29 $0

602L RTB $0 $83 $83 $83 $83

603L CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $1,063

604L OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,686 $620 $407 $1,146

M_THIRD PARTY

ASSURANCE MANAGEMSPENDING TYPE FY18 FY19 FY20 FY21 FY22

600M CAPEX $0 $0 $0 $0 $0

601M OPEX $0 $753 $0 $565 $0

602M RTB $0 $83 $83 $83 $83

603M CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

604M OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $836 $83 $648 $83

N_REMOTE ACCESS


600N CAPEX $0 $720 $668 $411 $0

601N OPEX $0 $295 $458 $0 $0

602N RTB $0 $83 $83 $83 $83

603N CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $2,057

604N OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $1,097 $1,210 $494 $2,140

O_PRIVACY SERVICES SPENDING TYPE FY18 FY19 FY20 FY21 FY22

600O CAPEX $0 $0 $0 $0 $0

601O OPEX $0 $565 $188 $0 $0

602O RTB $0 $83 $83 $83 $83

603O CAPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

604O OPEX ‐ REMOVAL/REFRESH $0 $0 $0 $0 $0

TOTAL $0 $648 $271 $83 $83

34

W

orkpaper 4.1


Witnesses: Leana, Sheridan, Nouel Roughan

Workpaper 4.1,

AMF Costs

REDACTED

35

AM

F C

osts

and

Ben

efits

(in m

illio

ns)

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 4

.1 -

AM

F C

osts

, RE

DA

CT

ED

Pag

e 1

of 9

#D

escr

ipti

on

Cat

ego

ryG

rou

pN

PV

FY

20

FY

21

FY

22

FY

23

- F

Y 3

9

BE

NE

FIT

S (

CO

MB

INE

D)

2B

enef

it fr

om e

limin

ated

AM

R m

eter

rea

ders

Ope

xA

MR

Met

er R

eadi

ng$1

3.51

-$

-$

0.46

$

30

.98

$

3

Ben

efit

from

elim

inat

ed A

MR

met

er r

eade

r ve

hicl

e co

sts

Ope

xA

MR

Met

er R

eadi

ng$1

.23

-$

-$

0.04

$

2.

81$

4

CO

2 be

nefit

from

elim

inat

ed A

MR

veh

icle

em

issi

ons

Em

issi

ons

AM

R M

eter

Rea

ding

(C

O2)

$0.0

2-

$

-

$

0.

00$

0.04

$

5B

enef

it fr

om r

educ

tion

of m

eter

inve

stig

atio

nsO

pex

Met

er In

vest

igat

ion

$6.2

0-

$

-

$

0.

21$

14.2

1$

6B

enef

it fr

om r

emot

e m

eter

ing

capa

bilit

ies

Ope

xR

emot

e C

onne

ct a

nd D

isco

nnec

t$2

6.90

-$

-$

0.92

$

61

.66

$

9

Ben

efit

from

impr

ovem

ent i

n ba

d de

bt w

rite-

offs

Ope

xR

educ

tion

in W

rite-

offs

$0.0

0-

$

-

$

-

$

18

.89

$

11

Ben

efit

from

miti

gatio

n / r

educ

tion

of d

amag

e cl

aim

sO

pex

Red

uctio

n in

Dam

age

Cla

ims

$2.6

1-

$

-

$

-

$

6.

13$

13

Ben

efit

from

red

uctio

n of

AM

R th

eft /

und

erm

eter

ing

Ope

xR

educ

tion

in T

heft

of S

ervi

ce$0

.00

-$

-$

1.22

$

80

.02

$

14

Ben

efit

from

VV

O/A

MF

inte

grat

ion

Ope

xV

olt-

VA

R O

ptim

izat

ion

$13.

73-

$

-

$

-

$

36

.88

$

15C

O2

bene

fit fr

om V

VO

/AM

F in

tegr

atio

nLo

sses

Vol

t-V

AR

Opt

imiz

atio

n (C

O2)

$5.4

6-

$

-

$

0.

14$

12.4

8$

16B

enef

it fr

om E

nerg

y In

sigh

ts/H

igh

usag

e al

erts

Rev

enue

Ene

rgy

Insi

ghts

/Hig

h U

sage

Ale

rts

$22.

02-

$

0.

55$

1.80

$

48

.88

$

17

CO

2 be

nefit

from

Ene

rgy

Insi

ghts

/Hig

h us

age

aler

tsLo

sses

Ene

rgy

Insi

ghts

/Hig

h U

sage

Ale

rts

(CO

2)$7

.88

-$

0.36

$

1.

05$

14.3

6$

18C

O2

bene

fit fr

om r

educ

tion

of m

eter

inve

stig

atio

nsE

mis

sion

sM

eter

Inve

stig

atio

n (C

O2)

$0.0

1-

$

-

$

0.

00$

0.03

$

19C

O2

bene

fit fr

om r

emot

e m

eter

ing

capa

bilit

ies

Em

issi

ons

Rem

ote

Con

nect

and

Dis

conn

ect (

CO

2)$0

.17

-$

-$

0.01

$

0.

35$

20O

utag

e M

anag

emen

t ope

ratio

nal b

enef

itO

pex

Sto

rm O

MS

Ben

efit

$1.8

8-

$

-

$

-

$

4.

42$

25B

enef

it fr

om E

lect

ric V

ehic

le T

VP

Ope

xE

lect

ric V

ehic

le P

ricin

g$2

4.81

-$

-$

-$

68.6

6$

26Lo

w-E

nd R

ed. &

Opt

-In

bene

fit fr

om C

ritic

al P

eak

Pric

ing

(CP

P)

peak

sha

ving

Ope

xT

ime

Var

ying

Pric

ing

$4.5

9-

$

-

$

-

$

12

.75

$

27

Low

-End

Red

. & O

pt-I

n be

nefit

from

Avo

ided

Ene

rgy

due

to T

ime-

of-U

se P

rogr

amO

pex

Tim

e V

aryi

ng P

ricin

g$3

.84

-$

-$

-$

10.6

5$

28Lo

w-E

nd R

ed. &

Opt

-In

CO

2 sa

ving

s fr

om A

void

ed E

nerg

y du

e to

Tim

e-of

-Use

Pro

gram

Em

issi

ons

Tim

e V

aryi

ng P

ricin

g (C

O2)

$2.8

6-

$

-

$

-

$

7.

59$

30B

enef

it fr

om E

lect

rom

echa

nica

l met

er A

ccur

acy

Ope

xE

lect

rom

echa

nica

l Met

er$0

.00

-$

2.08

$

4.

38$

20.8

9$

100

Avo

ided

Ele

ctric

AM

R E

quip

men

t Met

er R

epla

cem

ent

Cap

exC

apita

l $3

2.00

0.86

$

0.

89$

16.1

0$

30

.97

$

10

2A

void

ed A

MF

ele

ctric

met

er in

stal

latio

n co

st -

Cap

ex p

ortio

nC

apex

Cap

ital

$20.

600.

55$

0.57

$

10

.30

$

20.1

5$

105

Avo

ided

AM

F d

emon

stra

tion

perio

d co

stO

pex

Ope

ratio

ns &

Mai

nten

ance

$1.0

71.

16$

-$

-$

-$

123

Avo

ided

cos

t fro

m c

all c

ente

r an

d A

MO

, im

plem

enta

tion

Ope

xO

pera

tions

& M

aint

enan

ce$2

.44

-$

1.08

$

1.

87$

-$

124

Avo

ided

AM

F In

tern

al P

roje

ct M

anag

emen

t Lea

ders

hip

Sta

ff -

Cap

ex p

ortio

nC

apex

Cap

ital

$0.7

2-

$

0.

42$

0.44

$

-

$

12

6A

void

ed A

MF

ele

ctric

met

er in

stal

latio

n co

st -

CO

R p

ortio

nC

OR

Cap

ital

$0.6

40.

02$

0.02

$

0.

32$

0.62

$

128

Avo

ided

AM

F E

xter

nal P

roje

ct M

anag

emen

t lab

or c

ost -

Ope

x po

rtio

nO

pex

Ope

ratio

ns &

Mai

nten

ance

$0.0

0-

$

-

$

-

$

-

$

12

9A

void

ed A

MF

Inte

rnal

Pro

ject

Man

agem

ent L

eade

rshi

p S

taff

- O

pex

port

ion

Ope

xO

pera

tions

& M

aint

enan

ce$0

.38

0.41

$

-

$

-

$

-

$

13

4A

void

ed A

MF

inve

ntor

y eq

uipm

ent c

ost

Cap

exC

apita

l $0

.80

0.02

$

0.

02$

0.40

$

0.

77$

203

Avo

ided

CM

S D

eplo

ymen

t Cen

ter,

Fac

ility

cos

tC

apex

Cap

ital

$1.3

5-

$

1.

06$

0.54

$

-

$

20

4A

void

ed C

MS

Bac

k O

ffice

& C

leric

al c

ost

Cap

exC

apita

l $1

.86

-$

1.46

$

0.

75$

-$

205

Avo

ided

Ser

vice

Rep

rese

ntat

ive

Too

ls /

Uni

form

cos

tC

apex

Cap

ital

$0.1

9-

$

0.

16$

0.06

$

-

$

20

6A

void

ed In

stal

led

met

er Q

ualit

y A

ssur

ance

/ Q

ualit

y C

heck

cos

tC

apex

Cap

ital

$0.6

1-

$

0.

48$

0.25

$

-

$

20

7A

void

ed C

MS

Dep

loym

ent C

oord

inat

ion

Labo

r co

stC

apex

Cap

ital

$0.8

2-

$

0.

64$

0.33

$

-

$

20

8A

void

ed C

MS

Fie

ld In

stal

ler

Initi

al T

rain

ing

Cap

exC

apita

l $0

.78

0.43

$

0.

44$

-$

-$

209

Avo

ided

CM

S C

ellu

lar

Com

mun

icat

ion

cost

Cap

exC

apita

l $0

.06

-$

0.04

$

0.

02$

-$

210

Avo

ided

Han

dhel

d D

evic

es c

ost

Cap

exC

apita

l $0

.05

-$

0.06

$

-

$

-

$

302

Avo

ided

MD

S S

yste

m D

evel

opm

ent T

estin

gC

apex

Cap

ital

$0.0

60.

05$

0.02

$

-

$

-

$

400

Avo

ided

Cus

tom

er E

ngag

emen

t Pla

n C

ost

Ope

xO

pera

tions

& M

aint

enan

ce$2

.07

0.23

$

0.

85$

0.50

$

1.

16$

540

Avo

ided

FC

S C

osts

Ope

xF

CS

Met

er R

eadi

ng$0

.28

-$

-$

0.01

$

0.

66$

54

1A

void

ed In

terv

al M

eter

Rea

ding

Cos

tsO

pex

Inte

rval

Met

er R

eadi

ng$0

.02

-$

0.00

$

0.

00$

0.03

$

To

tal B

enef

it20

4.52

$

3.73

$

11

.18

$

42.1

2$

50

7.02

$

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 4.1 - AMF Costs, REDACTED Page 1 of 9

36

AM

F C

osts

and

Ben

efits

(in m

illio

ns)

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 4

.1 -

AM

F C

osts

, RE

DA

CT

ED

Pag

e 2

of 9

#D

escr

ipti

on

Cat

ego

ryG

rou

pN

PV

FY

20

FY

21

FY

22

FY

23

- F

Y 3

9

CO

ST

S (

CO

MB

INE

D)

100

AM

F e

lect

ric m

eter

equ

ipm

ent c

ost

Cap

exA

MF

Ele

ctric

Met

er E

quip

men

t and

Inst

alla

tion

$50.

50-

$

20

.03

$

41.2

1$

-

$

10

2A

MF

ele

ctric

met

er in

stal

latio

n co

st -

Cap

ex p

ortio

nC

apex

AM

F E

lect

ric M

eter

Equ

ipm

ent a

nd In

stal

latio

n$2

3.35

-$

9.25

$

19

.08

$

-$

104

AM

F fa

iled

met

er e

quip

men

t rep

lace

men

t cos

tC

apex

Equ

ipm

ent a

nd In

stal

latio

n R

efre

sh C

ost

$0.8

9-

$

0.

03$

0.09

$

1.

86$

10

5A

MF

dem

onst

ratio

n pe

riod

cost

Ope

xA

MF

Ele

ctric

Met

er E

quip

men

t and

Inst

alla

tion

$1.4

31.

54$

-$

-$

-$

110

AM

F n

etw

ork

engi

neer

ing,

des

ign,

con

trac

ting

cost

Cap

exN

etw

ork

Equ

ipm

ent a

nd In

stal

latio

n$0

.10

0.10

$

-

$

-

$

-

$

11

1N

etw

ork

com

mun

icat

ions

equ

ipm

ent c

ost,

Ele

ctric

Met

ers

Cap

exN

etw

ork

Equ

ipm

ent a

nd In

stal

latio

n$1

.29

-$

0.51

$

1.

05$

-$

112

Net

wor

k co

mm

unic

atio

ns e

quip

men

t cos

t, G

as M

eter

sC

apex

Net

wor

k E

quip

men

t and

Inst

alla

tion

$0.1

8-

$

0.

07$

0.15

$

-

$

11

3N

etw

ork

com

mun

icat

ions

inst

alla

tion

cost

, Ele

ctric

Met

ers

Cap

exN

etw

ork

Equ

ipm

ent a

nd In

stal

latio

n$0

.10

-$

0.04

$

0.

09$

-$

114

Net

wor

k co

mm

unic

atio

ns in

stal

latio

n co

st, G

as M

eter

sC

apex

Net

wor

k E

quip

men

t and

Inst

alla

tion

$0.0

1-

$

0.

01$

0.01

$

-

$

11

5N

etw

ork

com

mun

icat

ions

LT

E b

ackh

aul c

ost,

Ele

ctric

Met

ers

Ope

xB

ackh

aul

$0.9

5-

$

0.

03$

0.09

$

2.

00$

11

6N

etw

ork

com

mun

icat

ions

LT

E b

ackh

aul c

ost,

Gas

Met

ers

Ope

xB

ackh

aul

$0.1

1-

$

0.

00$

0.00

$

0.

25$

11

7A

MF

met

er c

ellu

lar

serv

ice

cost

, Ele

ctric

Met

ers

Ope

xE

quip

men

t and

Inst

alla

tion

Ref

resh

Cos

t$1

.55

-$

0.05

$

0.

15$

3.25

$

118

Net

wor

k co

mm

unic

atio

ns e

quip

men

t cos

t upg

rade

Cap

exN

etw

ork

Equ

ipm

ent a

nd In

stal

latio

n$1

.14

-$

-$

-$

2.35

$

119

AM

F c

omm

unic

atio

ns fa

iled

equi

pmen

t rep

lace

men

t cos

tC

apex

Equ

ipm

ent a

nd In

stal

latio

n R

efre

sh C

ost

$0.1

9-

$

-

$

0.

01$

0.42

$

120

AM

F c

omm

unic

atio

ns e

quip

men

t O&

M c

ost (

outs

ide

war

rant

y)O

pex

Equ

ipm

ent a

nd In

stal

latio

n R

efre

sh C

ost

$0.3

6-

$

-

$

-

$

0.

85$

12

1A

MF

Ext

erna

l Pro

ject

Man

agem

ent l

abor

cos

t - C

apex

por

tion

Cap

exP

roje

ct M

anag

emen

t$1

.75

-$

2.02

$

-

$

-

$

12

3C

ost f

rom

cal

l cen

ter

and

AM

O, i

mpl

emen

tatio

nO

pex

Pro

ject

Man

agem

ent

$4.8

7-

$

2.

15$

3.74

$

-

$

12

4A

MF

Inte

rnal

Pro

ject

Man

agem

ent L

eade

rshi

p S

taff

- C

apex

por

tion

Cap

exP

roje

ct M

anag

emen

t$0

.72

-$

0.42

$

0.

44$

-$

125

AM

F In

tern

al P

roje

ct M

anag

emen

t Bus

ines

s S

uppo

rt -

Cap

ex p

ortio

nC

apex

Pro

ject

Man

agem

ent

$2.4

21.

28$

1.42

$

-

$

-

$

12

6A

MF

ele

ctric

met

er in

stal

latio

n co

st -

CO

R p

ortio

nC

OR

AM

F E

lect

ric M

eter

Equ

ipm

ent a

nd In

stal

latio

n$0

.72

-$

0.29

$

0.

59$

-$

128

AM

F E

xter

nal P

roje

ct M

anag

emen

t lab

or c

ost -

Ope

x po

rtio

nO

pex

Pro

ject

Man

agem

ent

$1.8

31.

97$

-$

-$

-$

129

AM

F In

tern

al P

roje

ct M

anag

emen

t Lea

ders

hip

Sta

ff -

Ope

x po

rtio

nO

pex

Pro

ject

Man

agem

ent

$0.3

80.

41$

-$

-$

-$

130

AM

F In

tern

al P

roje

ct M

anag

emen

t Bus

ines

s S

uppo

rt-

Ope

x po

rtio

nO

pex

Pro

ject

Man

agem

ent

$1.2

81.

38$

-$

-$

-$

134

AM

F in

vent

ory

equi

pmen

t cos

tC

apex

AM

F In

vent

ory

$1.2

6-

$

0.

50$

1.03

$

-

$

13

5P

rofe

ssio

nal S

ervi

ces

- F

ield

Dep

loym

ent S

uppo

rt W

orks

trea

m c

ost

Cap

exC

omm

unic

atio

n N

etw

ork

Inst

alla

tion

Man

agem

ent

$3.2

1-

$

0.

42$

2.00

$

1.

65$

13

6P

rofe

ssio

nal S

ervi

ces

- F

ield

Dep

loym

ent S

uppo

rt W

orks

trea

m T

rave

l Exp

ense

s co

stO

pex

Com

mun

icat

ion

Net

wor

k In

stal

latio

n M

anag

eme

nt$0

.48

-$

0.06

$

0.

30$

0.25

$

201

Bac

k-O

ffice

Rev

enue

Ass

uran

ce A

naly

st c

ost

Ope

xO

ngoi

ng B

usin

ess

Man

agem

ent

$0.0

0-

$

-

$

-

$

-

$

20

2C

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f the

ft in

vest

igat

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xO

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agem

ent

$0.0

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loym

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$1.3

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$1.8

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$0.1

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0.

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6In

stal

led

met

er Q

ualit

y A

ssur

ance

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heck

cos

tC

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port

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0.48

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0.

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207

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bor

cost

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$0.8

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20

8C

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Fie

ld In

stal

ler

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exS

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fras

truc

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$0.7

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9C

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lula

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unic

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re$0

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210

Han

dhel

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exS

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$0.0

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0.

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300

AM

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dditi

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vice

s la

bor

cost

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xO

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agem

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$4.1

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0.

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0.70

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1B

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ent T

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Ong

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ines

s M

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emen

t$2

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0.17

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0.

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3.92

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302

MD

S S

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m D

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opm

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estin

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Sup

port

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astr

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re$0

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0.49

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0.

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-$

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400

Cus

tom

er E

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emen

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n C

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usto

mer

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agem

ent C

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$8.3

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93$

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501

CS

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ex C

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vice

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tem

$7.4

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-

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50

2P

rofe

ssio

nal S

ervi

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- H

ead

End

/MD

M S

olut

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Pro

gram

Man

agem

ent c

ost

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d-en

d an

d M

eter

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a M

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t Sys

tem

s*$2

.20

0.28

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1.

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50

3E

nerg

y M

onito

ring

Por

tal O

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tO

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tom

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duct

s an

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$1.3

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2.

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50

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ton

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nect

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ex C

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exC

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agem

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cts

and

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vice

s$2

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0.

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513

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ex c

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51

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51

6In

form

atio

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anag

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ex c

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exIS

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51

7D

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Cap

ex c

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re$0

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51

8P

rofe

ssio

nal S

ervi

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- H

ead

End

/MD

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ms

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emen

tatio

n W

orks

trea

m c

ost

Ope

xA

MF

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d-en

d an

d M

eter

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a M

anag

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t Sys

tem

s*$

5.11

4.81

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0.

73$

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519

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etup

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One

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e S

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cale

-up

exis

ting

syst

em)

cost

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xA

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d-en

d an

d M

eter

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a M

anag

emen

t S

yste

ms*

$0.1

90.

20$

-$

-$

-$


37

AM

F C

osts

and

Ben

efits

(in m

illio

ns)

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 4

.1 -

AM

F C

osts

, RE

DA

CT

ED

Pag

e 3

of 9

#D

escr

ipti

on

Cat

ego

ryG

rou

pN

PV

FY

20

FY

21

FY

22

FY

23

- F

Y 3

9

CO

ST

S (

CO

MB

INE

D)

520

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S F

ees

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eade

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oftw

are

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OC

CM

, OW

OC

PM

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E M

DM

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FN

D, F

DM

) co

stO

pex

AM

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ead-

end

and

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ata

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agem

ent S

yste

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98-

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1.

44$

3.97

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11

4.06

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52

1P

rofe

ssio

nal S

ervi

ces

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yste

m a

nd M

eter

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war

e U

pgra

de c

ost

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d-en

d an

d M

eter

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a M

anag

emen

t Sys

tem

s*$0

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-$

1.05

$

522

Tel

ecom

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x co

stO

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fras

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ture

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-

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-

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$

52

3T

elec

om R

TB

Cos

tO

pex

IS In

fras

truc

ture

$6.6

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0.

11$

0.41

$

14

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$

52

4E

SB

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x co

stO

pex

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fras

truc

ture

$0.5

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21$

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525

ES

B R

TB

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tO

pex

IS In

fras

truc

ture

$6.3

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00$

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526

Dat

a La

ke O

pex

cost

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xIS

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astr

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re$2

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0.15

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0.

13$

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4.

00$

52

7P

rofe

ssio

nal S

ervi

ces

- H

ead

End

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M S

olut

ion

Pro

gram

Man

agem

ent T

rave

l Exp

ense

s c o

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xA

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d-en

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d M

eter

Dat

a M

anag

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t Sys

tem

s*$0

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0.04

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0.

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$

52

8P

rofe

ssio

nal S

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- H

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End

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M S

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ms

Impl

emen

tatio

n W

orks

trea

m T

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l Exp

e nO

pex

AM

F H

ead-

end

and

Met

er D

ata

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agem

ent S

yste

ms*

$0.7

70.

72$

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-

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$

52

9G

reen

But

ton

Con

nect

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x C

ost

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xC

usto

mer

Eng

agem

ent P

rodu

cts

and

Ser

vice

s$0

.82

0.55

$

0.

35$

-$

-$

530

Info

rmat

ion

Man

agem

ent O

pex

cost

Ope

xIS

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astr

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re$0

.47

0.02

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0.

03$

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$

0.

92$

53

1In

form

atio

n M

anag

emen

t RT

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ost

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xIS

Infr

astr

uctu

re$3

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-$

0.06

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0.

20$

6.56

$

532

Ene

rgy

Mon

itorin

g P

orta

l RT

B C

ost

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mer

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agem

ent P

rodu

cts

and

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vice

s$0

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-$

0.01

$

0.

03$

0.86

$

533

CS

S E

nhan

cem

ents

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x C

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mer

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vice

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tem

$0.2

90.

01$

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$

0.

05$

0.07

$

534

CS

S E

nhan

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ents

RT

B C

ost

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xC

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mer

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vice

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tem

$0.2

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0.

00$

0.46

$

535

Gre

en B

utto

n C

onne

ct R

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Cos

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Cus

tom

er E

ngag

emen

t Pro

duct

s an

d S

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ces

$4.9

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$

0.

15$

0.40

$

10

.31

$

53

6D

ata

Lake

RT

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xIS

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astr

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re$1

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-$

0.03

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0.

10$

2.72

$

600

Cyb

er S

ecur

ity P

roje

ct C

apex

Initi

alC

apex

Cyb

er S

ecur

ity$7

.31

4.29

$

2.

52$

1.41

$

-

$

60

1C

yber

Sec

urity

Pro

ject

Ope

x In

itial

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$3.2

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0.

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602

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ct R

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11

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$

60

3C

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urity

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resh

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al C

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l C

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ecur

ity$7

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18.9

4$

604

Cyb

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ecur

ity C

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l Ref

resh

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$3.9

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8.85

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To

tal C

ost

259.

75$

32

.55

$

62.3

2$

85

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$

246.

74$

100-

400'

sC

apex

93.4

3$

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$

39

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$

67.1

0$

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28$

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pex

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6.

20$

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$

22

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$

T

otal

121.

24$

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53$

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3$

74

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$

29.2

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8$

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$

17

1.71

$

T

otal

110.

12$

17

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$

12.8

9$

8.

29$

178.

07$

600'

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2$

4.29

$

2.

52$

1.41

$

18

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$

O

pex

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5$

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$

1.

20$

0.97

$

20

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27.6

7$

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$

3.

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$

39

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$

Tot

al C

apex

129.

11$

17

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$

49.3

5$

69

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$

31.5

7$

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al O

pen

129.

91$

15

.38

$

12.6

8$

15

.43

$

215.

17$


38

AM

F C

osts

and

Ben

efits

(in m

illio

ns)

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 4

.1 -

AM

F C

osts

, RE

DA

CT

ED

Pag

e 4

of 9

#D

escr

ipti

on

Cat

ego

ryG

rou

pN

PV

FY

20

FY

21

FY

22

FY

23

- F

Y 3

9

BE

NE

FIT

S (

Ele

ctri

c)

2B

enef

it fr

om e

limin

ated

AM

R m

eter

rea

ders

Ope

xA

MR

Met

er R

eadi

ng$1

3.51

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-$

0.46

$

30

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$

3

Ben

efit

from

elim

inat

ed A

MR

met

er r

eade

r ve

hicl

e co

sts

Ope

xA

MR

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er R

eadi

ng$1

.23

-$

-$

0.04

$

2.

81$

4

CO

2 be

nefit

from

elim

inat

ed A

MR

veh

icle

em

issi

ons

Em

issi

ons

AM

R M

eter

Rea

ding

(C

O2)

$0.0

2-

$

-

$

0.

00$

0.04

$

5B

enef

it fr

om r

educ

tion

of m

eter

inve

stig

atio

nsO

pex

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er In

vest

igat

ion

$6.2

0-

$

-

$

0.

21$

14.2

1$

6B

enef

it fr

om r

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e m

eter

ing

capa

bilit

ies

Ope

xR

emot

e C

onne

ct a

nd D

isco

nnec

t$2

6.90

-$

-$

0.92

$

61

.66

$

9

Ben

efit

from

impr

ovem

ent i

n ba

d de

bt w

rite-

offs

Ope

xR

educ

tion

in W

rite-

offs

$0.0

0-

$

-

$

-

$

18

.89

$

11

Ben

efit

from

miti

gatio

n / r

educ

tion

of d

amag

e cl

aim

sO

pex

Red

uctio

n in

Dam

age

Cla

ims

$2.6

1-

$

-

$

-

$

6.

13$

13

Ben

efit

from

red

uctio

n of

AM

R th

eft /

und

erm

eter

ing

Ope

xR

educ

tion

in T

heft

of S

ervi

ce$0

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-$

-$

1.22

$

80

.02

$

14

Ben

efit

from

VV

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MF

inte

grat

ion

Ope

xV

olt-

VA

R O

ptim

izat

ion

$13.

73-

$

-

$

-

$

36

.88

$

15C

O2

bene

fit fr

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VO

/AM

F in

tegr

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sses

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t-V

AR

Opt

imiz

atio

n (C

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$5.4

6-

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-

$

0.

14$

12.4

8$

16B

enef

it fr

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nerg

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sigh

ts/H

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$17.

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0.

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1.34

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40

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$

17

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2 be

nefit

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rgy

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tsLo

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h U

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2)$7

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-$

0.36

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1.

05$

14.3

6$

18C

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bene

fit fr

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educ

tion

of m

eter

inve

stig

atio

nsE

mis

sion

sM

eter

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stig

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n (C

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$0.0

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-

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0.

00$

0.03

$

19C

O2

bene

fit fr

om r

emot

e m

eter

ing

capa

bilit

ies

Em

issi

ons

Rem

ote

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nect

and

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conn

ect (

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2)$0

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0.01

$

0.

35$

20O

utag

e M

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emen

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ratio

nal b

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rm O

MS

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efit

$1.8

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4.

42$

25B

enef

it fr

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lect

ric V

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le T

VP

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lect

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4.81

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-$

68.6

6$

26Lo

w-E

nd R

ed. &

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bene

fit fr

om C

ritic

al P

eak

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ing

(CP

P)

peak

sha

ving

Ope

xT

ime

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ying

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ing

$4.5

9-

$

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$

-

$

12

.75

$

27

Low

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. & O

pt-I

n be

nefit

from

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ided

Ene

rgy

due

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ime-

of-U

se P

rogr

amO

pex

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e V

aryi

ng P

ricin

g$3

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10.6

5$

28Lo

w-E

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ed. &

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2 sa

ving

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om A

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nerg

y du

e to

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e-of

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Pro

gram

Em

issi

ons

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e V

aryi

ng P

ricin

g (C

O2)

$2.8

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$

-

$

7.

59$

30B

enef

it fr

om E

lect

rom

echa

nica

l met

er A

ccur

acy

Ope

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echa

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2.08

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100

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770

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128

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207

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519

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40

AM

F C

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and

Ben

efits

(in m

illio

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TH

E N

AR

RA

GA

NS

ET

T E

LE

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CO

MP

AN

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b/a

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NA

L G

RID

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UC

Doc

ket N

o. 4

770

Wor

kpap

er 4

.1 -

AM

F C

osts

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DA

CT

ED

Pag

e 6

of 9

520

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S F

ees

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eade

nd S

oftw

are

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PM

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rou

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PV

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FY

21

FY

22

FY

23

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9

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524

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ital R

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14

8.34

$


41

AM

F C

osts

and

Ben

efits

(in m

illio

ns)

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 4

.1 -

AM

F C

osts

, RE

DA

CT

ED

Pag

e 7

of 9

#D

escr

ipti

on

Cat

ego

ryG

rou

pN

PV

FY

20

FY

21

FY

22

FY

23

- F

Y 3

9

BE

NE

FIT

S (

GA

S)

2B

enef

it fr

om e

limin

ated

AM

R m

eter

rea

ders

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xA

MR

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er R

eadi

ng$0

.00

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enef

it fr

om e

limin

ated

AM

R m

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der

vehi

cle

cost

sO

pex

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R M

eter

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ding

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$

-

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4

CO

2 be

nefit

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elim

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ed A

MR

veh

icle

em

issi

ons

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issi

ons

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R M

eter

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ding

(C

O2)

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5

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efit

from

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uctio

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it fr

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xR

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it fr

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enef

it fr

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xR

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enef

it fr

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educ

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of A

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t / u

nder

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uctio

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ft of

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Ben

efit

from

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grat

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15C

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efit

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fit fr

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18C

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bene

fit fr

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eter

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w-E

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27

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30B

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l $0

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102

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lect

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alla

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cost

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apex

por

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l $0

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105

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stra

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12

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ter

and

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12

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void

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agem

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taff

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126

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128

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205

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void

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209

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302

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400

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ided

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tom

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ngag

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n C

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tions

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540

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ided

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osts

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eadi

ng$0

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541

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ided

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rval

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eadi

ng C

osts

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terv

al M

eter

Rea

ding

$0.0

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-

$

-

$

-

$

T

ota

l Ben

efit

4.65

$

0.

16$

0.31

$

0.

61$

8.48

$


42

AM

F C

osts

and

Ben

efits

(in m

illio

ns)

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 4

.1 -

AM

F C

osts

, RE

DA

CT

ED

Pag

e 8

of 9

#D

escr

ipti

on

Cat

ego

ryG

rou

pN

PV

FY

20

FY

21

FY

22

FY

23

- F

Y 3

9

CO

ST

S (

GA

S)

100

AM

F e

lect

ric m

eter

equ

ipm

ent c

ost

Cap

exA

MF

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ctric

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er E

quip

men

t and

Inst

alla

tion

$0.0

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-

$

-

$

-

$

10

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MF

ele

ctric

met

er in

stal

latio

n co

st -

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ex p

ortio

nC

apex

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F E

lect

ric M

eter

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ipm

ent a

nd In

stal

latio

n$0

.00

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-$

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104

AM

F fa

iled

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quip

men

t rep

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men

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tC

apex

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ent a

nd In

stal

latio

n R

efre

sh C

ost

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-

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10

5A

MF

dem

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ratio

n pe

riod

cost

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MF

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ctric

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t and

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tion

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11

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wor

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quip

men

t and

Inst

alla

tion

$0.0

30.

04$

-$

-$

-$

111

Net

wor

k co

mm

unic

atio

ns e

quip

men

t cos

t, E

lect

ric M

eter

sC

apex

Net

wor

k E

quip

men

t and

Inst

alla

tion

$0.0

0-

$

-

$

-

$

-

$

11

2N

etw

ork

com

mun

icat

ions

equ

ipm

ent c

ost,

Gas

Met

ers

Cap

exN

etw

ork

Equ

ipm

ent a

nd In

stal

latio

n$0

.18

-$

0.07

$

0.

15$

-$

113

Net

wor

k co

mm

unic

atio

ns in

stal

latio

n co

st, E

lect

ric M

eter

sC

apex

Net

wor

k E

quip

men

t and

Inst

alla

tion

$0.0

0-

$

-

$

-

$

-

$

11

4N

etw

ork

com

mun

icat

ions

inst

alla

tion

cost

, Gas

Met

ers

Cap

exN

etw

ork

Equ

ipm

ent a

nd In

stal

latio

n$0

.01

-$

0.01

$

0.

01$

-$

115

Net

wor

k co

mm

unic

atio

ns L

TE

bac

khau

l cos

t, E

lect

ric M

eter

sO

pex

Bac

khau

l$0

.00

-$

-$

-$

-$

116

Net

wor

k co

mm

unic

atio

ns L

TE

bac

khau

l cos

t, G

as M

eter

sO

pex

Bac

khau

l$0

.11

-$

0.00

$

0.

00$

0.25

$

117

AM

F m

eter

cel

lula

r se

rvic

e co

st, E

lect

ric M

eter

sO

pex

Equ

ipm

ent a

nd In

stal

latio

n R

efre

sh C

ost

$0.0

0-

$

-

$

-

$

-

$

11

8N

etw

ork

com

mun

icat

ions

equ

ipm

ent c

ost u

pgra

deC

apex

Net

wor

k E

quip

men

t and

Inst

alla

tion

$0.1

4-

$

-

$

-

$

0.

29$

11

9A

MF

com

mun

icat

ions

faile

d eq

uipm

ent r

epla

cem

ent c

ost

Cap

exE

quip

men

t and

Inst

alla

tion

Ref

resh

Cos

t$0

.02

-$

-$

0.00

$

0.

05$

12

0A

MF

com

mun

icat

ions

equ

ipm

ent O

&M

cos

t (ou

tsid

e w

arra

nty)

Ope

xE

quip

men

t and

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alla

tion

Ref

resh

Cos

t$0

.05

-$

-$

-$

0.11

$

121

AM

F E

xter

nal P

roje

ct M

anag

emen

t lab

or c

ost -

Cap

ex p

ortio

nC

apex

Pro

ject

Man

agem

ent

$0.6

2-

$

0.

71$

-$

-$

123

Cos

t fro

m c

all c

ente

r an

d A

MO

, im

plem

enta

tion

Ope

xP

roje

ct M

anag

emen

t$0

.00

-$

-$

-$

-$

124

AM

F In

tern

al P

roje

ct M

anag

emen

t Lea

ders

hip

Sta

ff -

Cap

ex p

ortio

nC

apex

Pro

ject

Man

agem

ent

$0.2

5-

$

0.

15$

0.15

$

-

$

12

5A

MF

Inte

rnal

Pro

ject

Man

agem

ent B

usin

ess

Sup

port

- C

apex

por

tion

Cap

exP

roje

ct M

anag

emen

t$0

.85

0.45

$

0.

50$

-$

-$

126

AM

F e

lect

ric m

eter

inst

alla

tion

cost

- C

OR

por

tion

CO

RA

MF

Ele

ctric

Met

er E

quip

men

t and

Inst

alla

tion

$0.0

0-

$

-

$

-

$

-

$

12

8A

MF

Ext

erna

l Pro

ject

Man

agem

ent l

abor

cos

t - O

pex

port

ion

Ope

xP

roje

ct M

anag

emen

t$0

.64

0.69

$

-

$

-

$

-

$

12

9A

MF

Inte

rnal

Pro

ject

Man

agem

ent L

eade

rshi

p S

taff

- O

pex

port

ion

Ope

xP

roje

ct M

anag

emen

t$0

.13

0.15

$

-

$

-

$

-

$

13

0A

MF

Inte

rnal

Pro

ject

Man

agem

ent B

usin

ess

Sup

port

- O

pex

port

ion

Ope

xP

roje

ct M

anag

emen

t$0

.45

0.49

$

-

$

-

$

-

$

13

4A

MF

inve

ntor

y eq

uipm

ent c

ost

Cap

exA

MF

Inve

ntor

y$0

.00

-$

-$

-$

-$

135

Pro

fess

iona

l Ser

vice

s -

Fie

ld D

eplo

ymen

t Sup

port

Wor

kstr

eam

cos

tC

apex

Com

mun

icat

ion

Net

wor

k In

stal

latio

n M

anag

emen

t$0

.00

-$

-$

-$

-$

136

Pro

fess

iona

l Ser

vice

s -

Fie

ld D

eplo

ymen

t Sup

port

Wor

kstr

eam

Tra

vel E

xpen

ses

cost

Ope

xC

omm

unic

atio

n N

etw

ork

Inst

alla

tion

Man

agem

ent

$0.0

0-

$

-

$

-

$

-

$

201

Bac

k-O

ffice

Rev

enue

Ass

uran

ce A

naly

st c

ost

Ope

xO

ngoi

ng B

usin

ess

Man

agem

ent

$0.0

0-

$

-

$

-

$

-

$

20

2C

ost o

f the

ft in

vest

igat

ions

Ope

xO

ngoi

ng B

usin

ess

Man

agem

ent

$0.0

0-

$

-

$

-

$

-

$

20

3C

MS

Dep

loym

ent C

ente

r, F

acili

ty c

ost

Cap

exS

uppo

rt In

fras

truc

ture

$0.0

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$

-

$

-

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-

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20

4C

MS

Bac

k O

ffice

& C

leric

al c

ost

Cap

exS

uppo

rt In

fras

truc

ture

$0.0

0-

$

-

$

-

$

-

$

20

5S

ervi

ce R

epre

sent

ativ

e T

ools

/ U

nifo

rm c

ost

Cap

exS

uppo

rt In

fras

truc

ture

$0.0

0-

$

-

$

-

$

-

$

20

6In

stal

led

met

er Q

ualit

y A

ssur

ance

/ Q

ualit

y C

heck

cos

tC

apex

Sup

port

Infr

astr

uctu

re$0

.00

-$

-$

-$

-$

207

CM

S D

eplo

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t Coo

rdin

atio

n La

bor

cost

Cap

exS

uppo

rt In

fras

truc

ture

$0.0

0-

$

-

$

-

$

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$

20

8C

MS

Fie

ld In

stal

ler

Initi

al T

rain

ing

Cap

exS

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rt In

fras

truc

ture

$0.0

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-

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-

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-

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20

9C

MS

Cel

lula

r C

omm

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atio

n co

stC

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port

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re$0

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210

Han

dhel

d D

evic

es c

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Cap

exS

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rt In

fras

truc

ture

$0.0

0-

$

-

$

-

$

-

$

300

AM

F A

dditi

onal

Met

er D

ata

Ser

vice

s la

bor

cost

Ope

xO

ngoi

ng B

usin

ess

Man

agem

ent

$1.4

7-

$

0.

12$

0.25

$

2.

76$

30

1B

illin

g S

yste

m D

evel

opm

ent T

estin

gO

pex

Ong

oing

Bus

ines

s M

anag

emen

t$0

.00

-$

-$

-$

-$

302

MD

S S

yste

m D

evel

opm

ent T

estin

gC

apex

Sup

port

Infr

astr

uctu

re$0

.21

0.17

$

0.

06$

-$

-$

400

Cus

tom

er E

ngag

emen

t Pla

n C

ost

Ope

xC

usto

mer

Eng

agem

ent C

ost

$0.0

0-

$

-

$

-

$

-

$

501

CS

S E

nhan

cem

ents

Cap

ex C

ost

Cap

exC

usto

mer

Ser

vice

Sys

tem

$2.6

11.

89$

0.98

$

-

$

-

$

50

2P

rofe

ssio

nal S

ervi

ces

- H

ead

End

/MD

M S

olut

ion

Pro

gram

Man

agem

ent c

ost

Ope

xA

MF

Hea

d-en

d an

d M

eter

Dat

a M

anag

emen

t Sys

tem

s*$0

.77

0.10

$

0.

45$

0.36

$

-

$

50

3E

nerg

y M

onito

ring

Por

tal O

pex

Cos

tO

pex

Cus

tom

er E

ngag

emen

t Pro

duct

s an

d S

ervi

ces

$0.4

90.

04$

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$

-

$

1.

04$

50

4G

reen

But

ton

Con

nect

Cap

ex C

ost

Cap

exC

usto

mer

Eng

agem

ent P

rodu

cts

and

Ser

vice

s$0

.98

0.80

$

0.

27$

-$

-$

513

Tel

ecom

Cap

ex c

ost

Cap

exIS

Infr

astr

uctu

re$0

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$

0.

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$

-

$

51

4E

SB

Cap

ex c

ost

Cap

exIS

Infr

astr

uctu

re$2

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$

1.

06$

0.18

$

2.

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51

6In

form

atio

n M

anag

emen

t Cap

ex c

ost

Cap

exIS

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astr

uctu

re$0

.86

0.30

$

0.

35$

0.22

$

0.

23$

51

7D

ata

Lake

Cap

ex c

ost

Cap

exIS

Infr

astr

uctu

re$0

.08

0.09

$

-

$

-

$

-

$

51

8P

rofe

ssio

nal S

ervi

ces

- H

ead

End

/MD

M S

yste

ms

Impl

emen

tatio

n W

orks

trea

m c

ost

Ope

xA

MF

Hea

d-en

d an

d M

eter

Dat

a M

anag

emen

t Sys

tem

s*$

1.80

1.69

$

0.

26$

-$

-$

519

Saa

S S

etup

Fee

s -

One

Tim

e S

etup

(V

ersi

on u

pgra

de a

nd s

cale

-up

exis

ting

syst

em)

cost

Ope

xA

MF

Hea

d-en

d an

d M

eter

Dat

a M

anag

emen

t S

yste

ms*

$0.0

70.

07$

-$

-$

-$


43

AM

F C

osts

and

Ben

efits

(in m

illio

ns)

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 4

.1 -

AM

F C

osts

, RE

DA

CT

ED

Pag

e 9

of 9

520

Saa

S F

ees

- H

eade

nd S

oftw

are

(OW

OC

CM

, OW

OC

PM

, IE

E M

DM

, IoT

FN

D, F

DM

) co

stO

pex

AM

F H

ead-

end

and

Met

er D

ata

Man

agem

ent S

yste

ms*

$15.

42-

$

0.

29$

0.45

$

37

.28

$

#D

escr

ipti

on

Cat

ego

ryG

rou

pN

PV

FY

20

FY

21

FY

22

FY

23

- F

Y 3

9

CO

ST

S (

GA

S)

521

Pro

fess

iona

l Ser

vice

s -

Sys

tem

and

Met

er F

irmw

are

Upg

rade

cos

tO

pex

AM

F H

ead-

end

and

Met

er D

ata

Man

agem

ent S

yste

ms*

$0.2

1-

$

-

$

-

$

0.

37$

52

2T

elec

om O

pex

cost

Ope

xIS

Infr

astr

uctu

re$0

.00

-$

-$

-$

-$

523

Tel

ecom

RT

B C

ost

Ope

xIS

Infr

astr

uctu

re$2

.09

-$

0.03

$

0.

06$

4.78

$

524

ES

B O

pex

cost

Ope

xIS

Infr

astr

uctu

re$0

.18

0.07

$

0.

10$

0.03

$

-

$

52

5E

SB

RT

B C

ost

Ope

xIS

Infr

astr

uctu

re$1

.97

0.00

$

0.

03$

0.07

$

4.

48$

52

6D

ata

Lake

Ope

x co

stO

pex

IS In

fras

truc

ture

$0.7

50.

05$

0.04

$

0.

06$

1.41

$

527

Pro

fess

iona

l Ser

vice

s -

Hea

d E

nd/M

DM

Sol

utio

n P

rogr

am M

anag

emen

t Tra

vel E

xpen

ses

c oO

pex

AM

F H

ead-

end

and

Met

er D

ata

Man

agem

ent S

yste

ms*

$0.1

20.

01$

0.07

$

0.

05$

-$

528

Pro

fess

iona

l Ser

vice

s -

Hea

d E

nd/M

DM

Sys

tem

s Im

plem

enta

tion

Wor

kstr

eam

Tra

vel E

xpen

Ope

xA

MF

Hea

d-en

d an

d M

eter

Dat

a M

anag

emen

t Sys

tem

s*$0

.27

0.25

$

0.

04$

-$

-$

529

Gre

en B

utto

n C

onne

ct O

pex

Cos

tO

pex

Cus

tom

er E

ngag

emen

t Pro

duct

s an

d S

ervi

ces

$0.2

90.

19$

0.12

$

-

$

-

$

53

0In

form

atio

n M

anag

emen

t Ope

x co

stO

pex

IS In

fras

truc

ture

$0.1

70.

01$

0.01

$

0.

01$

0.32

$

531

Info

rmat

ion

Man

agem

ent R

TB

Cos

tO

pex

IS In

fras

truc

ture

$0.9

6-

$

0.

02$

0.03

$

2.

19$

53

2E

nerg

y M

onito

ring

Por

tal R

TB

Cos

tO

pex

Cus

tom

er E

ngag

emen

t Pro

duct

s an

d S

ervi

ces

$0.1

3-

$

0.

00$

0.00

$

0.

29$

53

3C

SS

Enh

ance

men

ts O

pex

Cos

tO

pex

Cus

tom

er S

ervi

ce S

yste

m$0

.10

0.00

$

0.

08$

0.02

$

0.

03$

53

4C

SS

Enh

ance

men

ts R

TB

Cos

tO

pex

Cus

tom

er S

ervi

ce S

yste

m$0

.06

-$

-$

0.00

$

0.

16$

53

5G

reen

But

ton

Con

nect

RT

B C

ost

Ope

xC

usto

mer

Eng

agem

ent P

rodu

cts

and

Ser

vice

s$1

.53

-$

0.04

$

0.

06$

3.44

$

536

Dat

a La

ke R

TB

cos

tO

pex

IS In

fras

truc

ture

$0.4

0-

$

0.

01$

0.02

$

0.

91$

600

Cyb

er S

ecur

ity P

roje

ct C

apex

Initi

alC

apex

Cyb

er S

ecur

ity$2

.57

1.51

$

0.

89$

0.50

$

-

$

60

1C

yber

Sec

urity

Pro

ject

Ope

x In

itial

Ope

xC

yber

Sec

urity

$1.1

50.

71$

0.37

$

0.

21$

-$

602

Cyb

er S

ecur

ity P

roje

ct R

TB

O&

MO

pex

Cyb

er S

ecur

ity$1

.66

0.03

$

0.

04$

0.05

$

3.

90$

60

3C

yber

Sec

urity

Ref

resh

/ R

emov

al C

apita

l C

apex

Cyb

er S

ecur

ity$2

.79

-$

-$

-$

6.67

$

604

Cyb

er S

ecur

ity C

apita

l Ref

resh

/ R

emov

al O

pex

Ope

xC

yber

Sec

urity

$1.3

9-

$

-

$

0.

00$

3.12

$

To

tal C

ost

$49.

73$1

0.47

$7.2

1$2

.96

$76.

08

100-

400'

sC

apex

2.33

$

0.

66$

1.50

$

0.

32$

0.35

$

Ope

x2.

85$

1.32

$

0.

12$

0.25

$

3.

12$

T

otal

5.19

$

1.

98$

1.62

$

0.

57$

3.47

$

500'

sC

apex

7.21

$

3.

72$

2.68

$

0.

41$

2.24

$

Ope

x27

.78

$

2.

51$

1.61

$

1.

22$

56.6

9$

Tot

al34

.99

$

6.

23$

4.29

$

1.

63$

58.9

3$

600'

sC

apex

5.36

$

1.

51$

0.89

$

0.

50$

6.67

$

Ope

x4.

19$

0.74

$

0.

41$

0.27

$

7.

01$

T

otal

9.55

$

2.

25$

1.30

$

0.

77$

13.6

8$

Tot

al C

apex

14.9

0$

5.89

$

5.

07$

1.23

$

9.

25$

Tot

al O

pen

34.8

3$

4.57

$

2.

14$

1.74

$

66

.83

$


44

Workpaper 5.1


Witness: Nouel

Workpaper 5.1

Electric Transport Costs / Assumptions

45

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

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THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 5.1 - Electric Transport Costs/Assumptions Page 1 of 12

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of

Dis

coun

t per

KW

$4.9

716

Ann

ual V

alue

of

Dis

coun

t per

KW

$59.

5817 18

Sta

tion

sB

ille

d K

W p

er S

tati

onK

W f

or G

roup

Tot

al D

isco

unt

19S

tati

ons

in Y

ear

120

4590

0$5

3,62

220

Sta

tion

s in

Yea

r 2

3067

.520

25$1

20,6

5021

Sta

tion

s in

Yea

r 3

4090

3600

$214

,488


54

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 5

.1 -

Ele

ctri

c T

rasn

port

Cos

ts/A

ssum

ptio

ns

10 o

f 12

Cos

t E

stim

ates

Tra

nsp

orta

tion

Ed

uca

tion

an

d O

utr

each

1Y

ear

1Y

ear

2Y

ear

3T

otal

2C

hann

el3

Dir

ect M

aili

ngs

4B

ill i

nser

ts/O

pow

er r

epor

ts/e

tc$1

5,00

0$1

5,00

0$2

2,00

0$5

2,00

05

Exi

stin

g C

hann

els

6R

ide-

n-D

rive

Eve

nts

$10,

000

$40,

000

$40,

000

$90,

000

7W

ebsi

te8

EV

Edu

cati

on &

Aw

aren

ess

Pag

e$5

,000

$10,

000

$25,

000

$40,

000

9S

ocia

l Med

ia10

Fac

eboo

k$4

,000

$4,0

00$5

,000

$13,

000

11T

wit

ter

$1,5

00$1

,500

$3,0

00$6

,000

12In

stag

ram

$4,0

00$4

,000

$4,0

00$1

2,00

013

Gen

eral

Aw

aren

ess

Adv

erti

sing

14B

illb

oard

or

Rad

io$1

0,00

0$2

0,00

0$4

5,00

0$7

5,00

015

Dig

ital

16O

nlin

e B

anne

rs a

nd S

EO

/SE

M$5

,000

$10,

000

$15,

000

$30,

000

17C

onte

nt D

evel

opm

ent

18A

genc

y C

ontr

act

$10,

000

$10,

000

$10,

000

$30,

000

19In

tern

al M

arke

ting

Pro

gram

Man

agem

ent

20S

taff

Tim

e$4

9,47

0$5

0,45

9$5

1,46

8$1

51,3

9721

TO

TA

L C

OS

TS

$113

,970

$164

,959

$220

,468

$499

,397


55

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 5

.1 -

Ele

ctri

c T

rasn

port

Cos

ts/A

ssum

ptio

ns

11 o

f 12

Cos

t E

stim

ates

Com

pan

y F

leet

Exp

ansi

on

1Y

ear

1Y

ear

2Y

ear

3T

otal

2E

xpen

se (

Veh

icle

Lea

se a

nd O

&M

)64

,000

$

12

8,00

0$

192,

000

$

38

4,00

0$

3C

apit

al (

EV

SE

)20

0,00

0$

200,

000

$

4 5

Cos

t Bre

akdo

wn

6 7In

crem

enta

l Veh

icle

Lea

se C

ost p

er V

e h80

000

8L

ease

Ter

m10

9A

nnua

l Inc

rem

enta

l Veh

icle

Lea

se C

ost

8,00

0$

10 11

Ann

ual S

uppo

rt/M

aint

enan

ce8,

000

$

13 14C

umul

ativ

e V

ehic

les

48

1215

Veh

icle

Cos

t32

,000

$

64

,000

$

96

,000

$

19

2,00

0$

16O

&M

Cos

t32

,000

$

64

,000

$

96

,000

$

19

2,00

0$

17T

otal

Exp

ense

64,0

00$

128,

000

$

192,

000

$

38

4,00

0$

23 24E

VS

E25

Cos

t Per

Por

t (L

2)16

,667

$

26

Por

ts12

27E

VS

E c

ost

200,

000

$

20

0,00

0$

28 29T

otal

Cos

t26

4,00

0$

128,

000

$

19

2,00

0$

584,

000

$

30

Lin

e N

otes

Lin

e 7-

11:

NG

Fle

et D

epar

tmen

t


56

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 5

.1 -

Ele

ctri

c T

rasn

port

Cos

ts/A

ssum

ptio

ns

12 o

f 12

Cos

t E

stim

ates

Init

iati

ve E

valu

atio

nY

ear

1Y

ear

2Y

ear

3T

otal

Ann

ual 3

rd-p

arty

eva

luat

ion

repo

rts

30,0

00$

30,0

00$

30

,000

$

90

,000

$


57

W

orkpaper 6.1


Witness: Miller

Workpaper 6.1

Electric Heat Costs / Assumptions

58

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 6

.1 -

Ele

ctri

c H

eat C

osts

/Ass

umpt

ions

Pag

e 1

of 5

Ele

ctri

c H

eat

Init

iati

ve -

Cos

t S

um

mar

y

1T

otal

Cos

ts b

y P

rogr

am T

ype

2Y

ear

1Y

ear

2Y

ear

33-

Yea

r T

otal

3G

SH

P P

rogr

am-

$

595,

000

$

-$

59

5,00

0$

4E

quip

men

t Inc

enti

ves

252,

140

$

280,

890

$

309,

640

$

842,

670

$

5

Com

mun

ity-

Bas

ed O

utre

ach

95,5

00$

95,5

00$

95,5

00$

286,

500

$

6

Oil

Dea

ler

Tra

inin

g an

d S

uppo

rt61

,000

$

61

,000

$

61

,000

$

18

3,00

0$

9T

otal

408,

640

$

1,03

2,39

0$

466,

140

$

1,90

7,17

0$

10 11P

rogr

am C

osts

by

Typ

e of

Exp

ense

12Y

ear

1Y

ear

2Y

ear

33-

Yea

r T

otal

13O

&M

Sub

tota

l40

8,64

0$

53

2,39

0$

46

6,14

0$

1,

407,

170

$

14

Cap

ital

Sub

tota

l-

$

500,

000

$

-$

50

0,00

0$

15T

otal

408,

640

$

1,03

2,39

0$

466,

140

$

1,90

7,17

0$

16 17S

um

mar

y b

y In

itia

tive

18Y

ear

1Y

ear

2Y

ear

33-

Yea

r T

otal

19 G

SH

P P

rogr

am

20 C

apit

al

-$

50

0,00

0$

-

$

500,

000

$

21

Exp

ense

-

$

95,0

00$

-$

95

,000

$

22

Equ

ipm

ent I

ncen

tive

s 23

Cap

ital

-

$

-$

-

$

-$

24 E

xpen

se

252,

140

$

280,

890

$

309,

640

$

842,

670

$

25 C

omm

unit

y-B

ased

Out

reac

h 26

Cap

ital

-

$

-$

-

$

27 E

xpen

se

95,5

00$

95,5

00$

95,5

00$

286,

500

$

28

Oil

Dea

ler

Tra

inin

g an

d S

uppo

rt

29 C

apit

al

30 E

xpen

se

61,0

00$

61,0

00$

61,0

00$

183,

000

$

36

Tot

al

408,

640

$

1,03

2,39

0$

466,

140

$

1,90

7,17

0$

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 6.1 - Electric Heat Costs/Assumptions Page 1 of 5

59

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 6

.1 -

Ele

ctri

c H

eat C

osts

/Ass

umpt

ions

Pag

e 2

of 5

Cos

t E

stim

ates

GS

HP

Pro

gram

Yea

r 1

Yea

r 2

Yea

r 3

Tot

al1

NG

Pro

gram

Man

ager

FT

E -

Pro

gram

Man

ager

Lab

or-

$

27,1

15$

-

$

27,1

15$

2G

SH

P S

yste

m D

esig

n-

$

50,0

00$

-

$

50,0

00$

6P

rogr

am M

arke

ting

-$

17

,885

$

-$

17

,885

$

7-

$

95,0

00$

-

$

95,0

00$

8 9F

TE

Cal

cula

tion

10F

TE

per

yea

r0

0.25

011

2018

Lab

or R

ate

(Pro

g M

gr)

95,0

00$

14

Lab

or B

urde

n14

.17%

15F

ully

Bur

dene

d L

abor

Rat

e10

8,46

2$

108,

462

$

10

8,46

2$


60

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 6

.1 -

Ele

ctri

c H

eat C

osts

/Ass

umpt

ions

Pag

e 3

of 5

Cos

t E

stim

ates

Eq

uip

men

t In

cen

tive

sY

ear

1Y

ear

2Y

ear

3T

otal

1N

G P

rogr

am M

anag

er F

TE

- E

E P

rogr

am M

anag

er L

abor

27,1

15$

27

,115

$

27,1

15$

81

,346

$

2

Ince

ntiv

es20

7,50

0$

236,

250

$

26

5,00

0$

708,

750

$

3

Pro

gram

Mar

keti

ng17

,525

$

17,5

25$

17

,525

$

52,5

74$

425

2,14

0$

280,

890

$

30

9,64

0$

842,

670

$

5 6

Ince

ntiv

es C

alcu

lati

on7

Ind

icat

ive

AS

HP

reb

ate

($/t

on)

500

$

500

$

500

$

8 A

SH

P to

nnag

e ta

rget

400

450

500

9 A

SH

P s

ubto

tal

200,

000

$

22

5,00

0$

250,

000

$

67

5,00

0$

10 11 I

ndic

ativ

e G

SH

P r

ebat

e ($

/ton

)75

0$

75

0$

75

0$

12

GS

HP

tonn

age

targ

et10

1520

13 G

SH

P s

ubto

tal

7,50

0$

11,2

50$

15

,000

$

33,7

50$

14T

otal

207,

500

$

23

6,25

0$

265,

000

$

70

8,75

0$

15 16F

TE

Cal

cula

tion

17F

TE

per

yea

r0.

250.

250.

2518

2018

Lab

or R

ate

(EE

Pro

g M

gr)

95,0

00$

19

Lab

or B

urde

n14

.17%

20F

ully

Bur

dene

d L

abor

Rat

e10

8,46

2$

108,

462

$

10

8,46

2$


61

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 6

.1 -

Ele

ctri

c H

eat C

osts

/Ass

umpt

ions

Pag

e 4

of 5

Cos

t E

stim

ates

Com

mu

nit

y-B

ased

Ou

trea

chY

ear

1Y

ear

2Y

ear

3T

otal

1N

G P

rogr

am M

anag

er F

TE

- E

E P

rogr

am M

anag

er L

abor

27,1

15$

27

,115

$

27,1

15$

81

,346

$

2

Com

mun

ity

Ince

ntiv

es60

,000

$

60,0

00$

60

,000

$

180,

000

$

3

Pro

gram

Des

ign

Con

sult

ing

8,38

5$

8,38

5$

8,38

5$

25,1

54$

495

,500

$

95,5

00$

95

,500

$

286,

500

$

5 6

Ince

ntiv

es C

alcu

lati

on7

Inc

enti

ve b

udge

t per

com

mun

ity

20,0

00$

20

,000

$

20,0

00$

8

Com

mun

itie

s3

33

9 T

otal

60,0

00$

60

,000

$

60,0

00$

18

0,00

0$

10 11F

TE

Cal

cula

tion

12F

TE

per

yea

r0.

250.

250.

2513

2018

Lab

or R

ate

(EE

Pro

g M

gr)

95,0

00$

14

Lab

or B

urde

n14

.17%

15F

ully

Bur

dene

d L

abor

Rat

e10

8,46

2$

108,

462

$

10

8,46

2$


62

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 6

.1 -

Ele

ctri

c H

eat C

osts

/Ass

umpt

ions

Pag

e 5

of 5

Cos

t E

stim

ates

Oil

Dea

ler

Tra

inin

g an

d S

up

por

tY

ear

1Y

ear

2Y

ear

3T

otal

1N

G P

rogr

am M

anag

er F

TE

- E

E P

rogr

am M

anag

er L

abor

27,1

15$

27

,115

$

27,1

15$

81

,346

$

2

Tra

inin

g P

rogr

am M

arke

ting

8,88

5$

8,88

5$

8,88

5$

26,6

54$

3T

rain

ing

Pro

gram

Con

sult

ant

25,0

00$

25

,000

$

25,0

00$

75

,000

$

461

,000

$

61,0

00$

61

,000

$

183,

000

$

5 6

FT

E C

alcu

lati

on7

FT

E p

er y

ear

0.25

0.25

0.25

820

18 L

abor

Rat

e (E

E P

rog

Mgr

)95

,000

$

9L

abor

Bur

den

14.1

7%10

Ful

ly B

urde

ned

Lab

or R

ate

108,

462

$

10

8,46

2$

108,

462

$


63

W

orkpaper 7.1


Witnesses: Nouel, Perkinson

Workpaper 7.1

Energy Storage Costs / Assumptions

64

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 7

.1 -

Ene

rgy

Sto

rage

Cos

ts/A

ssum

ptio

nsP

age

1 of

2

Ove

rall

Sto

rage

CA

PE

X C

ost

Est

imat

es

Sit

eT

ype

Siz

e un

its

Cos

t per

uni

t $/W

(h)

Fro

m E

xhib

it s

pp2

Cap

ital

in $

M f

or

Dev

elop

men

t

Est

imat

ed 3

%

Pro

ject

M

anag

emen

t C

ost (

$)

Est

imat

ed 1

.25%

C

omm

issi

onin

g co

st (

$)

Est

imat

ed

15%

Nat

iona

l G

rid

Cap

ital

O

verh

ead

All

ocat

ions

($)

Tot

al

Ow

ners

hip

Cos

t ($)

N

umbe

r of

in

vert

ers

Num

ber

of

mod

ules

(@

30

0 w

att)

Est

imat

ed

Lea

se r

ate

$k/M

W f

or

sola

r or

$k

/MW

h fo

r st

orag

e

Lea

se p

er y

ear

CY

201

6 P

rope

rty

Tax

es

1S

tora

ge50

0kW

h$1

,500

$750

,000

$2

2,50

0$9

,375

$112

,500

$894

,375

4N

/A10

$5,0

002

Sto

rage

75

0kW

h$1

,500

$1,1

25,0

00

$33,

750

$14,

063

$168

,750

$1,3

41,5

634

N/A

10$7

,500

3.00

%1.

25%

15%

Tot

al

$2,2

35,9

38T

otal

$1

2,50

0

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 7.1 - Energy Storage Costs/Assumptions Page 1 of 2

65

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 7

.1 -

Ene

rgy

Sto

rage

Cos

ts/A

ssum

ptio

nsP

age

2 of

2E

stim

ated

Mid

-Poi

nt

Su

mm

ary

of C

osts

AB

-1B

-2C

-1C

-2D

EF

GH

-1H

-2H

-3I

Siz

e R

ange

(kW

)T

arge

ted

Tot

al

Sol

ar I

nsta

lled

pe

r R

ange

(k

W)

Tar

gete

d T

otal

S

yste

m

Enh

ance

men

ts

(kW

)

Mid

-poi

nt C

ost

for

Dev

elop

men

t of

Sol

ar (

$/kW

)

Mid

-poi

nt C

ost

for

Dev

elop

men

t of

Sys

tem

E

nhan

cem

ents

($

/kW

)

Tot

al M

id-

poin

t Sub

tota

l C

osts

($)

for

D

evel

opm

ent

Est

imat

ed 1

.5%

P

roje

ct

Man

agem

ent

Cos

t ($)

Est

imat

ed 1

.25%

C

omm

issi

onin

g co

st (

$)

Est

imat

ed 1

5%

Nat

iona

l Gri

d C

apit

al O

verh

ead

All

ocat

ions

($)

Mid

-poi

nt o

f T

otal

Ow

ners

hip

Cos

t ($)

(S

olar

)

Mid

-poi

nt o

f T

otal

Ow

ners

hip

Cos

t ($)

(Sys

tem

E

nhan

cem

ents

)

Tot

al M

id-p

oint

C

ost o

f O

wne

rshi

p ($

)

Mid

-poi

nt T

otal

fo

r ow

ners

hip

in

($/k

W)

9E

ner g

y S

tora

ge-

7,00

0-

$1,5

00

$10,

500,

000

$157

,500

$131

,250

$1,6

18,3

13-

$12,

407,

063

-1,

772

$

Lin

e 9

Col

umn

A =

Ene

rgy

Sto

rage

L

ine

9 C

olum

n C

2 =

Mid

-poi

nt d

evel

opm

ent c

ost f

or s

yste

m e

nhan

cem

ents

L

ine

9 C

olum

n D

= M

id-p

oint

of

deve

lopm

ent c

ost b

ased

on

the

targ

eted

kW

siz

e. C

olum

n B

mul

tipl

ied

by C

olum

n C

Lin

e 9

Col

umn

E =

Est

imat

ed P

roje

ct M

anag

emen

t fee

incu

rred

by

the

Com

pany

to p

rovi

de o

vers

ight

and

gui

danc

e to

dev

elop

ers

on d

evel

opm

ent i

ssue

s; e

stim

ated

at 1

.5%

of

the

deve

lopm

ent c

ost

Lin

e 9

Col

umn

F =

Est

imat

ed C

omm

issi

onin

g fe

e in

curr

ed b

y th

e C

ompa

ny to

ens

ure

inst

alle

d sy

stem

s ar

e in

stal

led

and

oper

atin

g as

des

ired

; est

imat

ed a

t 1.2

5% o

f th

e de

velo

pmen

t cos

tL

ine

9 C

olum

n G

= E

stim

ated

Com

pany

ove

rhea

d al

loca

tion

s fo

r bl

anke

t wor

k or

der

Cap

ital

Pro

ject

s; e

stim

ated

at 1

5% o

f th

e de

velo

pmen

t cos

tL

ine

9 C

olum

n H

-2 =

Sum

of

Col

umn

D th

roug

h H

(S

yste

m E

nhan

cem

ent C

osts

)L

ine

9 C

olum

n I

= C

olum

n H

div

ided

by

Col

umn

BL

ine

9 re

pres

ents

a s

yste

m e

nhan

cem

ent f

or li

thiu

m-i

on b

atte

ry s

yste

ms

in th

e 1

MW

h to

4 M

Wh

rang

e

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 7.1 - Energy Storage Costs/Assumptions Page 2 of 2

66

Workpaper 8.1


Witnesses: Nouel, Perkinson

Workpaper 8.1

Solar Costs / Assumptions

67

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 8

.1 -

Sol

ar C

osts

/Ass

umpt

ions

Pag

e 1

of 3

Ove

rall

Sol

ar C

AP

EX

Cos

t E

stim

ates

AB

CD

EF

GH

IJ

KL

MN

OP

Sit

eT

ype

Siz

e un

its

Cos

t per

uni

t $/W

(h)

Fro

m E

xhib

it s

pp2

Cap

ital

in $

M f

or

Dev

elop

men

t

Est

imat

ed 3

%

Pro

ject

M

anag

emen

t C

ost (

$)

Est

imat

ed 1

.25%

C

omm

issi

onin

g co

st (

$)

Est

imat

ed 1

5%

Nat

iona

l Gri

d C

apit

al

Ove

rhea

d A

lloc

atio

ns (

$)

Tot

al

Ow

ners

hip

Cos

t ($)

Pro

gram

Cos

t U

sed

in B

CA

($

)

Num

ber

of

inve

rter

s

Num

ber

of

mod

ules

(@

300

w

att)

Est

imat

ed L

ease

rat

e $k

/MW

for

sol

ar o

r $k

/MW

h fo

r st

orag

e L

ease

per

yea

rC

Y 2

016

Pro

pert

y T

axes

1S

olar

Can

opy

(par

king

lot)

250

kW$4

,450

$1

,112

,500

$3

3,37

5$1

3,90

6$1

66,8

75$1

,326

,656

$1,3

37,5

005

833

35$8

,750

2S

olar

Can

opy

(par

king

lot)

500

kW$4

,263

$2,1

31,5

00

$63,

945

$26,

644

$319

,725

$2,5

41,8

14$2

,550

,000

1016

6730

$15,

000

3S

olar

15

00kW

$2,8

93$4

,339

,500

$1

30,1

85$5

4,24

4$6

50,9

25$5

,174

,854

$5,1

75,0

0010

1667

30$4

5,00

03.

00%

1.25

%15

%

Tot

al

$9,0

43,3

24T

otal

$6

8,75

0

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 8.1 - Solar Costs/Assumptions Page 1 of 3

68

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 8

.1 -

Sol

ar C

osts

/Ass

umpt

ions

Pag

e 2

of 3

Su

mm

ary

Of

Est

imat

ed A

nn

ual

Op

erat

ion

Cos

ts

A

BC

DE

1S

ize

Ran

ge (

kW)

60 to

200

201

to 5

0050

1 to

1,0

0010

01 to

5,0

002

Tar

gete

d T

otal

Sol

ar I

nsta

lled

per

Ran

ge (

kW)

075

00

1,50

03

Est

imat

ed N

umbe

r of

Sys

tem

s0

20

14

Ann

ual s

yste

m O

&M

-$

14,2

50$

-

$

24

,000

$

5

Sit

e m

aint

enan

ce-

$

12

,000

$

-$

19,2

00$

6N

Gri

d ov

ersi

ght,

repo

rtin

g, a

nd a

naly

sis

-$

9,37

5$

-$

18,7

50$

7S

yste

m E

nhan

cem

ent M

aint

enan

ce1

-$

3,75

0$

-$

-$

9T

otal

yea

r 1

O&

M c

osts

-$

39,3

75$

-

$

61

,950

$

Lin

e 1

= T

he s

ize

of s

yste

ms

in k

ilow

atts

(kW

) in

stal

led

in a

ran

geL

ine

2 =

Tar

gete

d ki

low

atts

(kW

) of

dir

ect c

urre

nt (

DC

) of

the

Pho

tovo

ltai

c sy

stem

s in

a r

ange

Lin

e 3

= A

vera

ge n

umbe

r of

sys

tem

s in

stal

led

in e

ach

rang

eL

ine

4 =

Est

imat

ed c

ost o

f an

nual

ope

rati

on a

nd m

aint

enan

ce is

$19

/kW

(60

-100

0)kW

& $

16/k

W (

1000

-500

0)kW

bas

ed o

n N

RE

L (

upda

ted

Feb

201

6)

Lin

e 5

= C

ost o

f si

te m

aint

enan

ce, a

ssum

es $

300

per

mon

th f

or s

yste

ms

in th

e ra

nge

60 to

200

kW

,

$

500

per

mon

th f

or s

yste

ms

bet

wee

n 20

0 an

d 50

0 kW

, $80

0 pe

r m

onth

for

sys

tem

s be

twee

n 50

0 an

d 1,

000

kW a

nd $

1600

per

mon

th f

or s

yste

ms

betw

een

1001

and

5,0

00 k

WL

ine

6 =

Est

imat

ed c

ost o

f N

atio

nal G

rid

to o

vers

ee a

nnua

l ope

rati

on, m

aint

enan

ce a

nd m

onit

orin

g of

sys

tem

s, r

epor

ting

to s

tate

and

loca

l age

ncie

s ($

12.5

/kW

)L

ine

7 =

Sys

tem

Enh

ance

men

t Mai

nten

ance

(T

rack

ing,

Can

opy,

etc

.) (

est.

$5/k

W)

Lin

e 9

= s

um o

f li

nes

4 th

roug

h 8,

equ

als

cost

per

yea

rC

olum

n F

= T

otal

, sum

of

Col

umns

B +

C +

D +

E.

1 Wil

l onl

y be

app

lied

to s

ite

wit

h S

yste

m E

nhan

cem

ents

inst

alle

d (e

x. T

rack

ing)


69

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 8

.1 -

Sol

ar C

osts

/Ass

umpt

ions

Pag

e 3

of 3

Est

imat

ed M

id-P

oin

t S

um

mar

y of

Cos

ts

AB

-1B

-2C

-1C

-2D

EF

GH

-1H

-2H

-3I

Siz

e R

ange

(kW

)T

arge

ted

Tot

al S

olar

In

stal

led

per

Ran

ge (

kW)

Tar

gete

d T

otal

S

yste

m

Enh

ance

me

nts

(kW

)

Mid

-poi

nt

Cos

t for

D

evel

opm

ent

of

Sol

ar

($/k

W)

Mid

-poi

nt C

ost f

or

Dev

elop

men

t of

Sys

tem

E

nhan

cem

ents

($

/kW

)

Tot

al M

id-p

oint

Sub

tota

l C

osts

($)

for

Dev

elop

men

tE

stim

ated

1.5

%

Pro

ject

M

anag

emen

t C

ost (

$)

Est

imat

ed 1

.25%

C

omm

issi

onin

g co

st (

$)

Est

imat

ed 1

5%

Nat

iona

l Gri

d C

apit

al

Ove

rhea

d A

lloc

atio

ns (

$)

Mid

-poi

nt o

f T

otal

O

wne

rshi

p C

ost (

$)

(Sol

ar)

Mid

-poi

nt o

f T

otal

O

wne

rshi

p C

ost (

$) (

Syst

em

Enh

ance

men

ts)

Tot

al M

id-

poin

t Cos

t of

Ow

ners

hip

($)

Mid

-poi

nt

Tot

al f

or

owne

rshi

p in

($/

kW)

160

to 2

001,

000

-$3

,476

-

$3,4

76,0

00

$52,

140

$43,

450

$535

,739

$4,1

07,3

29-

-4,

107

$

2

200

to 5

002,

000

-$3

,113

-

$6,2

26,0

00

$93,

390

$77,

825

$959

,582

$7,3

56,7

97-

-3,

678

$

3

500

to 1

,000

5,00

0-

$2,9

26

-$1

4,63

0,00

0 $2

19,4

50$1

82,8

75$2

,254

,849

$17,

287,

174

--

3,45

7$

41,

000

to 5

,000

6,00

0-

$2,8

93

-$1

7,35

8,00

0 $2

60,3

70$2

16,9

75$2

,675

,302

$20,

510,

647

--

3,41

8$

5C

anop

y (M

ulti

-lev

el p

arki

ng

-1,

000

-$2

,314

$2

,314

,000

$3

4,71

0$2

8,92

5$3

56,6

45-

$2,7

34,2

80-

2,73

4$

6C

anop

y (p

arki

ng lo

t)-

2,00

0-

$1,3

37

$2,6

74,0

00

$40,

110

$33,

425

$412

,130

-$3

,159

,665

-1,

580

$

7

Tra

ckin

g si

ngle

axi

s-

3,00

0-

$330

$9

90,0

00

$14,

850

$12,

375

$152

,584

-$1

,169

,809

-39

0$

8

Tra

ckin

g du

al a

xis

-1,

000

-$5

00

$500

,000

$7

,500

$6,2

50$7

7,06

3-

$590

,813

-59

1$

Lin

e 1-

4 C

olum

n A

= S

ize

of s

yste

m in

kil

owat

ts (

kW)

dc in

stal

led

wit

hin

a kW

ran

ge in

pre

-sel

ecte

d co

mm

unit

ies

Lin

e 5-

8 C

olum

n A

= S

yste

m E

nhan

cem

ents

incl

udin

g: C

anop

y S

olar

and

Tra

ckin

g (t

o be

inst

alle

d w

ith

Sol

ar)

Lin

e 1-

4 C

olum

n C

1 =

Mid

-poi

nt d

evel

opm

ent c

ost f

or P

V s

yste

ms

inst

alle

d w

ithi

n a

kW r

ange

take

n fr

om p

ubli

c re

cord

s of

the

Mas

sach

uset

ts D

OE

R S

RE

C p

rogr

am a

nd th

e C

ompa

nies

exp

erie

nce

in it

s S

olar

Pha

se I

& S

olar

Pha

se I

I P

rogr

ams

Lin

e 5-

8 C

olum

n C

2 =

Mid

-poi

nt d

evel

opm

ent c

ost f

or s

yste

m e

nhan

cem

ents

(L

ines

5-8

) to

PV

sys

tem

s in

stal

led

wit

hin

a kW

ran

ge ta

ken

from

pub

lic

reco

rds

of th

e M

assa

chus

etts

DO

ER

SR

EC

pro

gram

and

NR

EL

rep

orts

Lin

e 1-

8 C

olum

n D

= M

id-p

oint

of

deve

lopm

ent c

ost b

ased

on

the

targ

eted

kW

siz

e. C

olum

n B

mul

tipl

ied

by C

olum

n C

Lin

e 1-

8 C

olum

n E

= E

stim

ated

Pro

ject

Man

agem

ent f

ee in

curr

ed b

y th

e C

ompa

ny to

pro

vide

ove

rsig

ht a

nd g

uida

nce

to d

evel

oper

s on

dev

elop

men

t iss

ues;

est

imat

ed a

t 1.5

% o

f th

e de

velo

pmen

t cos

tL

ine

1-8

Col

umn

F =

Est

imat

ed C

omm

issi

onin

g fe

e in

curr

ed b

y th

e C

ompa

ny to

ens

ure

inst

alle

d sy

stem

s ar

e in

stal

led

and

oper

atin

g as

des

ired

; est

imat

ed a

t 1.2

5% o

f th

e de

velo

pmen

t cos

tL

ine

1-8

Col

umn

G =

Est

imat

ed C

ompa

ny o

verh

ead

allo

cati

ons

for

blan

ket w

ork

orde

r C

apit

al P

roje

cts;

est

imat

ed a

t 15%

of

the

deve

lopm

ent c

ost

Lin

e 1-

4 C

olum

n H

-1 =

Sum

of

Col

umn

D th

roug

h H

(S

olar

Cos

t)L

ine

5-8

Col

umn

H-2

= S

um o

f C

olum

n D

thro

ugh

H (

Sys

tem

Enh

ance

men

t Cos

ts)

Lin

e 1-

8 C

olum

n I

= C

olum

n H

div

ided

by

Col

umn

BL

ine

1-4

Col

umn

J =

Est

imat

ed n

umbe

r of

sys

tem

s in

stal

led

wit

hin

a ra

nge;

Col

umn

B d

ivid

ed b

y A

vera

ge o

f C

olum

n A

Lin

e 5

repr

esen

ts a

sys

tem

enh

ance

men

t for

sol

ar c

anop

ies

on to

p of

mul

ti-s

tory

par

king

gar

ages

in th

e 50

0 kW

to 1

000

kW r

ange

Lin

e 6

repr

esen

ts a

sys

tem

enh

ance

men

t for

sol

ar c

anop

ies

in s

urfa

ce-l

evel

par

king

lots

in th

e 20

0 kW

to 5

00 k

W r

ange

Lin

e 7

repr

esen

ts a

sys

tem

enh

ance

men

t for

sin

gle-

axis

trac

king

sys

tem

s in

the

1,00

0 kW

to 5

,000

kW

ran

geL

ine

8 re

pres

ents

a s

yste

m e

nhan

cem

ent f

or d

ual-

axis

trac

king

sys

tem

s in

the

200

kW to

500

kW

ran

ge


70

W

orkpaper 9.1


Witnesses: McGuinness, Roughan

Workpaper 9.1

Peak Demand Reduction Targets

71

TH

E N

AR

RA

GA

NS

ET

T E

LE

CT

RIC

CO

MP

AN

Yd/

b/a

NA

TIO

NA

L G

RID

RIP

UC

Doc

ket N

o. 4

770

Wor

kpap

er 9

.1 -

Pea

k D

eman

d R

educ

tion

Tar

gets

Pag

e 1

of 9

2019

2020

2021Basis Points

Minim

um

22

18

19

6

Target

29

26

26

12

Maxim

um

38

31

31

18

2019

2020

2021Basis Points

Minim

um

28

23

26

1

Target

36

34

36

1.75

Maxim

um

47

44

46

2.5

Annual Peak R

eduction Targets(M

Ws) and Basis Points

Annual Sum of Monthly Peak R

eduction Targets(M

Ws) and Basis Points

Summary of Forw

ard Cap

acity Market an

d M

onthly Transm

ission Peak Reduction Targets

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 9.1 - Peak Demand Reduction Targets Page 1 of 9

72

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mw

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tm

w_e

em

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v

RH

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E IS

LA

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MM

ER

Ind

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t 50

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ks (

MW

)

(b

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re &

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er D

ER

s)

EE

% o

fP

V %

of

Cal

end

arR

eco

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itu

ted

Fin

al F

ore

cast

Fin

al F

ore

cast

EE

Red

uct

ion

PV

Red

uct

ion

'Rec

on

stit

ute

d'

'Rec

on

stit

ute

d'

An

nu

al E

E im

pac

tA

nn

ual

So

lar

imp

act

Cumulative EE

impact starting

2019

PV im

pact

starting 2019

Post‐2018

reconstituted

Yea

r(b

efo

re r

edu

ctio

ns)

w/ E

E R

edu

ctio

n o

nly

(aft

er a

ll re

du

ctio

ns)

Fo

reca

stF

ore

cast

Del

iver

ies

Del

iver

ies

2003

1,81

31,

803

1,80

39

00.

5%0.

0%20

041,

860

1,83

91,

839

210

1.1%

0.0%

11.9

020

051,

802

1,77

21,

772

300

1.7%

0.0%

90

2006

1,84

41,

803

1,80

341

02.

2%0.

0%11

020

071,

902

1,85

21,

852

510

2.7%

0.0%

100

2008

1,87

81,

817

1,81

761

03.

3%0.

0%10

020

091,

893

1,81

61,

816

770

4.0%

0.0%

150

2010

1,88

71,

798

1,79

889

04.

7%0.

0%12

020

111,

919

1,81

81,

817

102

05.

3%0.

0%13

0.23

016

2012

1,94

41,

823

1,82

212

10

6.2%

0.0%

190.

1818

620

131,

968

1,82

01,

817

148

27.

5%0.

1%27

2.05

758

2014

2,00

11,

814

1,81

118

74

9.3%

0.2%

391.

1751

620

152,

075

1,85

51,

850

220

510

.6%

0.2%

331.

1327

420

162,

036

1,78

51,

778

250

712

.3%

0.4%

312.

6159

720

172,

018

1,73

91,

723

279

1613

.8%

0.8%

298.

673

2018

2,04

11,

731

1,70

631

025

15.2

%1.

2%31

8.69

420

192,

063

1,72

31,

691

340

3216

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1.6%

317.

413

317

1,72

920

202,

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1,71

81,

679

369

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1.9%

296.

678

6014

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320

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109

1,71

41,

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395

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2.0%

263.

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110

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1,66

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252,

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1,72

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477

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2026

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61,

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1,68

149

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272,

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1,74

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252

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2030

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----

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----

-

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 9.1 - Peak Demand Reduction Targets Page 2 of 9

73

THE NARRAGANSETT ELECTRIC COMPANYd/b/a NATIONAL GRIDRIPUC Docket No. 4770

Workpaper 9.1 - Peak Demand Reduction TargetsPage 3 of 9

Year 2019 2020 2021

Forecast Peak Load (1) 1691 1679 1672 Forecast peak load Rwith EE and PV impacts included

Forecast Peak Load (reconstituted) (2) 1729 1753 1774 Forecast peak load reconstituted for EE and PV for rate years

Minimum DER Impact (3)=(4)+(5)+(6)+(7)+(8)+(9) 43 82 117

Solar PV (4) 7 13 16

Energy Efficiency (5) 33 65 95

VVO (6) 2 3 5

Storage (7) 1 1 1

CHP (8) 0 0 0 CHP is assumed in EE targets

Heat Electrification (9) 0 0 0

Minimum Peak Load before Incremental effort (10)=(2)‐(3) 1686 1671 1657

Incremental effort (11) 2 5 10

Implied Minimum Peak Load Target (12)=(10)‐(11) 1684 1666 1647

Difference from original forecast (13)=(1)‐(12) 7 13 25

Year 2019 2020 2021

Forecast Peak Load (1) 1691 1679 1672 Forecast peak load Rwith EE and PV impacts included

Forecast Peak Load (reconstituted) (2) 1729 1753 1774 Forecast peak load reconstituted for EE and PV for rate years

Midpoint DER Impact (3)=(4)+(5)+(6)+(7)+(8)+(9) 46 91 133

Solar PV (4) 7 14 17

Energy Efficiency (5) 35 70 104

VVO (6) 3 5 8

Storage (7) 1 2 3



Midpoint Peak Load before Incremental effort (10)=(2)‐(3) 1682 1661 1642


Implied Midpoint Peak Load Target (12)=(10)‐(11) 1677 1651 1626


Year (1) 2019 2020 2021

Forecast Peak Load (reconstituted) (2) 1729 1753 1774 Forecast peak load Rwith EE and PV impacts included

Maximum DER Impact (3)=(4)+(5)+(6)+(7)+(8)+(9) 50 101 147 Forecast peak load reconstituted for EE and PV for rate years

Solar PV (4) 8 16 19

Energy Efficiecy (5) 37 75 113

VVO (6) 3 6 9

Storage (7) 2 4 6



Maximum Peak Load before Incremental Effort (10)=(2)‐(3) 1678 1652 1627


Implied Maximum Peak Load Target (12)=(10)‐(11) 1668 1637 1606


2018 WN Peak Forecast (MW)

1706 Cumulative MW Reductions from 2018

2019 2020 20201

Min 22 40 59

Mid 29 55 80

Max 38 69 100

Annual Peak MW Reductions from prior year (starting with 2018)

2019 2020 2021

Min 22 18 19

Mid 29 26 26

Max 38 31 31

Percent Reduction from 2018

2019 2020 2021

Min 1.30% 2.35% 3.46%

Mid 1.68% 3.19% 4.70%

Max 2.20% 4.04% 5.86%

Incremental MW Reductions to Forecast

2019 2020 2021

7 13 25

13 27 46

22 42 65

Forward Capacity Market Peak Demand Reduction Targets

MINIMUM PEAK REDUCTION TARGETS

MIDPOINT PEAK REDUCTION TARGETS

MAXIMUM PEAK REDUCTION TARGETS

74



Total Peak Impacts from DERs at Minimum, Target, and Maximum Levels

2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

Peak ‐ Actual & Forecast 1,822 1,807 1,811 1,850 1,778 1,723 1,706 1,691 1,679 1,672

Peak Forecast for Rate Years ‐ without EE & PV 1729 1753 1774

Total Peak Impacts

Peak Impacts (MW) 2019 2020 2021

Solar photovoltaics (PV) 7 13 16

Energy Efficiency (EE) 33 65 95

VVO 2 3 5

Storage 1 1 1

CHP 0 0 0 Included in EE

Heat 0 0 0

Minimum 43 82 117

Peak Impacts (MW)2019 2020 2021



VVO 3 5 8

Storage 1 2 3


Heat 0 0 0

Target 46 91 133

Peak Impacts (MW) 2019 2020 2021



VVO 3 6 9

Storage 2 4 6


Heat 0 0 0

Maximum 50 101 147

NECO Weather Normalized Peak ‐ Internal Forecast

75



Solar

2017 2018 2019 2020 2021

Baseline 9 9 7 7 3

Min 7 6 3

Target 7 7 3

Max 8 7 4

Assumes 90% of forecast solar available at min, 100% at target, 110% at max

Total cumulative impact at thulative (2018=0)

2017 2018 2019 2020 2021

Baseline 7 14 17

Min 7 13 16

Target 7 14 17

Max 8 16 19

Annual peak impact (MW)

Peak impact (MW)

Cumulative Solar (MW )

Forecast

Forecast

76



Energy Efficiency

Peak Impact (MW) from annual incremental installations

2017 2018 2019 2020 2021

Baseline 0 35.188 35 34 34

Min 32 31 31

Target 35 34 34

Max 39 38 38

2019 and 2020 baseline reflect values in 3 Year Plan. 2021 assumed same as 2020

Assumes 90% of planned EE achieved at min, 100% at target, 110% at max

Peak Reduction

Total impact in MW at time oCumulative (2018 =0)

2017 2018 2019 2020 2021

Baseline 35 70 104

Min ‐ ‐ 33 65 95

Target ‐ ‐ 35 70 104

Max ‐ ‐ 37 75 113

Assumed % of annual installations that contribute to peak

0.50

Peak Impact (MW)

Forecast

Peak Impact (MW)

Forecast

77

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VVO

Total impact in M

W at time of system

peak

2017

2018

2019

2020

2021

Baseline

Min

1.80

3.35

5.372% red

uction

Target

2.70

5.03

8.063% red

uction

Max

3.15

5.87

9.413.5% red

uction

Project inform

ation

FY Installed

Ben

efits

realized

in FY

CAPEX

VVO

OPEX

VVO

COR VVO

# of substations

# of

feed

ers

# of customers

MVA

GWhr

2% M

VA

Red

uction

3% M

VA

reduction

3.5% M

VA

Red

uction

Cumulative M

VA

Impact (3%)

Cumulative

MVA Im

pact

(3.5%)

FY17

FY18

27

FY18

FY19

$1,486,674

$303,741

$98,407

38

20,109

90.05

247.79

1.8

2.7

3.15

2.7

3.15

FY19

FY20

$1,463,679

$318,384

$98,336

210

15,862

77.7

322.99

1.55

2.33

2.72

5.03

5.87

FY20

FY21

$1,814,591

$341,488

$127,032

115

18,531

101.01

393.51

2.02

3.03

3.54

8.06

9.41

FY21

FY22

$1,337,650

$324,480

$83,815

210

13,421

86.94

270.89

1.74

2.61

3.04

10.67

12.45

FY22

FY23

$571,026

$184,027

$38,779

13

4,560

28.44

129.57

0.57

0.85

111.52

13.44

MW

Forecast

PILOT

78



Battery Storage

Total impact in MW at time of system peak from battery storage

2017 2018 2019 2020 2021

Baseline

Min 0 0 0.896739 0.896739 0.896739

Target 0 0 1 2 3

Max 0 0 2 4 6

Min targets align with expected storage project impacts

Target and max assume additional storage

Peak Impact (MW)Forecast

79



Electrification of Heat

Total impact in MW at time of system peak from Electric Heat Initiative

Peak Impact (MW)

2017 2018 2019 2020 2021

Baseline

Min 0 0 0.044255 0.095624 0.153585

Target 0 0 0.044255 0.095624 0.153585

Max 0 0 0.044255 0.095624 0.153585

80

Workpaper 9.2



Workpaper 9.2

Electric Heat Initiative Targets

81


Workpaper 9.2 - Electric Heat Initiative TargetsPage 1 of 2

ANNUALIZED CO2 Reductions

2018 2019 2020Min 0 44 0Mid 0 55 0Max 0 66 0Min 119 134 156Mid 149 168 195Max 179 202 234

Final Targets (combined metric tons CO2 avoided per yer) 2018 2019 2020Min 119 178 156Mid 149 223 195Max 179 268 234

GSHP: 55.23 tons avoided CO2 expected per year of the system Equipment Incentives: 149, 168, and 195 incremental tons annually for years 1, 2, 3

Targets (annual metric tons CO2)

1. GSHP ProgramCarbon reduction (metric tons CO2 avoided per year)

2. Equipment IncentivesCarbon reduction (metric tons CO2 avoided per year)

Program Design Element Program MetricsTarget Levels

82

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.2 -

Ele

ctri

c H

eat I

niti

ativ

e T

arge

tsP

age

2 of

2Assumptions

Carbon Emissions Factors ‐ non‐electric fuels

Fuel

Lbs / MMBTU

Short Ton /

MMBTU

Metric Ton /

MMBTU

Source

Natural G

as117

0.0585

0.05307037https://www.eia.gov/tools/faqs/faq.cfm

?id=73&t=11

Fuel Oil

161.3

0.08065


?id=73&t=11

Propane

139

0.0695


?id=73&t=11

Metric tons CO2

% reduction

Average annual emissions of an

oil‐heated

home

~8n/a

Average annual avoided

CO2 from oil‐to‐

ccASH

P conversion

~338%

Average annual avoided

CO2 from oil‐to‐GSH

P

conversion

~563%

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 9.2 - Electric Heat Initiative Targets Page 2 of 2

83

W

orkpaper 9.3



Workpaper 9.3

Electric Vehicle Targets

84

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ompa

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of P

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Dat

aR

ow L

abel

s20

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1220

1320

1420

1520

1620

17 Y

TD

2018

2019

2020

2021

BE

V(P

EV

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4111

719

329

3H

EV

(PH

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818

241

353

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V(N

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Gra

nd T

otal

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716

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9

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EV

3241

117

193

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463

706

1,

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1,53

7

PH

EV

178

182

413

538

733

1,04

1

1,44

8

1,

983

2,68

8

Tot

al E

v21

022

353

073

110

261,

505

2,

153

3,03

2

4,

225

Ann

ual N

ew B

EV

Reg

istr

atio

ns9

7676

100

Ann

ual N

ew P

HE

V R

egis

trat

ions

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519

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EV

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otal

1330

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1,

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orec

ast

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120

17

0

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48

8

PH

EV

s -

Incr

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2015

2016

2017

2018

2019

2020

2021

Act

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and

For

ecas

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112

523

4

308

40

6

53

5

705

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reg

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PH

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0.31

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Tot

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Reg

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st p

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n

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d Y

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num

ber

for

2017

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es a

nnua

lize

d Y

TD

num

ber

for

2017

)

THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 9.3 - Electric Vehicle Targets Page 1 of 1

85

W

orkpaper 9.4



Workpaper 9.4

Incentive Benefits

86

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e 1

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Ben

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Key

In

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Ass

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s20

1920

2020

2159

,493

$

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RN

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mis

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111

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1920

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2120

2220

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25-

$

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5,44

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154,

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THE NARRAGANSETT ELECTRIC COMPANY d/b/a NATIONAL GRID RIPUC Docket No. 4770 Workpaper 9.4 - Incentive Benefits Page 1 of 5

87

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Wor

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.4 -

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enti

ve B

enef

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FC

M S

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ts20

1920

2020

21B

asis

Poi

nts

2218

196

2926

2612

3831

3118

FC

M P

eak

Tar

gets

exp

ress

ed a

s M

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educ

tion

s re

lati

ve to

Com

pany

for

ecas

t inc

ludi

ng E

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nd s

olar

impa

cts

Not

e: th

ese

valu

es w

ere

used

for

cal

cula

ting

FC

M b

enef

its

Tar

gets

2019

2020

2021

713

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2242

65

Ann

ual C

apac

ity

Ben

efit

s20

1820

1920

2020

2120

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PV

Min

00

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get

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Ann

ual V

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get L

evel

s20

1820

1920

2020

2120

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PV

Min

035

6,96

1$

363,

159

$

38

1,61

3$

886,

970

$

Tar

get

071

3,92

1$

726,

317

$

76

3,22

7$

1,77

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0$

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$

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144,

840

$

2,66

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Pre

sent

Val

ue o

f 20

21 I

ncen

tive

2018

2019

2020

2021

2022

NP

V0

00

381,

613

$

28

5,75

2$

0

00

763,

227

$

57

1,50

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88

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4744

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Ann

ual V

alue

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tal T

rans

mis

sion

Cos

t Sav

ings

2018

2019

2020

2021

2022

NP

VM

in0

254,

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$

21

4,88

0$

243,

504

$

$5

75,1

66T

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30

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52M

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Ann

ual V

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of

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ntiv

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Tar

get L

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s20

1820

1920

2020

2120

22N

PV

Min

059

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$

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26$

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02$

14

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T

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36

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1$


89

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RR

AG

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EL

EC

TR

IC C

OM

PA

NY

d/b/

a N

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ION

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GR

IDR

IPU

C D

ocke

t No.

477

0 W

orkp

aper

9.4

- I

ncen

tive

Ben

efit

sP

age

4 of

5

Ele

ctri

c V

ehic

les

Pro

gram

Net

Ben

efit

s an

d V

alu

e of

In

cen

tive

Com

par

isio

n

NP

V o

f ne

t ben

efts

fro

m E

V

conv

ersi

on p

art o

f pr

ogra

m, p

er

BC

A1,

414,

836

$

Max

bas

is p

oint

s of

ince

ntiv

e3.

5

Net

Pre

sent

Val

ue o

f M

axim

um I

ncen

tive

2018

2019

2020

2021

2022

NP

VM

axim

um0

208,

227

$

21

1,84

2$

22

2,60

8$

$517

,399

.26

Ele

ctri

c H

eat I

niti

ativ

e P

rogr

am N

et B

enef

its

and

Val

ue o

f In

cent

ive

Com

pari

son

NP

V o

f pr

ogra

m n

et b

enef

its,

pe

r B

CA

396,

389

$

M

ax b

asis

poi

nts

of in

cent

ive

2

Net

Pre

sent

Val

ue o

f M

axim

um I

ncen

tive

2018

2019

2020

2021

2022

NP

VM

axim

um0

118,

987

$

12

1,05

3$

12

7,20

4$

$295

,657


90


Workpaper 9.4 - Incentive BenefitsPage 5 of 5

NPV of Benefit in 2022 Due

to 2019‐2021 Targets

NPV of 2021 Value of

Incentive

NPV of Value of Incentive

(2019‐2021)

Minimum 2,594,124$ 285,752$ 886,970$

Target 4,816,010$ 571,505$ 1,773,940$

Maximum 6,901,576$ 857,257$ 2,660,910$

NPV of Customer Savings

(2019‐2021)

NPV of Incentive (2019‐

2021) Share of Savings to Customer

Minimum $575,166 147,828$ 0.74

Target $779,652 258,700$ 0.67

Maximum $1,016,979 369,571$ 0.64

Program Net Benefits (NPV)

Incentive Value 2019‐

2021 (NPV)

Share of Quantified Net

Benefits to Customer

Electric Vehicles $1,414,836 $517,399 0.63

Electric Heat

Initiative $396,389 $295,657 0.25

91

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