A06_PV_CONDITION_ASSESSMENT_MPLC_WAREHOUSE.pdf

Bureau of Land Management PV Condition Assessment Uncompahgre Field Office

Submitted on: April 9, 2025

Submitted to: Bureau of Land Management

Submitted by: Ameresco, Inc.

111 Speen Street, Ste. 410 Framingham, MA 01701

Point of Contact: Greg Caplan VP Federal Business Development gcaplan@ameresco.com 202-650-6214

Ameresco: PV Condition Assessment Colorado Site (Uncompahgre Field Office) Bureau of Land Management Table of Contents

Table of Contents

1.0 PV Condition Assessment – Uncompahgre Field Office

1.1 Uncompahgre Field Office

1.1.a PV condition assessment survey

1.1.b Visual Observation of Panels, Exposed Electrical Wire / Insulation / Conduit, Inverters, and Associated Electrical Equipment

1.1.c Visual Inspection of Mounting Structure

1.1.d Review and Verify Proper Grounding

1.1.e Verify Wiring, Conductors, and Conduit

1.1.f Verify Safety Markings and Signs

1.1.g Net Metering

1.1.h NEC Code Violations

1.1.i Performance Testing

1.1.j System Comparison and Recommendations

1.1.k Energy Management System

Appendix A: Drawings

Appendix B: PVsyst Simulation Report

Bureau of Land Management Page 1

1.0 PV Condition Assessment – Uncompahgre Field Office

Perform condition assessments of 26 photovoltaic (PV) systems located in eight western states and determine the appropriate methods for transmitting data from those systems into the contractor’s Energy Management Information System. Referred to collectively as PV field work.

1.1 Uncompahgre Field Office

32 kW of photovoltaic generation, with 1 – 30 kW inverter, North Office Building energy meter, and renewable energy meter (all existing)

1.1.a PV condition assessment survey

Provide the following for each of the 26 PV sites described in Subparagraph l. Provide system description including block system diagram, and photographic records. Document PV system components including the following:

Figure 1: Current PV Configuration at Uncompahgre

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i. Panels: Manufacture, model number, individual panel watts, number of strings, total number of panels, total system watts, expected degradation rate.

a. Array 1

i. Manufacturer: Solar World

ii. M/N: SW 245

iii. Individual panel watts: 245W

iv. Number of strings: 11

v. Total number of panels: 132

vi. Total system watts: 32 kW DC

b. Expected degradation rate: 19%

ii. Description of mounting and mounting system, i.e., roof mounted with ballast or rack system, or ground mounted with steel rack system.

Ground Mounted w/steel racking for both arrays

iii. Inverter: Include inverter manufacture, model number, the type of interface capabilities of the inverter and whether it is currently connected for remote reading or is capable of being connected for remote reading.

a. Manufacturer: PV Powered

b. Model number: PVP30kw

i. CEC efficiency: 93%

c. Serial number: unreadable

d. Communication Interface: RS-485

e. EchoLabs not communicating during our visit

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iv. AC and DC disconnect, fuses, and circuit breakers. Provide manufacture and disconnect, fuse, and circuit breaker sizes. Verify DC disconnect is DC-rated.

a. Inverter AC Disconnects #1 & #2 (AC Combiner Panels)

i. Siemens 30A 600VAC - 3 Pole

ii. Fuses - LITTELFUSE FLSR-30-ID W/INDICATOR, 30 AMP, CLASS RK5, DUAL ELEMENT, FLSR_ID SERIES, 75-600VAC, TIME DELAY, FUSE

b. Main AC Disconnect

i. Siemens 60A 600VAC - 3 Pole

ii. Fuses - LITTELFUSE FLSR-60-ID W/INDICATOR, 60 AMP, CLASS RK5, DUAL ELEMENT, FLSR_ID SERIES, 75-600VAC, TIME DELAY, FUSE

c. Array #1 & #2 DC Disconnects

i. Square D 60A - 600VAC & 600VDC - 3 Pole - Non-Fused

ii. Disconnects are DC rated

v. Description of rapid shutdown system.

N/A. None present on these systems.

Figure 2: Current communication

Bureau of Land Management Page 4

1.1.b Visual Observation of Panels, Exposed Electrical Wire / Insulation / Conduit, Inverters, and Associated Electrical Equipment

Visual observation of the conditions of individual panels, exposed electrical wire/insulation/conduit, inverters, and associated electrical equipment. Photos shall be taken during the survey and included in the site assessment report. Common examples include cracked, damaged, or discolored individual panels, shaded or dirty panels, water intrusion in panel, corrosion and encapsulate yellowing, deteriorated electrical components such as strings, combiner box, disconnects, fuses, cables, conduit, or other exposed equipment, and equipment identified as beyond or near its estimated useful life.

i. Modules and Array wiring

a. PV wire and MC4 connector insulation is fine.

b. Wire management is very good.

ii. Inverters

a. Inverter is not operational, electrical tech. spent the day troubleshooting and all were in fatal fault.

iii. AC & DC Disconnects & Fuses

a. No corrosion or thermal issues present.

b. DC disconnects need to be cleaned and wasp nests removed.

iv. Conduit & Gutters

a. No corrosion or thermal issues present.

v. DC Combiners & Strings

a. No corrosion or thermal issues present.

Bureau of Land Management Page 5

Figure 3: Wire management and mountings are all very good condition

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1.1.c Visual Inspection of Mounting Structure

Visually inspect mounting structure to ensure roof penetrations are properly sealed, supports are structurally sound, and ballast systems are properly aligned.

Figure 4: Uncompahgre site, showing the non-functional inverter

Supports are structurally sound, and ballast system properly aligned.

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1.1.d Review and Verify Proper Grounding

Review and verify proper grounding of all metallic surfaces including metallic PV module frames.

Figure 5: Typical grounding at Uncompahgre

System is properly grounded.

Bureau of Land Management Page 8

1.1.e Verify Wiring, Conductors, and Conduit

Verify wiring, conductors, and conduit are secure.

Wiring, conductors, and conduit were all secure during our two site visits.

1.1.f Verify Safety Markings and Signs

Verify safety markings and signs are installed and are legible.

Fail, site needs new safety markings in accordance with federal and state regulations.

1.1.g Net Metering

Determine whether the PV system is connected to the grid and set up for net metering. Verify net metering is operational.

Net meter is readable, but the inverter is not operational.

1.1.h NEC Code Violations

Identify and document NEC code violations.

Pass, no NEC code violations were present during either of the two site visits.

1.1.i Performance Testing

Performance testing: Provide and report the following:

1. Date and time.

06/25/2024, 8:00 am

2. Name and contact information of person performing tests/inspection.

Chris Carelli, any questions regarding the test should be directed to Tim Mullen, tmullen@ameresco.com 410-507-6603

3. Time of day and weather conditions.

8 am, full sun

Bureau of Land Management Page 9

4. Solar irradiance level.

230 w/m2

5. Ambient temperature.

75° F

6. Array temperature.

90°F

7. Open-circuit voltage (Voc) and polarity of each string. (Verify all strings have the same number of modules).

a. Polarity

a. All Strings - Pass

b. Same Module Count on Strings

a. Pass

c. Array #1

a. Combiner #1

i. 410v

ii. 409v

iii. 410v

iv. 410v

v. 409v

vi. 409v

b. Combiner #2

i. 410v

ii. 410v

iii. 392v

iv. 410v

v. 410v

8. Short-circuit current (Isc) of each string.

8.25 Amps

9. Confirm inverter is operational.

Inverter is not operational

10. Confirm inverter shuts down if AC utility is disconnected Inverter not operational

Bureau of Land Management Page 10

11. Maximum power point current (Imp) for each string. Current measurements for each string should be within 0.1A range of each other assuming consistent weather conditions, and all strings having same tilt and azimuth angle.

a. No readings for inverter 1 since this information can only be recorded when inverter is operating.

12. Check condition of combiner box fuses for inoperable strings.

Pass, no blown fuses.

13. Confirm inverter’s power reading using independent meters. Afterwards, inverter power readings may be used for subsequent reporting.

Inverters not operational.

14. Expected standard test condition (STC) power.

32.3 kWp

15. System power output under actual conditions.

Inverters are not operational.

16. Calculate the balance-of-system efficiency.

Inverters are not operational.

17. Compare actual performance to expected STC power.

Inverters are not operational.

18. Total power generated (kWh).

Inverters are not operational.

19. Determine system expected degradation rate based upon manufacturer’s literature.

Inverters are not operational.

20. Determine actual system degradation rate.

Inverters are not operational.

1.1.j System Comparison and Recommendations

System Comparison and Recommendations:

1. Determine if additional troubleshooting, including the number of hours required to perform troubleshooting, is necessary to determine why the renewable system is not operating optimally.

Inverters are not operational; it is recommended that the inverter be removed and replaced as outlined below.

Bureau of Land Management Page 11

2. Compare on-site data measurements to manufacturer data.

Not applicable, inverters are not operational.

3. Provide recommendations for maintenance, repairs, and improvements to optimize the performance the system based upon site investigation and data analysis.

Include a detailed cost estimate of the work required to restore, repair, or upgrade the system based upon recommendations.

Ameresco recommends that the inoperable inverter be removed and replaced with a Sunny Tri power Core 1 33-US Sunny Tri-power 33kW inverters. We would test all solar panels and any with a short circuit will be bypassed. With the new inverters Ameresco would also install a new NEMA 4 junction box. This fix will make the PV field operational again at which time we can take baseline field readings and provide that data to BLM to compare system performance going forward.

If Ameresco does the inverter upgrade, we will also provide the required safety signage for the site for an additional $400.00.

Figure 6: Proposed new inverter configuration.

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4. Provide a projection of the remaining life expectancy of functional components, as well as for the overall system.

a. Solar Panels

i. Current panels are 9.5 years old

ii. Most manufacturers offer warranties of 25–30 years, guaranteeing at least 80% of the original efficiency by the end of the period.

iii. Many panels continue operating beyond 30 years with reduced efficiency.

b. Inverters

i. Needs replacing

c) Racking and Wiring:

i. Typically, last 30+ years with minimal maintenance.

ii. Corrosion or weather damage may require minor repairs over time.

Factors Affecting Lifespan:

• Quality of components: Higher-quality materials and reputable brands last longer.

• Environmental conditions: Harsh weather (extreme heat, humidity, hail, snow) can degrade components faster.

• Maintenance: Regular inspections and cleaning improve longevity.

• Installation quality: Poor installation can lead to premature failure of electrical and structural components.

5. Include a detailed cost estimate of the work required to restore/repair/upgrade the renewable energy systems, so they are fully functional.

Bureau of Land Management Page 13

Table 1: Cost of installing a new inverter

6. Report on PV systems and recommendations on work to restore/repair/upgrade them must also evaluate the cost to completely replace the PV system and compare the repair cost to the replacement cost of a similarly sized PV system. The field investigation report may confirm that based on the age of the existing PV array, replacing it may be the most economical solution. If replacement is the conclusion providing a detailed estimate on the cost of the repair of the existing system is not necessary. However, a justification describing the significant deficiencies of the existing system is to be provided.

Estimated cost of a new 33 kW system is in the ballpark of $140,000.00 to $165,000.00

Bureau of Land Management Page 14

1.1.k Energy Management System

Reporting to the energy management system.

1. Detail and describe how electrical generation from each PV system and functional operation information will be transmitted to the contractor’s energy management system.

The PV system at Uncompahgre Field Office will use a Leviton IDAS-A8810-4G-S data acquisition system (DAS) to connect to the existing inverters Modus TCP (Ethernet). Data is collected by the DAS and uploaded periodically to AssetPlanner using a Cradlepoint cellular modem (typically a Cradlepoint S700). The communication between the DAS and AssetPlanner is encrypted. The DAS and cellular modem will be mounted in a NEMA 4 enclosure.

2. The following information is to be transmitted from each PV site to the contractor’s energy management system. The information is to be processed by the energy management system to create PV production reports, allow for comparison of each PV site, and calculation of emissions reduced, and their greenhouse gas equivalents.

The DAS will provide current electrical energy production reported by each inverter on site.

Inverter level metering will include voltage, current and power factor for each phase, as well as any alarms or fault codes generated by the inverter. In addition to the alarms generated by the inverters, AssetPlanner’s Analytics Planner module includes a rules engine that includes rules to trigger alerts based on lower than expected production or loss of communication. The rules engine also allows for user define rules using any of the data points monitored by the DAS.

AssetPlanner will create PV production reports and calculate emissions reductions and greenhouse gas equivalents based on metered PV electric energy generation. It also has the site and portfolio level dashboards to monitor the current production and status of the systems and can optionally create public dashboards.

Figure 7: Overview of PV Data Acquisition System and AssetPlanner Analytics Planner for PV Systems

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Figure 8: Sample portfolio and site status dashboards from AssetPlanner Analytics Planner for PV Systems

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3. Include a single line diagram showing existing and new components required to enable reporting to the energy management system.

Figure 9: One line diagram of data acquisition system showing existing inverter and electric energy meter

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4. Include a detailed cost estimate of the work required to enable reporting to the energy management system. The cost estimate shall include detailed material breakouts, and labor hours. Use of lump sum costing is not acceptable.

The estimated cost of hardware and installation labor is $4,838.85 and the estimated annual fees for software subscription and cellular data services are $934. Detailed cost estimates are shown in the following two tables.

Table 2: Estimated DAS Hardware and Installation Costs for PV System Monitoring

Description Part Number Qty Unit Cost

Total Cost

Data Acquisition System with cell model and enclosure

Leviton

IDAS-A8810-4G-S 1 $3,150.00 $3,150.00

Shipping (estimated) 1 $150.00 $150.00 Installation Labor (on-site) Electrician 8 hours $71.40 $571.20

Configuration & Commissioning Labor Building Control Systems Engineer 5 hours $191.53 $ 957.65

Total Hardware Installation Cost $4,828.85

Table 3: Estimated Annual Fees for PV System Monitoring

Description

Part Number

Qty Unit Cost

Total Cost

Annual Subscription Fee for AssetPlanner Analytics Planner Module for DER-PV

AP-AnP-DER-PV

$350.00

$350.00

Cellular Data Plan Annual Fee ASG-Cell-1GB 1 $400.00 $400.00 Total Annual Fees $750.00

Bureau of Land Management Appendix

Appendix A: Drawings

INV-1 PV POWER,

PVP30KW, 480VAC

PV ARRAY

1 2 3 12

1 2 3 12

CB01

5 STRING

12 MOD/STG

(1) 15A FUSE/STG

CB02

6 STRING

12 MOD/STG

(1) 15A FUSE/STG

SOLAR WORLD

SW 245 MONO

TO

(E) FACILITY

CONNECTION.

FIELD VERIFY

LOCATION FOR

AS BUILT

DRAWINGS

SOLAR WORLD

SW 245 MONO

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DRAWING NUMBER

PROJECT NO.

DRAWING TITLE

Pl ot

D at e:

ISSUED FORREV DATE

2355 EAST CAMELBACK ROAD,

SUITE 410

PHOENIX, AZ, 85016

480.499.9200 www.ameresco.com

ELECTRICAL ENGINEER

5716 FOLSOM BLVD, #309

SACRAMENTO, CA, 95819

(916 425-4056) | PVAMPS.COM

LICENSE # AZ 62410

SEALS AND SIGNATURES

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SINGLE LINE

DIAGRAM

KEYNOTES

1 (E) INVERTER TO BE REMOVED

(E) PV MODULES TO REMAIN.

(E) ELECTRICAL EQUIPMENT TO BE REMOVED OR ABANDONED IN

PLACE. COORDINATE WITH OWNER.

PV ARRAY

1 2 3 12

1 2 3 12

SOLAR WORLD

SW 245 MONO

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CONNECTION.

FIELD VERIFY

LOCATION FOR

AS BUILT

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SOLAR WORLD

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SUNNY TRIPOWER CORE 1 33-US

MPPT 1

MPPT 2

MPPT 3

MPPT 6

MPPT 5

MPPT 4

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DRAWING NUMBER

PROJECT NO.

DRAWING TITLE

Pl ot

D at e:

ISSUED FORREV DATE

2355 EAST CAMELBACK ROAD,

SUITE 410

PHOENIX, AZ, 85016

480.499.9200 www.ameresco.com

ELECTRICAL ENGINEER

5716 FOLSOM BLVD, #309

SACRAMENTO, CA, 95819

(916 425-4056) | PVAMPS.COM

LICENSE # AZ 62410

SEALS AND SIGNATURES

UN

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DRAWN BY: JP

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KEYNOTES

1 EXTEND EACH STRING WIRE TO INVERTER LOCATION. ATTACH AMPHENOL

H4 PLUS CONNECTORS (VERIFY WITH SMA) AND DIRECTLY CONNECT THE

STRING WIRE TO INVERTER TERMINALS. INVERTER MPPT RANGE

330V-800V.

TERMINATE INVERTER OUTPUT CIRCUIT CONDUCTORS AT 50A/3P

BREAKER.

Bureau of Land Management Appendix

Appendix B: PVsyst Simulation Report

PVsyst V8.0.6

PVsyst - Simulation report Grid-Connected System

Project: Uncompahgre Montrose Field Office Variant: Uncompahgre Montrose Field Office v01_2025-03-21

Sheds, single array System power: 32.3 kWp

Montrose Co. Arpt - United States

Author PV AMPS (United States)

21/03/25

VC0, Simulation date:

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Project: Uncompahgre Montrose Field Office Variant: Uncompahgre Montrose Field Office v01_2025-03-21

PV AMPS (United States)

PVsyst Licensed to PV AMPS (United States)

Project summary

Geographical Site Montrose Co. Arpt United States

Situation Latitude Longitude Altitude Time zone

38.50 -107.90

UTC-7

°N °W m

Project settings Albedo 0.20

Weather data Montrose Co. Arpt

NREL NSRD : TMY3

System summary

Grid-Connected System Sheds, single array

Orientation #1 Fixed plane Tilt/Azimuth 30 / 0 °

Near Shadings Linear shadings : Fast (table)

User's needs Unlimited load (grid)

System information PV Array Nb. of modules Pnom total

32.3 units kWp

Inverters Nb. of units Pnom total Pnom ratio

30.0

1.078 unit kWac

Results summary Produced Energy 48895 kWh/year Specific production 1512 kWh/kWp/year Perf. Ratio PR 77.62 %

Table of contents Project and results summary General parameters, PV Array Characteristics, System losses Near shading definition - Iso-shadings diagram Main results Loss diagram Predef. graphs Single-line diagram

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PV AMPS (United States)

PVsyst Licensed to PV AMPS (United States)

General parameters

Grid-Connected System Sheds, single array

Orientation #1 Fixed plane Tilt/Azimuth 30 / 0 °

Sheds configuration Nb. of sheds Single array

3 units

Shading limit angle Limit profile angle 18.5 °

Sizes Sheds spacing Collector width Average GCR Top inactive band Bottom inactive band

8.00 3.37 42.1 0.02 0.02 m m m m

Models used Transposition Diffuse Circumsolar

Perez Imported separate

Horizon Free Horizon

Near Shadings Linear shadings : Fast (table)

User's needs Unlimited load (grid)

PV Array Characteristics

PV module Manufacturer Model

SolarWorld SW 245 Mono

(Original PVsyst database) Unit Nom. Power 245 Wp Number of PV modules Nominal (STC) Modules

32.3

11 string x 12 units kWp In series

At operating cond. (50°C) Pmpp U mpp I mpp

28.80 kWp V A

Inverter Manufacturer Model

PV Powered

PVP 30KW-480

(Original PVsyst database) Unit Nom. Power 30.0 kWac Number of inverters Total power

30.0 unit kWac

Operating voltage Pnom ratio (DC:AC)

295-500 1.08

V

Total PV power Nominal (STC) Total Module area kWp modules m²

Total inverter power Total power Number of inverters Pnom ratio

1.08 kWac unit

Array losses

Thermal Loss factor Module temperature according to irradiance Uc (const) Uv (wind)

20.0 0.0

W/m²K W/m²K/m/s

DC wiring losses Global array res.

Loss Fraction

1.5 mΩ % at STC

Module Quality Loss Loss Fraction 1.5 %

Module mismatch losses Loss Fraction 2.0 % at MPP

Strings Mismatch loss Loss Fraction 0.2 %

IAM loss factor ASHRAE Param.: IAM = 1 - bo (1/cosi -1) bo Param. 0.05

AC wiring losses

Inv. output line up to injection point Inverter voltage Loss Fraction

1.00

Vac tri % at STC

Inverter: PVP 30KW-480 Wire section (1 Inv.)

Wires length

Copper 1 x 3 x 6 mm² m

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PV AMPS (United States)

PVsyst Licensed to PV AMPS (United States)

Near shadings parameter

Perspective of the PV-field and surrounding shading scene

Iso-shadings diagram

Orientation #1

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PV AMPS (United States)

PVsyst Licensed to PV AMPS (United States)

Main results

System Production Produced Energy 48895 kWh/year Specific production

Perf. Ratio PR

77.62 kWh/kWp/year

Normalized productions (per installed kWp) Performance Ratio PR

Balances and main results

GlobHor DiffHor T_Amb GlobInc GlobEff EArray E_Grid PR kWh/m² kWh/m² °C kWh/m² kWh/m² kWh kWh ratio

January 71.5 31.25 -3.60 113.2 108.2 3371 3135 0.856 February 81.3 40.71 1.60 110.6 106.3 3225 2998 0.838 March 127.5 51.21 3.83 155.8 150.2 4432 4122 0.818 April 151.8 59.55 7.28 162.9 156.4 4468 4153 0.788 May 192.2 69.48 15.71 187.2 179.1 4936 4592 0.758 June 235.7 55.85 21.71 219.4 210.5 5493 5110 0.720 July 182.9 72.02 22.05 174.2 166.6 4442 4129 0.733 August 184.7 60.99 21.99 191.4 183.8 4860 4527 0.731 September 154.3 46.87 18.86 182.9 176.2 4723 4399 0.744 October 123.0 37.61 10.60 169.2 163.6 4598 4280 0.782 November 93.3 21.95 4.00 155.9 149.8 4355 4058 0.805 December 70.1 22.28 -2.44 124.9 118.9 3645 3391 0.839

Year 1668.2 569.77 10.17 1947.7 1869.6 52547 48895 0.776

Legends GlobHor DiffHor T_Amb GlobInc GlobEff

Global horizontal irradiation Horizontal diffuse irradiation Ambient Temperature Global incident in coll. plane Effective Global, corr. for IAM and shadings

EArray E_Grid

PR

Effective energy at the output of the array Energy injected into grid Performance Ratio

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PV AMPS (United States)

PVsyst Licensed to PV AMPS (United States)

Loss diagram

Global horizontal irradiation1668 kWh/m²

+16.8% Global incident in coll. plane

-1.5% Near Shadings: irradiance loss

-2.5% IAM factor on global

Effective irradiation on collectors 1870 kWh/m²

* 221 m² coll.

efficiency at STC = 14.67% PV conversion

Array nominal energy (at STC effic.)60705 kWh

-0.6% PV loss due to irradiance level

-8.6% PV loss due to temperature

-1.5% Module quality loss

-2.1% Mismatch loss, modules and strings

-1.1% Ohmic wiring loss

Array virtual energy at MPP52576 kWh

-6.4% Inverter Loss during operation (efficiency)

0.0% Inverter Loss over nominal inv. power

0.0% Inverter Loss due to max. input current

0.0% Inverter Loss over nominal inv. voltage

0.0% Inverter Loss due to power threshold

-0.1% Inverter Loss due to voltage threshold

Available Energy at Inverter Output49175 kWh

-0.6% AC ohmic loss

Energy injected into grid48895 kWh

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PV AMPS (United States)

PVsyst Licensed to PV AMPS (United States)

Predef. graphs

Daily Input/Output diagram

System Output Power Distribution

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VC0, Simulation date:

21/03/25 08:43 with V8.0.6

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/HRV (Za stvaranje Adobe PDF dokumenata najpogodnijih za visokokvalitetni ispis prije tiskanja koristite ove postavke. Stvoreni PDF dokumenti mogu se otvoriti Acrobat i Adobe Reader 5.0 i kasnijim verzijama.)

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/NOR /POL /PTB /RUM /RUS /SKY /SLV /SUO /SVE /TUR /UKR /ENU (Use these settings to create Adobe PDF documents best suited for high-quality prepress printing. Created PDF documents can be opened with Acrobat and Adobe Reader 5.0 and…