SDN1501E ES1 PV Addenda to BOD.pdf

NORFOLK COUNTY CORRECTIONAL CENTER (NCCC)

Basis of Design Description of Mechanical, Plumbing and Electrical Systems Addendum A – Install PV System on Main Building Roof

B1509940.000

April 4, 2016

Prepared For:

Division of Capital Asset Maintenance and Management

TABLE OF CONTENTS

I. INTRODUCTION

II. ELECTRICAL

III. GENERAL SPECIFICATIONS REQUIREMENTS

IV. APPENDICES

V. MEP DRAWINGS

I. INTRODUCTION

A. PURPOSE

a. This document is an addendum to the “Basis of Design Description of Mechanical, Plumbing, and Electrical System” dated January 22nd, 2016

b. The purpose of this document is to develop schematic level design documentation for ECM-21.00: Install Photovoltaic System on Main Building Roof in the form of a basis of design and applicable drawings and specifications in order to be procured through a request for proposal (RFP) by DCAMM under Chapter 25A.

c. The design concept was derived from an ASHRAE Level-II Energy Audit from which energy conservation measures (ECM’s) required further development in a basis of design (BOD) in order to procure through Chapter 25A.

B. DELIVERABLES

a. WSP I Parsons Brinckerhoff has provided a Basis of Design (BOD) that includes design criteria, drawings, diagrams, and performance specifications that has brought the ECM’s to a 30% schematic design level; where the awarded Contractor shall complete the design and implement the ECM per all applicable local and state codes.

C. SCOPE

a. In general, the scope of measures included in this addendum includes installing the following selected ECM outlined in WSP I Parsons Brinckerhoff’s Energy Audit Report:

a. ECM-21.00: Install Photovoltaic System on Main Building Roof

II. ELECTRICAL

A. Codes and Standards

1. Massachusetts Electrical Code: NFPA 70: (NEC) 2014 with Massachusetts Amendments.

2. Massachusetts State Building Code, 8th Edition

3. Massachusetts State Building Code 248 CMR

4. International Building Code, 2009 Edition

5. International Energy Code, 2012 Edition

6. NFPA 72

7. NFPA 101

8. Underwriters Laboratories (UL)

9. Occupational Safety & Health Administration (OSHA)

B. ECM-21.00: Install Photovoltaic (PV) System on Main Building Roof

1. Existing Conditions

a. Currently, there are no renewable energy systems on site. All electricity is purchased from the grid.

b. The building is being served via a 1500kVA 13.8kV-480/277V utility transformer located adjacent to the central unit mechanical space.

c. Power is distributed throughout the facility from a 2500A, 480/277V, 3-phase, 4-wire switchboard MSB-1 located in the main electric room.

d. Historical data from 2013 and 2014 indicates a peak electrical demand averaging approximately 405kW in the winter months and 589kW in the summer months.

e. A structural analysis was performed to assess the existing conditions of the Main Building. The methodology and key findings of the structural analysis have been summarized into a narrative with supporting drawings, found in Appendix A – Roof Structural Analysis. The narrative includes the following:

1) Assessment of available roof area for the photovoltaic arrays

2) Structural assessment of the load bearing roof capacity

2. Recommendations

a. Provide a 138kW solar array on the roof of the main building. The location of the solar panels will be based on several factors, including:

1) OSHA required distance from the edge of the roof

2) Placement of existing HVAC equipment

3) Locations where shadows are expected (north of HVAC equipment and building extrusions).

4) Load bearing capability of the roof based on structural analysis

b. Provide two central inverters capable of providing AC power to the building from the DC power generated by the solar panels. Location of inverters and AC combiner panels to be coordinated on site with the facilities manager.

c. Provide new 250A circuit breaker in existing switchboard MSB-1 for connection to PV system.

d. New circuit breaker shall be located on the opposite end of the switchboard bus from the incoming utility connection in order to comply with NEC 705.12.D.2 requirements for minimum bus ampere rating.

New circuit breaker being provided for Cogen system under ECM-16.00 shall be located adjacent to PV system circuit breaker.

e. Provide DC combiner boxes, meters, grounding and warning signs as required for a complete, working system.

f. Refer to drawings E-001, E-002, and E-003 for additional information.

g. Refer to Appendix B – PV Energy Analysis for an overview historical utility data and energy savings, energy cost savings, and implementation costs associated with this measure.

III. GENERAL SPECIFICATIONS REQUIREMENTS

A. 260001– ELECTRICAL – PHOTOVOLTAIC SYSTEM

DCAMM STANDARD SPECIFICATIONS MASS. STATE PROJECT NUMBER SDN1501E ES1

ADDENDUM A NCCC DEDHAM, MA

ELECTRICAL WORK APRIL 04, 2016

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1.27 PHOTOVOLTAIC SYSTEM

A. The Contractor shall provide design services (layout and detail drawings, manufacturers product information, execution methods, engineering calculations including PV panels, installation methods, combining and disconnecting means, inverters, wiring methods and electrical protection) for an electrical review the entire photovoltaic system both DC and AC components, prior to installation to determine a latest edition of the Massachusetts Electrical Code (MEC) and utility compliant interconnection method. Electrical system design services shall be performed under the direct guidance and control of a professional engineer licensed in the Commonwealth of Massachusetts. The design shall be based on the installation indicated on the contract drawings and the contractor’s choice of materials to meet the project specifications.

B. The photovoltaic system on the contract drawings is based on the following equipment:

1. Photovoltaic PV module Solon blue 220/16 -14% module efficiency.

2. Panel Claw Polar Bear II 10 degree tilt

3. Solectria ARCCOM String Combiner with AFCI and rapid shutdown compliance

4. Solectria PVI-75 UL 480V inverter

5. Solectria PVI-60 UL 480V inverter

C. All array design temperature corrections used to calculate maximum system voltage, as defined in the MEC, will be based upon a value of -34°C as the lowest expected ambient temperature. The total voltage drop of the DC system from the DC terminals of the in-verter(s) to the most distant array shall not exceed 3% of the system maximum power voltage (Vmp). The system maximum power voltage (Vmp) for all systems shall be cal-culated as the sum of the rated maximum power voltages of the series-connected photo-voltaic modules corrected for a cell temperature of 48°C.

D. In addition the Contractor shall provide construction layout and detail drawings, manu-facturers product information, execution methods, engineering calculations and specifica-tions signed and sealed by a professional engineer licensed in the Commonwealth of Massachusetts for review and approval for the roof/wind/snow/ice/seismic loads and de-tailed installation requirements in accordance with the latest edition of the Massachusetts Building Code. Structural and roofing design services shall be performed under the direct guidance and control of the respective professional engineer licensed in the Common-wealth of Massachusetts.

E. The PV system shall be utility grid connected following Eversource required design and installation standards for grid-tied customer-sited generation. The contractor is responsi-ble to coordinate all utility interconnection requirements and interconnection with the building’s existing electrical distribution system. Contractor shall be responsible for in-terconnection application up to and including final acceptance of installation.

F. The Contractor shall provide a complete Operations and Maintenance manual and set of

As-Built drawings for each system. Upon completion of the project the Contractor shall provide training to personnel in the operation and maintenance of the PV system.

G. All mounting materials shall be corrosion-proof anodized aluminum or Type 316 stain-less steel. All materials subject to exposure to the sun must be sunlight resistant material.

All conductors shall be tin-coated copper. Equipment shall be as follows:

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1. Maximum inverter efficiency, based upon the California Energy Commission’s

(CEC) list of eligible inverters weighted efficiencies, shall be greater than or equal to 94 percent. (refer to http://www.gosolarcalifornia.ca.gov/equipment/inverter.php).

2. Installation and equipment shall meet the current UL 1741/IEEE Standard 1547, MEC codes and the latest applicable ANSI and FCC standards at the time bids are submitted.

3. Each inverter shall include:

a. Automatic operation including start-up, shutdown, self-diagnosis, fault detection and alarming to BAC.

b. LCD or LEDs for display of operating status.

c. Ground fault protection.

d. Integral local display capabilities.

e. NEMA 4XSS(316) for any exterior location.

4. Combiner boxes and junction boxes which are located outdoors shall have the following characteristics: NEMA 4XSS(316L) enclosure, 600 VDC, and shall be identified and listed for the application by a nationally recognized testing labora-tory as determined by NETA (National Electrical Testing Laboratory). All pho-tovoltaic system output circuits shall be protected by lightning arrestors of the appropriate voltage rating.

5. The DC disconnect(s) shall be 600 VDC, heavy-duty safety switch and be listed by a nationally recognized testing laboratory. Where located outdoors, discon-nects shall be NEMA 4XSS(316). Where fused disconnects are used, fuses shall have appropriate DC ratings.

6. All AC disconnects shall be rated to interrupt the necessary voltage and current for the application and be listed by a nationally recognized testing laboratory.

Where located outdoors, disconnects shall be NEMA 4XSS(316).

7. Each system shall include a revenue grade kilowatt-hour meter that shall record the full AC output of the associated inverter. Meters shall be on the List of Eli-gible System Performance Meters as published by Go Solar California on their website at http://www.gosolarcalifornia.org/equipment/meter.php.

8. Provide interconnection circuit breakers capable of reverse current flow in switchboard MSB-1. Circuit breakers provided shall be rated to withstand a short circuit current of 65kA at 480 Volts AC. Circuit breaker(s) provided shall be complete with shunt trip and/or ground fault mechanism..

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9. Wires and cables shall meet applicable requirements of NFPA 70 and UL for types of insulation, jacket, and conductor specified or indicated. Wire and cable shall be new and shall have the size, grade of insulation, voltage and manufactur-er's name permanently marked on the outer covering at regular intervals and shall be delivered in complete coils or reels with identifying size, type and insulation tags. Wire and cable shall be suitably protected from weather and damage during storage and handling, and shall be in first-class condition when installed. Copper conductors shall be tin coated. The tin coating shall be applied in accordance with ASTM B33-81. Bare conductor prior to coating will meet ASTM B1-81, B2-82, or B3-74.

10. Cable shall be Type USE single-conductor tinned copper wire for lead-in from

PV arrays. Insulation shall be black crosslinked polyethylene, UL Listed, 600 Volts, Type USE-2 RHH / RHW-2.

11. Low voltage conductors (600 volts). Conductors shall be softdrawn annealed tinned copper with heat- and moisture-resistant insulation, for 75 or 90 degrees C service, type XHHW conforming to UL 44. Minimum wire size shall be No. 10 AWG. Conductors No. 8 and larger shall be stranded. Wire and cable No. 8 AWG and smaller shall be factory color-coded with a separate color for each phase and neutral used consistently throughout. Color coding for 480 volt sys-tems shall differ from 120/208 or 120/240 volt systems where run within the same building. Colors shall be black, red, blue and white for the lower voltage and brown, orange, yellow and off-white for the higher. Wire and cable No. 6 AWG and larger may be black and color coded at all terminations and splices.

Conductors shall be as manufactured by Cablec Corporation, Rome Cable, Okonite Company, American Insulated Wire, Southwire Company or equal.

12. Grounding Cable. Grounding cable installed in the raceways with circuit cables shall be single conductor, stranded, soft-drawn annealed tinned copper, 600 volt, type THW conforming to UL 83, colored green.

13. Shielded Cable for Instrumentation Wiring: stranded tinned copper conductors.

Insulate conductors individually with color coded polyethylene or polyvinylchlo-ride. Twist pairs twisted with varying lay (if more than one pair) and cover with cable tape and copper or aluminum coated mylar shielding tape and tinned cop-per drain wire. Jacket: polyvinylchloride. Cables: rated 600 volts and 90 de-grees C.

14. CAT 5e Cable: Horizontal Telephone Cable 4 Pair, tinned copper conductors, 24

AWG, Plenum Cable.

15. CCTV cable shall be RG59/U.

a. Center Conductor: Tinned Copper, 20 AWG, 10 ohms DC Resistance

b. Braided Shield: Bare tinned Copper with 95% or better braid coverage

c. Dielectric Material: Polyethylene

d. Impedance: 75 Ohms

e. Jacket: Polyethylene, outdoor rated.

16. All conduits exposed outside the building shall be PVC coated rigid galvanized steel conduit.

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17. All outdoor electrical enclosures shall be NEMA 4XSS(316) and have watertight connections.

18. Exposed cables shall be listed as sunlight resistant.

19. Cables between photovoltaic panel arrays, or between arrays and combiners, not installed directly beneath a photovoltaic panel array shall be installed in conduit.

H. Photovoltaic system ground(s) shall be installed and sized in accordance with MEC Arti-cle 690.47(C)(2) and shall terminate on the ground bus in the respective motor control center.

I. The AC interconnection(s) shall comply with MEC Article 690.64(B)(3) by providing ground fault protection for the inverter(s) AC output circuit(s). Each protective circuit design shall include a discrete ground fault relay that shall trip the interconnecting circuit breaker in the event of detection of excessive ground fault currents. The Contractor shall coordinate the PV systems’ AC ground fault detection and protection device thresholds with the existing buildings’ distribution system ground fault protection. The Contractor shall confirm that any ground fault protection device that is part of the supply to an exist-ing power distribution system shall be identified and listed as suitable for backfeeding.

J. PV Array

1. Photovoltaic modules shall be 220 Watt STC or larger.

2. Photovoltaic modules loss of output power, at all times during the first ten (10) years following the effective Substantial Completion date, shall not exceed an average of one (1) percent per year and total ten (10) percent of the minimum power rating of the product specifications for the module. Further the loss of out-put power for each module installed in the system, at all times during the elev-enth (11) through twenty-fifth (25) years following the effective Substantial Completion date, shall not exceed an average of one (1) percent per year and a total of ten (10) percent of the minimum power rating of the product specifica-tions for the module.

3. Modules shall be UL 1703 listed.

4. Modules shall be approved and listed with the California Energy Commission’s list of eligible photovoltaic modules:

(http://www.gosolarcalifornia.org/equipment/pvmodule.php).

5. The mounting system must fit within the footprint specified on the drawings

6. The mounting systems, including the photovoltaic modules, must add not more than 12lb/sf

7. The mounting system shall be UL listed and shall promote ambient air circulation beneath and above modules to enhance efficiency.

8. Modules shall be individually removable for roof access, maintenance or repair.

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9. Contractor shall maintain all existing roofing warranties.

10. The mounting system shall be designed to meet or exceed requirements of appli-cable state and local building codes, including wind speed, snow and seismic load requirements.

11. The Contractor shall work with the lightning protection system. Meet all current code and UL requirements with respect to lightning protection. The Contractor shall have the system redesigned, the system reworked, and the building recerti-fied by a firm certified by the Lightning Protection Institute. Comply with NFPA 780, UL 96A, and LPI-175. The lightning protection professional shall be a certi-fied Master Installer by the Lightning Protection Institute. Use of bare copper shall not be allowed. Aluminum or tin coated copper shall be used wherever pos-sible.

12. Mounting system design must permit access to the array and all roof or ground mounted structures for maintenance purposes.

13. The mounting system components shall be a ballasted non-penetrating system.

The existing roofing membrane shall be protected by placing protective mem-brane between the PV panel pavers and roofing membrane. The installation shall not block the flow of rainwater to the drains.

14. The mounting system shall be installed no closer than 10’-0” to the edge of the flat roof.

K. The Contractor shall provide a data monitoring system. The will not allow retransmission or access to this data over any transmission medium including phone or internet connec-tions. The data monitoring system for each installation shall report the system parame-ters and fault conditions using hard wired outputs to the building BAS. The data moni-toring system output provided shall be 4-20mA for analog signals and dry relay contacts for digital signals. At a minimum the system parameters shall include:

1. DC power (kW)

2. AC power (kW)

3. DC current (Amps)

4. DC voltage (Volts)

5. Ambient temperature near the array (Deg. F)

6. Back of module surface temperature (Deg. F)

7. Plane of Array (POA) irradiance

L. Provide heavy-duty equipment, and other specified devices furnished hereunder, and rat-ed for continuous industrial uses. Laboratory grade instrumentation is not acceptable.

Provide system components produced from a single manufacturer whenever possible.

Provide the most current model of each component available at the time of construction.

Provided equipment must allow for field expansion, modification, and full adjustment for calibration.

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M. Operate all instrumentation equipment on 120Vac, +/-10%, at 60Hz, unless otherwise specified. Provide power supplies, regulators, and constant-voltage transformers to meet the specified requirements.

N. Provide solid-state electronic instrumentation, utilizing linear transmission signals of 4 to

20 mAdc, (milliampere direct current). Instruments within the same panel or enclosure may be operated by 1-5 Vdc, (volts direct current), provided it is converted to a 4 to 20 mAdc signal.

O. Provide 4 to 20 mAdc outputs from transmitters, transducers, and any other signal pro-cessing devices, capable of driving all instruments.

P. Provide non-standard signals with transducers that immediately convert into compatible standard signals at their source. Zero based signals are not acceptable.

Q. The output of the photovoltaic inverter(s) shall not interfere with or damage the function of existing building electrical distribution systems. All serviceable components must be “accessible” as defined by the MEC article 100. The installation shall comply with all Federal, state and local building codes, including the latest version of the Massachusetts Electrical Code.

R. PV Panels Support

1. 1. Penetrating the existing membrane roof shall not be permitted.

2. The design shall be in accordance with the Seventh Edition of the Massachusetts

State Building Code.

3. The ground snow load and basic wind speed shall be based on the criteria speci-fied for the Town of Dedham:

a. Ground Snow Load: Pg = 45 psf

b. Snowdrift shall be determined based on the Seventh Edition of the Mas-sachusetts State Building Code.

c. Basic Wind Speed: V = 105 mph

4. The building shall be assumed to have the following categories and factors:

a. Occupancy Category III

b. Thermal Factor (Ct) of 1.0

c. Exposure Category D

5. The Contractor can assume the existing roof framing can accommodate a PV panel system (including panels, rack frames and ballast) that has a weight equal to or less than 15 pounds per square foot.

6. The Contractor shall submit calculations for the PV support system and a check of the roof system (decking and framing members). The calculations shall be stamped by a Professional Engineer who is registered in the Commonwealth of Massachusetts.

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S. The Contractor shall provide a commissioning plan for review and approval the testing shall include:

1. Measurement and recording of Voc of every source circuit.

2. Measurement and recording of Imp of every source circuit, measured at each combiner box. Source circuit measurements should be done under uniform irra-diance conditions and the time of the first and last measurements taken at each combiner box should be recorded.

3. Perform inverter startup tests as specified by each inverter manufacturer in the inverter operation manual.

4. Measure ac power and compare to predicted power based upon estimated irradi-ance level.

5. Perform loss of grid test and verify five minute delay upon restoration of grid.

6. The Contractor shall verify that each data acquisition/display system is function-ing properly, comparing independent measurements to data acquisition display, through to the Deer Island DCS.

7. The Contractor shall correct any deficiencies uncovered by the testing prior to commissioning of the system at no cost.

T. The Contractor shall train up to 12 staff in the operation and maintenance of PV sys-tem(s), in accordance with Section 01735 of these Technical Specifications. Training shall include principles of operation, routine maintenance and safety issues.

U. For a period of 5 years from the date of Substantial Completion the Contractor warrants that the entire PV system including the inverter, mounts, and PV panels conforms to these Technical Specifications and is free from defects in materials and workmanship. The Contractor shall repair or replace any work found to be defective within said warranty pe-riod. Such repair or replacement shall include the cost of removal and reinstallation.

V. The Contractor shall obtain from the photovoltaic module manufacturer its written war-ranty that its equipment, including all hardware will be free from defects in design, mate-rials, and workmanship for a period of 5 years following Substantial Completion.

W. The Contractor shall obtain from the inverter manufacturer its written warranty that its equipment including all hardware will be free from defects in design, materials, and workmanship for a period of 5 years following Substantial Completion.

X. The Contractor shall obtain from the mounting system manufacturer its written warranty that its equipment including all hardware will be free from defects in design, materials, and workmanship for a period of 5 years following Substantial Completion.

IV. APPENDICES

a. Appendix A – Roof Structural Analysis

b. Appendix B – PV Energy Analysis

c. Appendix C – PV Cut Sheets

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April 1, 2016

Mr. Michael Reinhardt Energy Project Manager Office of Facilities Management and Maintenance Division of Capital Asset Management and Maintenance One Ashburton Place Boston, MA 02108

Dear Mr. Reinhardt, Per your request, WSP | Parsons Brinckerhoff (WSP | PB) has assessed the structural feasibility of installing photovoltaic panels to the existing roofs of the Norfolk County Jail and HOC. The assumed proposed panel locations are shown on the attached “PV Panel Array Layout Plan.” It is our understanding that the preferred PV array system would be a ballasted system (without mechanical attachment to the existing roof structure).

Based on typical standard cut sheets of ballasted PV array systems, we assumed that the array systems typically weigh between 8 and 12 psf.

Our review was primarily based off the following sheets as part of the original 1989 construction drawings prepared under Project No. CN080-1:

· S-3, S-4, S-7, S-8, S-13, S-14, S-17, S-20, S-21, S-24, S-25

The Norfolk County Jail and HOC consists of eight independent structures with five different types of roof construction. For purposes of this feasibility study, the analysis was based upon current MSBC gravity design loading requirements (dead load, live load, snow load, and loading combinations). Additionally, the impact on the existing lateral force resisting systems was assessed based on the pertinent MSBC Chapter 34 Existing Building lateral force resisting system code requirements. The roof structures that we ultimately deemed to have reserve gravity load-carrying capacity include an 8” two-way reinforced concrete slab, a 10” two-way reinforced concrete slab, and 1 ½” Type B 20 gauge metal deck with 2 ½” normal weight concrete on 28LH07 joists spaced at 2’-0”. For your use and review, we have included two roof plan drawings at the end of this report. The first plan identifies the various roof construction types across the multiple structures comprising the Norfolk County Jail and HOC. The second plan identifies those portions of roof structures which have reserve gravity load-carrying capacity.

The design snow load per the eighth edition of the Massachusetts State Building Code (MSBC) for this building is 35 psf (pg [ground snow load] = 45psf, I [importance factor] =1.1), plus associated snow drift.

This is an increase from the original snow load of 30 psf stated on the record drawings at the time of building construction.

We estimated superimposed dead loads to be 15 psf to account for the roof membrane, hung ceilings, and hung MEP equipment.

Based on our review and analysis of the available information, portions of the existing roof structure appear to have capacity to receive the ballasted PV arrays, in the areas indicated on the attached plan. Please note that on the orange areas, only strips of the roof have adequate reserve gravity load-carrying capacity and therefore the space limitations and maintenance access required will restrict the feasibility of PV array installation within these areas.

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APPENDIX A

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The additional loading from the proposed ballasted PV array system (if limited to the highlighted areas on the attached plan) does not increase the seismic weight of each building beyond the code-required threshold and therefore a lateral force resisting system upgrade does not appear to be required per the requirements of the MSBC Chapter 34.

We feel this information is adequate to inform your future decisions regarding the installation of ballasted PV arrays on the existing roof structures of the Norfolk County Jail and HOC. If you have any questions, please do not hesitate to call.

Respectfully, Ryan Couto, P.E., LEED AP Senior Structural Engineer WSP | Parsons Brinckerhoff

EXP. JOINT

8" NWC TWO-WAY SLAB, #5@9B, #5@12T (TYP)

8" NWC ONE-WAY SLAB, #5@12B, #4@12T (TYP)

10" NWC TWO-WAY SLAB, #5@12B, #6@12T (TYP)

1 1/2" TYPE B METAL DECK, 20 GA., + 2 1/2" NWC

1 1/2" TYPE B METAL DECK, 20 GA., + 2 1/2" NWC

ROOF CONSTRUCTION LEGEND:

EXISTING STRUCTURAL ROOF CONSTRUCTION KEY PLAN

EXP. JOINT

SKYLIGHT/SCREEN

ROOF TOP UNIT

AREA WITH GRAVITY CAPACITY TO RECEIVE

WIDE SPREAD PV ARRAYS

LEGEND:

T.O.C. EL. 247'-8 3/8"

T.O.S. EL. 254'-0"

T.O.C. EL. 260'-0 3/8" (VARIES)

T.O.S. EL. 264'-0"

5,300 FT2

4,200 FT2

6,200 FT2

1,200 FT2

3,200 FT2

800 FT2

2,600 FT2

N

RESTRICTIVE STRIPS OF PV ARRAY LAYOUT PLAN

AREA WITH RESERVE

CAPACITY DUE

TO IRREGULAR SPACING

IN ROOF JOISTS - LIMITED

FEASIBLE TO INSTALL

PV ARRAYS HERE.

AREA WITH RESERVE

GRAVITY LOAD-CARRYING CAPACITY

MEMORANDUM

To: DCAMM

From: WSP | Parsons Brinckerhoff

Date: April 4, 2016

Project Name: Norfolk County Correctional Center – 30% MEP Design

Project Number: B1509940.000

Subject: Energy Analysis of ECM-21.00: Install Photovoltaic System on Main Building Roof

OVERVIEW

The intent of this memo is to:

1. Review (24) months of utility bills to confirm that a 138 kW photovoltaic (PV) system is appropriate.

a. Note that a 138 kW system is proposed upon surveying the available roof area with sufficient structural capacity, while maintaining access to existing rooftop equipment.

b. Forecast electric load as a result of the implementation of non-PV energy conservation measures included under DCAMM energy project – SDN1501E ES1

2. Determine the energy savings, energy cost savings, and implementation costs associated with the proposed PV system.

UTILITY BILL ANALYSIS

WSP | Parsons Brinckerhoff reviewed (24) months of utility bills to determine the baseline (existing) electric load at the Norfolk County Correctional Center (NCCC) campus.

The design intent is that the system will be inter-connected with the main electrical feed serving the campus (Eversource Account # 26114731008).

The average annual electrical consumption, maximum peak demand, and minimum peak demand during the (24) month period from January 2013 through December 2014 was 3,219,060 kWh, 589 kW, and 391 kW, respectively. See Table 1 below.

Table 1 - 24 Month Electric Consumption

Year Days Metered Max Peak kW Metered Min Peak kW Metered kWh kWh/Day

Year 1* 365 589 391 3,230,520 8,851

Year 2** 365 589 391 3,207,600 8,788

Average: 365 589 391 3,219,060 8,819

*Year 1 is December 2014 through November 2015

**Year 2 is December 2013 through November 2014

Monthly utility data is provided in Table 2 and Table 3.

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APPENDIX B

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Table 2 – 2013 Electric Breakdown Table 3 – 2014 Electric Breakdown

Month Energy Usage (kWh) Peak Demand

Month Energy Usage (kWh) Peak Demand

Jan-13 233,160 405 Jan-14 231,600 412

Feb-13 243,360 398 Feb-14 242,520 405

Mar-13 226,440 391 Mar-14 239,160 391

Apr-13 265,200 513 Apr-14 226,080 453

May-13 280,440 576 May-14 269,760 515

Jun-13 356,760 579 Jun-14 333,600 589

Jul-13 318,360 585 Jul-14 311,880 579

Aug-13 304,800 589 Aug-14 324,000 565

Sep-13 260,640 574 Sep-14 298,800 528

Oct-13 255,720 492 Oct-14 252,480 530

Nov-13 225,720 410 Nov-14 217,800 418

Dec-13 259,920 408 Dec-14 259,920 408

2013 Summary: 3,230,520 493 2014 Summary: 3,207,600 483

Figure 1 below was captured during field investigations on 10/14/15. The figure is a photograph of the ammeter on the main switchboard.

Figure 1 - Main Switchboard Ammeter

As per Figure 1 above, the ammeter is reading approximately 600 amperes, which correlates to 500 kW. The ammeter reading aligns with the range between the minimum and maximum peak kWs recorded on the utility bills.

Upon the implementation of energy conservation measures, as part of DCAMM’s energy project – SDN1501E ES1, it is forecasted that the annual electric consumption and peak demand at the NCCC Campus will reduce to approximately 1,684,313 kWh and 278 kW, respectively. Note that this does not include the electric consumption and demand savings associated with the PV system itself.

Borrowing any special circumstances, the instantaneous PV generation will never exceed the electrical load at the NCCC campus. Therefore, exporting renewable energy to the grid is not necessary, nor recommended.

However, consumption of renewable energy will offset the total consumption of “grid-purchased” electricity therefore reducing electric consumption costs.

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ENERGY AND COST SAVINGS

The proposed PV system is rated to produce approximately 138 kW DC during peak operating performance.

A program called PVWatts was used to compute the potential energy and energy cost savings associated with the PV system. The results indicate a 138 KW system would generate 180,728 kWh annually. The results of the PVWatts program are provided is attached (see last page).

The blended utility rate over the (24) month period (January 2013 through December 2014) was $0.12/kWh.

While generating 180,728 kWh annually, the PV system is expected to yield $21,688 in annual energy cost savings.

The total cost of installing the PV system, including module, inverter, hardware costs, and labor is estimated to be $1,104,000 with a simple payback of 51 years.

Table 3 below summarizes the energy savings, energy cost savings, and implementation costs associated with the proposed PV system.

Table 3 - Savings Summary

Estimated Annual Electrical Energy Savings: 180,728 kWh/yr Estimated Annual Cost Savings: $21,87

Estimated Electrical Peak Demand Savings: 92 kW Estimated Implementation Cost: $1,104,000

Estimated Annual Gas Heating Savings: 0 Therms/yr Simple Payback: 50.9 years

Due to the high payback associated with this measure, the utility companies will not incentive this project. However, the sale of renewable energy credits (RECs) and/or federal grants may be pursued to drive down the project payback.

<END OF MEMO>

4/4/2016 PVWatts Calculator http://pvwatts.nrel.gov/pvwatts.php 1/1

Caution: Photovoltaic system performance predictions calculated by PVWatts® include many inherent assumptions and uncertainties and do not reflect variations between PV technologies nor sitespecific characteristics except as represented by PVWatts® inputs. For example, PV modules with better performance are not differentiated within PVWatts® from lesser performing modules. Both NREL and private companies provide more sophisticated PV modeling tools (such as the System Advisor Model at http://sam.nrel.gov) that allow for more precise and complex modeling of PV systems.

The expected range is based on 30 years of actual weather data at the given location and is intended to provide an indication of the variation you might see.

For more information, please refer to this NREL report: The Error Report.

Disclaimer: The PVWatts® Model ("Model") is provided by the National Renewable Energy Laboratory ("NREL"), which is operated by the Alliance for Sustainable Energy, LLC ("Alliance") for the U.S. Department Of Energy ("DOE") and may be used for any purpose whatsoever.

The names DOE/NREL/ALLIANCE shall not be used in any representation, advertising, publicity or other manner whatsoever to endorse or promote any entity that adopts or uses the Model.

DOE/NREL/ALLIANCE shall not provide any support, consulting, training or assistance of any kind with regard to the use of the Model or any updates, revisions or new versions of the Model.

YOU AGREE TO INDEMNIFY

DOE/NREL/ALLIANCE, AND ITS

AFFILIATES, OFFICERS, AGENTS, AND

EMPLOYEES AGAINST ANY CLAIM OR

DEMAND, INCLUDING REASONABLE

ATTORNEYS' FEES, RELATED TO YOUR

USE, RELIANCE, OR ADOPTION OF THE

MODEL FOR ANY PURPOSE WHATSOEVER.

THE MODEL IS PROVIDED BY

DOE/NREL/ALLIANCE "AS IS" AND ANY

EXPRESS OR IMPLIED WARRANTIES,

INCLUDING BUT NOT LIMITED TO THE

IMPLIED WARRANTIES OF

MERCHANTABILITY AND FITNESS FOR A

PARTICULAR PURPOSE ARE EXPRESSLY

DISCLAIMED. IN NO EVENT SHALL

DOE/NREL/ALLIANCE BE LIABLE FOR ANY

SPECIAL, INDIRECT OR CONSEQUENTIAL

DAMAGES OR ANY DAMAGES

WHATSOEVER, INCLUDING BUT NOT

LIMITED TO CLAIMS ASSOCIATED WITH

THE LOSS OF DATA OR PROFITS, WHICH

MAY RESULT FROM ANY ACTION IN

CONTRACT, NEGLIGENCE OR OTHER

TORTIOUS CLAIM THAT ARISES OUT OF

OR IN CONNECTION WITH THE USE OR

PERFORMANCE OF THE MODEL.

The energy output range is based on analysis of 30 years of historical weather data for nearby , and is intended to provide an indication of the possible interannual variability in generation for a Fixed (open rack) PV system at this location.

180,728 kWh per Year *RESULTS

System output may range from 173,462 to 187,306kWh per year near this location.

Month Solar Radiation ( kWh / m2 / day )

AC Energy ( kWh )

Energy Value

January 2.71 10,097 1,212

February 3.67 12,277 1,473

March 4.49 16,157 1,939

April 5.01 17,113 2,054

May 5.75 19,416 2,330

June 6.03 19,058 2,287

July 6.13 19,908 2,389

August 5.83 19,010 2,281

September 4.93 15,872 1,905

October 4.09 14,096 1,692

November 2.61 9,112 1,093

December 2.35 8,612 1,033

Annual 4.47 180,728 $ 21,688

Location and Station Identification

Requested Location 02026

Weather Data Source (TMY2) BOSTON, MA 12 mi

Latitude 42.37° N

Longitude 71.03° W

PV System Specifications (Commercial)

DC System Size 138 kW

Module Type Standard

Array Type Fixed (roof mount)

Array Tilt 20°

Array Azimuth 180°

System Losses 14%

Inverter Efficiency 96%

DC to AC Size Ratio 1.1

Initial Economic Comparison

Average Cost of Electricity Purchased from Utility 0.12 $/kWh

Initial Cost 3.00 $/Wdc

Cost of Electricity Generated by System 0.14 $/kWh

These values can be compared to get an idea of the costeffectiveness of this system. However, system costs, system financing options (including 3rd party ownership) and complex utility rates can significantly change the relative value of the PV system.

STRING COMBINER

ARCCOM

ADVANCED STRING COMBINERS

Yaskawa - Solectria Solar’s ARCCOM offers customers the best quality, ease of installation, mounting flexibility, safety and protection features. It is compliant with NEC 2014 arc-fault and rapid shutdown requirements and contains a contactor disconnect, lockable switch and string level arc-fault protection, allowing it to detect and interrupt a series arc. It is also built and designed for wide temperature ranges and rugged conditions. All components are vetted for highest reliability through Highly Accelerated Life Testing (HALT). The ARCCOM also features standard oversized mechanical lugs that allow for long-run output conductors and multiple conduit entry locations so it can be mounted vertically or horizontally - thus eliminating the need for labor-intensive conduit bends. Additional options include surge arrestor and connector plates for those installers who prefer to field-crimp oversized output conductors. The

ARCCOM is compatible with all Yaskawa - Solectria Solar three-phase central inverters (PVI 50-100KW, SGI 225-500PE, SGI 500XT, SGI 500/750XTM).

FEATURES

• Compliant with NEC 2014

690.11 & 690.12 arc-fault and rapid shutdown requirements

• Compatible with all Solectria three-phase central inverters

(PVI 50-100KW, SGI 225-

500PE, SGI 500XT, SGI

500/750XTM)

• String level arc-fault detection

• Remote shutdown

• Contactor disconnect

• Audible, LED, and dry contact indicators

• Multiple fuse sizes

• Switch locking mechanism

• Lowest power consumption in the industry

• AC or DC control power

OPTIONS

• Connection plates for field-crimped lugs

• Surge arrestor

SOLECTRIA.COM

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MADE IN THE USA

ARCCOM SPECIFICATIONS

Number of Fused Inputs 8 12 16 24 Input Wire Range 12-8 AWG

Ouput Wire Range* Single Conductor Copper Conductors Aluminum Conductors Two Parallel Conductors Copper Conductors Aluminum Conductors

1AWG - 600kcmil 1/0AWG - 600kcmil

1/0AWG - 600kcmil 1/0AWG - 600kcmil

3/0AWG - 600kcmil 4/0AWG - 600kcmil

1/0AWG - 600kcmil 1/0AWG - 600kcmil

250kcmil - 600kcmil 350kcmil - 600kcmil

1/0AWG - 600kcmil 1/0AWG - 600kcmil

500kcmil - 600kcmil Not Allowed

3/0AWG - 600kcmil 4/0AWG - 600kcmil

Maximum Voltage 600 or 1000 VDC

Maximum Continuous Current 96 A 144 A 192 A 288 A

Available String Fuses 4A, 6 A, 8A, 10A, 12A, 15A

Operating Temperature -40°F to +122°F (-40° C to +50°C)

Mounting Locations Indoor, Outdoor, Wall, Array, Rooftop - Vertical, or Horizontal

Inverter Compatibility PVI 50-100KW, SGI 225-500PE, SGI 500XT, SGI 500/750XTM

Certifications Safety Listings & Certifications UL 1741, CSA C22.2#107.1, UL 1699B

Certification Agency ETL

Warranty

Standard 5 year

Power Supply/Signals Control Power** 120-277 VAC or 24 VDC / 0.32 A (max)

Dry Contact Arc-Fault Detection 24 V / 5 A rated

Enclosure Dimensions (H x W x D) 20 in. x 24 in. x 7 in. (508 mm x 610 mm x 178 mm)

Weight 42 lbs (19 kg) 43 lbs (19.5 kg) 44 lbs (20 kg)

Enclosure Rating Type 4; Optional Type 4X

Enclosure Polyester powder coated steel; Optional 316 stainless steel or fiberglass

*Inquire about option (code) for field-crimp lug plates for output terminals **External Control Power REQUIRED for all ARCCOM units. Each ARCCOM contains an AC/DC power supply. The customer needs to supply external control power 100-277VAC to the AC/DC power supply. If a customer would like to use external 24VDC Control Power instead, the internal control power form the AC/DC power supply to the main electronics board must be disconnected from the main electronics board.

See the Installation and Operations Manual for full details.

www.solectria.com | inverters@solectria.com | 978.683.9700

COMMERCIAL INVERTERS

COMMERCIAL INVERTERS

The PVI 50-100KW inverters are compliant with NEC 2014 690.11 &

690.12 requirement when ordered with the ARCCOM combiner. The most customizeable full line of commercial grid-tied PV inverters available today, the PVI 50-100KW series has been utilized in projects ranging from 50KW to multi-megawatt solar farms, including a 30MW solar farm. This series of inverters is capable of operating at 208 VAC, 240 VAC, 480 VAC, and 600 VAC and comes standard with AC and DC disconnects, transformer isolation, LCD, and monitoring gateway. They also contain a lightweight power stage making it easily serviceable. Options include premium efficient models, integrated fuse or breaker subcombiners, forward facing disconnects, stainless steel enclosure, web-based monitoring and sub-array monitoring, built-in cellular connectivity, and a dust filter. AC voltage and frequency settings may be customized according to utility specification.

FEATURES

• Compliant with NEC 2014 690.11

& 690.12 arc fault and rapid shutdown requirements when coupled with ARCCOM combiner

• Highest peak and CEC efficiencies

• Modbus communications

• User-interactive LCD

• Real power curtailment

OPTIONS

• Fuse or breaker subcombiner options

• Dust filter

• Forward facing disconnects

• Stainless steel enclosure

• Web-based monitoring

• Built-in cellular connectivity

• Sub-array monitoring

SOLECTRIA.COM

PVI 50KW

PVI 60KW

PVI 75KW

PVI 85KW

PVI 100KW

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MADE IN THE USA

SPECIFICATIONS PVI 50KW PVI 60KW PVI 75KW PVI 85KW PVI 100KW

DC Input

Absolute Maximum Input Voltage 600 VDC

Max Power Input Voltage Range (MPPT)* 300-500 VDC

MPPT Input Voltage Range - Low Voltage Option 285-500 VDC

Maximum Operating Input Current 176 A 211 A 264 A 299 A 351 A

Maximum Operating Input Current - Low Voltage Option 185 A 222 A 278 A 314 A 370 A

Strike Voltage 400 V

Strike Voltage - Low Voltage Option 380 V

Rapid Shutdown Bleed Down Time ( to < 30V) < 10s

AC Output

Nominal Output Voltage 208, 240, 480 or 600 VAC, 3-Ph (3-wire standard, 4-wire optional)

AC Voltage Range (Standard) -12%/+10%

Continuous Output Power 50 kW 60 kW 75 kW 85 kW 100 kW

Continuous Output Current

208 VAC 139 A 167 A 208 A 236 A 278 A

240 VAC 120 A 144 A 180 A 205 A 240 A

480 VAC 60 A 72 A 90 A 102 A 120 A

600 VAC 48 A 58 A 72 A 82 A 96 A

Maximum Backfeed Current 0 A

Nominal Output Frequency 60 Hz

Output Frequency Range 57.0 -60.5 Hz

Power Factor Adjustable - 0.9 to +0.9, factory set at 1

Total Harmonic Distortion (THD) @ Rated Load <3%

Efficiency

Peak Efficiency

208 VAC 96.7% 96.7% 97.3% 96.6% 96.5%

240 VAC 97.7% 97.8% 97.1% 96.7% 96.9%

480 or 600 VAC 96.5% 96.5% 97.2% 96.9% 96.9%

CEC Efficiency

208 VAC 96.0% 96.0% 97.0% 96.0% 96.0%

240 VAC 97.0% 97.0% 96.0% 96.0% 96.0%

480 VAC 96.0% 96.0% 97.0% 96.5% 96.5%

Tare Loss < 3 W

Subcombiner Options

Fuses or Breakers 2-8 positions, 40-300 A

Temperature

Ambient Temperature Range (full power) -40°F to +131°F (-40°C to +55°C)

Storage Temperature Range -40°F to +131°F (-40°C to +55°C)

Relative Humidity (non-condensing) 0-95%

Data Monitoring

Optional SolrenView Web-based Monitoring Integrated

Optional Revenue Grade Monitoring External

Optional SolZoneTM Sub-Array Monitoring (DC Current) 2-8 zones

Optional Cellular Communication SolrenView AIR

External Communication Interface RS-485 SunSpec Modbus RTU

Certifications

Safety Listings & Certifications UL 1741/IEEE 1547, CSA C22.2#107.1, FCC part 15 B

Certification Agency ETL

Warranty

Standard 5 year

Optional 10, 15, 20 year; extended service agreement; uptime guarantee

Enclosure dBA (Decibel) Rating < 62 dBA @ 3 m

Transformer Standard, fully-integrated (internal)

AC/DC Disconnects Standard, fully-integrated

Dimensions - Side Facing Disconnects (H x W x D) Dimensions - Forward Facing Disconnects (H x W x D)

78.2 in. x 50-53 in. x 33 in. (1987 mm x 1270-1347 mm x 839 mm)**

78.2 in. x 79-88 in. x 33 in. (1987 mm x 2007-2236 mm x 839 mm)**

Weight 1450 lbs (658 kg) 1875 lbs (851 kg)

Enclosure Rating Type 3R

Enclosure Finish Polyester powder coated steel; Optional 316 stainless steel *At nominal AC voltage **Width dependent upon rating of disconnect chosen www.solectria.com | inverters@solectria.com | 978.683.9700

Maximum Efficiency.

The latest, high-efficiency monocrystalline and polycrystalline cell technology from the world’s leading cell suppliers

Excellent low light performance

Improved output due to positive sorting of power classes (0 to +4.99 Wp)

PID-free products with guaranteed performance stability

Exceptional module efficiency of up to 16.2%

Highest Stability and Longevity.

Comprehensive lifespan tests, including outdoor tests and climate chamber storage

34 mm anodized aluminum frame with twin-wall profile

Drainage holes for outstanding weather-resistance

Corrosion-proof component

SOLON Quality for all Projects.

SOLON Blue 220/16 and SOLON Black 220/16 are standard solutions for all photovoltaic projects– whether on detached houses or large industrial rooftops. They combine quality and reliability at a fair price. With efficiency of over 16 %, “Made by SOLON” quality and free-of-charge module recycling, each project is a success. It’s as simple as that.

Highest Quality.

All system components meet stringent SOLON quality criteria

Rigorous process and material monitoring

Continuous auditing using internal and external tests

Safety Included.

High mechanical durability: tested to 5,400Pa (550 kg/m2)

Comprehensive SOLON warranties

SOLON Advantages:

10-year product warranty1)

5-level performance guarantee for 25 years1)

Positive sorting of power classes (0 to +4.99 Wp)

1) According to the SOLON Product and Performance Guarantee.

SOLON 220/16

SOLON Black 220/16 (monocrystalline)

Electrical data – typical (STC) STC (Standard Test Conditions): 1,000 W/m², (25 ± 2)°C, AM 1.5 in accordance with EN 60904-3 Power rating Pmax 265 Wp1) 260 Wp1) 255 Wp 250 Wp 245 Wp 240 Wp Module efficiency 16,16% 15,85% 15,55% 15,24% 14,94% 14,63% Rated voltage Umpp 30,7 V 30,5 V 30,2 V 30,0 V 29,8 V 29,6 V Rated current Impp 8,67 A 8,57 A 8,45 A 8,34 A 8,22 A 8,11 A Open circuit voltage Uoc 38,1 V 37,8 V 37,5 V 37,3 V 37,0 V 36,8 V Short circuit current Isc 9,01 A 8,92 A 8,83 A 8,74 A 8,65 A 8,56 A Maximum reverse current Ir 20 A 20 A 20 A 20 A 20 A 20 A Maximum system voltage 1.000 V 1.000 V 1.000 V 1.000 V 1.000 V 1.000 V Measuring tolerance for Pmax: ± 3% Reduction of module efficiency from 1,000 W/m² to 200 W/m2 : < 4 %

Electrical data – typical (NOCT) NOCT (Nominal Operating Cell Temperature): 800 W/m², NOCT, AM 1.5 Power rating Pmax 190 Wp 186 Wp 183 Wp 179 Wp 176 Wp 172 Wp Rated voltage Umpp 27,5 V 27,3 V 27,1 V 26,9 V 26,7 V 26,6 V Rated current Impp 6,92 A 6,83 A 6,75 A 6,66 A 6,57 A 6,48 A Open circuit voltage Uoc 34,4 V 34,2 V 33,9 V 33,7 V 33,5 V 33,2 V Short circuit current Isc 7,27 A 7,20 A 7,13 A 7,06 A 6,98 A 6,91 A

Thermal data Tc of open circuit voltage -0,33% /K Tc of short circuit current 0,04% /K Tc of power -0,43% /K NOCT (according to IEC 61215) 48°C ± 2°C Measuring tolerance for all final data: ± 10 % (except Pmax (STC) and NOCT)

Electrical data – typical (STC) STC (Standard Test Conditions): 1,000 W/m², (25 ± 2)°C, AM 1.5 in accordance with EN 60904-3 Power rating Pmax 255 Wp 1) 250 Wp 245 Wp 240 Wp 235 Wp 230 Wp Module efficiency 15,55% 15,24% 14,94% 14,63% 14,33% 14,02% Rated voltage Umpp 30,5 V 30,3 V 30,1 V 29,9 V 29,8 V 29,6 V Rated current Impp 8,40 A 8,28 A 8,16 A 8,03 A 7,90 A 7,78 A Open circuit voltage Uoc 37,5 V 37,4 V 37,2 V 37,0 V 36,9 V 36,7 V Short circuit current Isc 8,83 A 8,71 A 8,59 A 8,47A 8,36 A 8,24 A Maximum reverse current Ir 20 A 20 A 20 A 20 A 20 A 20 A Maximum system voltage 1.000 V 1.000 V 1.000 V 1.000 V 1.000 V 1.000 V Measuring tolerance for Pmax: ± 3% Reduction of module efficiency from 1,000 W/m² to 200 W/m2 : < 5 %

Electrical data – typical (NOCT) NOCT (Nominal Operating Cell Temperature): 800 W/m², NOCT, AM 1.5 Power rating Pmax 186 Wp 182 Wp 178 Wp 175 Wp 171 Wp 167 Wp Rated voltage Umpp 27,8 V 27,6 V 27,4 V 27,3 V 27,1 V 26,9 V Rated current Impp 6,69 A 6,60 A 6,51 A 6,41 A 6,32 A 6,22 A Open circuit voltage Uoc 34,3 V 34,1 V 34,0 V 33,8 V 33,7 V 33,5 V Short circuit current Isc 7,17 A 7,07 A 6,97 A 6,88 A 6,79 A 6,69 A

Thermal data Tc of open circuit voltage -0,32% /K Tc of short circuit current 0,05% /K Tc of power -0,41% /K NOCT (according to IEC 61215) 46°C ± 2°C Measuring tolerance for all final data: ± 10 % (except Pmax (STC) and NOCT)

1) Available in limited amounts upon request.

SOLON Blue 220/16 (polycrystalline)

V. MEP DRAWINGS

a. Electrical Drawings:

a. E-001 – Electrical Rooftop PV Plan

b. E-002 – Electrical PV Riser Diagram

c. E-003 – Electrical PV Details

OVERALL ROOF PLAN

SCALE: 1/20" = 1'-0"

1 2 31 2 3

3 APPROXIMATE AREAS WITH

STRUCTURAL CAPACITY TO

SUPPORT PV ARRAYS

LOCATION OF

WEATHER STATION

MAXIMUM DISTANCE OF ROOFTOP

EQUIPMENT TO EDGE OF ROOF

COMBINER BOX 1

COMBINER BOX 2

COMBINER BOX 3

COMBINER BOX 4

COMBINER BOX 5

DOWN TO PV EQUIPMENT

ROOM BELOW

PV MODULES WITH

CONCRETE BLOCK

BALLASTS

EXISTING ROOFTOP

MECHANICAL EQUIPMENT

TO REMAIN (TYP)

SHEET NOTES:

1. LOCATION OF ROOFTOP MECHANICAL EQUIPMENT IS APPROXIMATE

BASED ON AS-BUILT DRAWINGS AND AERIAL PHOTOS OF THE SITE. EXACT

LOCATIONS SHALL BE FIELD VERIFIED PRIOR TO FINAL LAYOUT.

2. EXISTING ROOFTOP WALKING SURFACE TO BE RE-ROUTED BASED ON

FINAL PV CONFIGURATION.

1 2 31 2 3

1 2 31 2 3 4

7 8 9 10 11 12 13 14

5 6

1 2 31 2 3 4

7 8 9 105 6

1 2 31 2 3 4 5 6

7 8…