Solar Glare Analysis Report Alberta Solar One...Solar Glare Analysis Report – Alberta Solar One...

Solar Glare Analysis Report – Alberta Solar One Morgan Solar Inc., County of Forty Mile, Alberta

Version 2.0 – Issued for Use

Confidential

12 September 2018

Delivered to: Samuel Buckstein, Morgan Solar Inc.

Solas Energy Consulting Inc. Suite 119, 2-2009 33 Ave SW Calgary, Alberta T2T 1Z5

Phone: 403-454-9463 Email: [email protected] Web: www.solasenergyconsulting.com

mailto:[email protected]

Alberta Solar One Glare Analysis

Confidential

12 September 2018 Page i

Acknowledgement

Prepared by: Leonard Olien

Jason Mah

Paula McGarrigle

Document Purpose

This report provides an assessment of glare hazard from the Alberta Solar One solar farm in the

County of Forty Mile, Alberta, Canada.

Document History


Version Date Comments

1.0 12 August 2018 Issued for Review

2.0 12 September 2018 Issued for Use - updated analysis to include limitations to tracking rotation

Disclaimer

While this document is believed to contain correct information, Solas Energy Consulting Inc. (“SOLAS”) does not make any

warranty, either expressed or implied, nor assumes any legal liability or responsibility for accuracy, completeness,

methodology, usefulness, reliability, or current status of any material contained in this document (“Report”), nor shall SOLAS

assume any liability with respect to any matter or information referred to or contained in the Report, nor shall any person

relying on the Report (“Recipient”) or any party to whom the Recipient provides the Report or information have any claim

against SOLAS arising out of such Report. The interpretation of this or any other data or report related to this project is solely

the responsibility of the client.


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12 September 2018 Page ii

Table of Contents

1 INTRODUCTION ............................................................................................................................................ 4

2 PROJECT DESCRIPTION ................................................................................................................................. 5

3 PROJECT ASSUMPTIONS ............................................................................................................................... 7

4 GLARE REGULATIONS AND RECEPTORS ......................................................................................................... 8

5 GLARE PREDICTION METHOD ..................................................................................................................... 11

6 ANALYSIS RESULTS ..................................................................................................................................... 13

7 CONCLUSIONS AND DISCUSSION ................................................................................................................ 14

Table of Figures

Figure 1: Location of the Project: Alberta Solar One and proximity to Burdett and Highway 3.................................... 5

Figure 2: Project Boundary and Proposed Alberta Solar One Array .............................................................................. 6

Figure 3: Alberta Solar One Array with Observation Points Identified .......................................................................... 9

Figure 4: Reflected Light and Angle of Incidence on the PV Module Illustration ........................................................ 11

Table of Tables

Table 1: Description of Observation Points ................................................................................................................. 10

Table of Appendices

Appendix A ForgeSolar Modelling Assumptions


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12 September 2018 Page iii

Glossary

Abbreviation Term

After-image Visual image that persists after the stimulus that caused it has stopped.

AUC Alberta Utilities Commission

Azimuth Horizontal angle of the Sun around an object. North is 0°, east is 90°, south is 180°, and west is 270°.

FP Flight path

kWDC Kilowatts Direct Current

mrad Measure of angle, 1/1000th of a radian

MWAC Megawatts Alternating Current

MWDC Megawatts Direct Current

OP Observation point

Subtended Angle Size of an object divided by the distance from the observer.

WDC Watts Direct Current


Section 1, Introduction

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12 September 2018 Page 4

1 INTRODUCTION Morgan Solar Inc. (Morgan Solar) is developing a utility-scale solar photovoltaic project called

Alberta Solar One (Project) in southeastern Alberta. The Project is located north of Highway 3,

approximately four kilometres west of Burdett, Alberta. The Project is expected to have a total

capacity of 9.5 MWAC.

Photovoltaic (PV) solar modules are designed to convert sunlight into electricity; however, up to

10 percent of the sunlight may be reflected into the surrounding areas1. In certain situations, the

reflected sunlight can produce glint (a momentary flash of bright light) and glare (a continuous

source of bright light) that may result in an ocular impact to individuals.

Solas Energy Consulting Inc. (Solas) was retained by Morgan Solar to conduct a glare analysis for

observation points at nearby residences, and from major transportation infrastructure near the

Project. Solas performed an analysis for residential locations, major roadways, and the rail line near

the Project.

This report documents the potential for solar glare from the Project at the observation points.

1 Solar Glare Hazard Analysis Tool (SGHAT) User’s Manual v 1.0, Ho and Sims, Sandia National Laboratories,

2013.


Section 2, Project Description

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2 PROJECT DESCRIPTION The 9.5 MWAC Project is a ground-mounted, dual-axis tracking solar concentrating photovoltaic

(CPV) array using new proprietary technology. The Project will be located on agricultural land in

the west half of NE-21-10-12-W4M. The approximate location of the Project is shown in Figure 1.

The Project will be connected to the distribution system, and the electricity produced will be sold

to the grid. Construction is expected to occur in 2018-2019.

The Project is 400 metres west of Range Road 123, one kilometre (km) north of Highway 3

(Crowsnest Highway) and the Canadian Pacific Railway, four kilometres west of Burdett, and 7.5

kilometres south of the South Saskatchewan River. The Burdett 368S substation is three kilometres

southeast of the Project. There are residences on the land around the Project, which is relatively

flat with few trees.

There are no registered helipads or airport landing strips within three kilometres of the Project.

Figure 1: Location of the Project: Alberta Solar One and proximity to Burdett and Highway 3

Figure 2 outlines the Project area in red and shows the solar CPV array as the dark interior area.


Section 2, Project Description

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Figure 2: Project Boundary and Proposed Alberta Solar One Array


Section 3, Project Assumptions

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3 PROJECT ASSUMPTIONS The Project is located on approximately 76 acres of land. Solas used multiple sources to determine

the site elevation, including a topographic site plan provided by Morgan Solar. A change of grade

may affect the results from the glare analysis.

The Project will use Morgan Solar’s 335-WattDC “SimbaX” solar CPV modules and “Savanna” dual-

axis tracking racks. Three CPV modules will be mounted on each tracker. Dual-axis trackers allow

modules to directly face the sun at all times, rotating to a maximum of 60 degrees from horizontal.

At night, the modules return to the horizontal orientation to enter stow mode. Stow mode is also

engaged during high wind events, positioning the short edge as the leading edge facing into the

wind. SimbaX modules have a glass surface that has anti-reflective coating. While the technology

associated with the SimbaX modules differs from standard solar PV, the SimbaX module’s use of a

glass surface with anti-reflective coating is consistent with that of solar PV. In the vertical position,

the modules will be 1.15 metres above the ground at the bottom, extending to a height of 3.15

metres at the top2. Approximate locations for the solar array vertices were used in the analysis as

exact coordinates were not available.

The model assumes the reflective surface lies in a plane defined by the array vertices, so the

analysis was completed at the top and bottom elevations to determine glare due to different

parts of the modules. The analysis was also run at an intermediate elevation of 2.15 metres to help

identify trends in the frequency and size of glare. The analysis was completed as if the Project will

be installed as a single array.

Detailed input parameters and assumptions can be found in Appendix A.

2 Data provided by Morgan Solar


Section 4, Glare Regulations and Receptors

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4 GLARE REGULATIONS AND RECEPTORS At the time of writing, there are no Canadian federal, provincial, or municipal regulations or

requirements regarding glare from solar projects. In the United States, the Federal Aviation

Administration stipulates that any glare occurring along an aircraft’s flight landing path must have

a low potential of producing after-image3. Glare outside of 50 degrees of the pilot’s line of sight is

not considered a risk.

Alberta Transportation requires developers to obtain a roadside development permit for

construction of structures near provincial highways. If a proposed development is to be located

within 300 metres of a provincial highway right-of-way, or within 800 metres of the centre point of

an intersection between a provincial highway and another public road, a roadside development

application must be made to Alberta Transportation. The proposed Project will not be located

within these boundaries, so it will not require a roadside development permit from Alberta

Transportation.

Transport Canada publication TP1247E Aviation Land Use in the Vicinity of Aerodromes offers

guidelines useful for glare reports. The guidelines indicate “The analysis of glare should involve a

review of the position of the aircraft for both landing and take-offs as well as performing a circling

approach… The designer should review the positioning and orientation of the panels in relation

to the control tower to ensure that adverse reflection will not be produced.”

Solas completed a review of registered airstrips and helipads within three kilometres of the Project,

and did not find any; therefore, Solas did not evaluate flight paths near the project. Solas selected

observation points to assess the potential glare on nearby residents and vehicle routes.

Observation points for residences near the Project were evaluated at an elevation of 1.83 metres

above ground level to mimic an individual standing at a window on the main floor. Observation

points on roads were evaluated at an elevation of 1.22 metres to mimic a driver sitting in a small

truck or passenger vehicle. Solas evaluated railway observation points at an elevation of 4.27

metres above ground level to simulate the conductor inside the cab of the train.

Solas analyzed the potential for glare at the observation points shown in Figure 3. Nine observation

points were evaluated.

3 https://www.federalregister.gov/documents/2013/10/23/2013-24729/interim-policy-faa-review-of-solar-

energy-system-projects-on-federally-obligated-airports



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Figure 3: Alberta Solar One Array with Observation Points Identified

Table 1 lists the observation points used in the analysis. The table also identifies the number of

vehicles travelling along Highway 3 south of the Project.4,5

4 http://www.transportation.alberta.ca/mapping/2017/TM/00123080.pdf 5 http://www.transportation.alberta.ca/mapping/2017/TM/70000622.pdf



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Table 1: Description of Observation Points

Observation

Point Number

Location Description Daily Traffic

(Number of Vehicles)

OP1 Residence Main floor (1.83 metres) N/A




OP5 Highway 3 Eastbound 3,500

OP6 Highway 3 Westbound 3,640

OP7 Railway Approaching Range Rd 124 from the

west

N/A

OP8 Railway Approaching Range Rd 122 from the

east

N/A



Section 5, Glare Prediction Method

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5 GLARE PREDICTION METHOD The impact of glare depends on the interaction between the position of the sun, the tilt of the

solar modules, the reflectivity of the modules’ surface, the size of the project, and the relative

location of the driving path or the observer. Solas did not consider the screening effect from

existing or proposed hedgerows or other objects in this evaluation.

The sun’s position is described using the angle of elevation and solar azimuth. The angle of

elevation is the angle between the horizon and the centre of the sun. The azimuth is measured as

the angle from true north in a clockwise direction.

Solas performed the glare analysis using the ForgeSolar GlareGauge6 software tool. This tool uses

project inputs and solar positioning calculations to determine if glare will occur at identified

observation points. If glare is found, the tool calculates the retinal irradiance (brightness) and

subtended angle (size divided by distance) of the glare source. These two factors predict ocular

hazards ranging from temporary after-image to retinal burn. Minor topographic features are not

always identified in GlareGauge due to the resolution of the topographic contours from Google

Earth.

“Green” rated glare indicates a low potential for after-image, “yellow” rated glare indicates the

potential for after-image exists, and “red” rated glare indicates the potential for retinal damage.

Glare that is beyond 50 degrees from a driver’s line-of-sight does not constitute a safety hazard.7

The amount of light reflected by a solar module depends on the sunlight’s angle of incidence at

the module as illustrated in Figure 4.

Figure 4: Reflected Light and Angle of Incidence on the PV Module Illustration

6 Copyright, Sims Industries, 2015 7 SGHAT_Users_Manual_v2-F.pdf


Section 5, Glare Prediction Method

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Approximately 10 percent of sunlight is reflected from a solar module without anti-reflective

coatings on average8, which is about the same as open water9. Anti-reflection coating on the

solar module can reduce the reflection to one to two percent on average. The software models

the reflectivity for each angle of incidence based on experiments Sandia National Laboratories

performed for a variety of different module constructions10. Very little light is reflected when the

sun is nearly perpendicular to the module, but more light is reflected when the sun is at a shallow

angle to the module.

Solas uses Google maps to define the location and size of the CPV arrays, characteristics of the

CPV array, and position of observers.

5.1 Limitations of the Model This analysis aims to provide an indication of the glare that may be produced by the proposed

solar CPV array. The prediction methods employed in the analysis have uncertainty. The following

lists some of the limitations inherent in the analysis.

• The base model assumes clear skies at all times. The model does not use historical weather

pattern data. This results in a total cumulative duration of glare that is likely higher than

what will occur over the course of a year.

• Shading is not considered in the model.

• Obstructions such as foliage, structures, and hills between the arrays and observation

points are not modelled by ForgeSolar’s GlareGauge software tool.

o Separate analysis can be performed to evaluate the impact of topographical

features available in Google Earth on the predicted glare.

▪ The land surrounding the Project is flat, so topography will not likely affect

the results.

o The impact of trees and foliage is extremely variable, so it is not considered.

• Ocular and perceived hazards differ from person to person, depending on multiple

environmental, optical, and human factors.

• Changes in site and array elevation from the assumptions may change the results of the

analysis.

• The model assumes the use of conventional solar PV modules, which may have different

reflective characteristics when compared with Morgan Solar’s solar CPV modules.

• The model does not place a limit on the rotation of dual-axis trackers. Solas has manually

calibrated the results to ensure that the angle beyond 60 degrees is not permitted. Glare

results beyond 60 degrees have been removed.

8 Lasnier and Ang, 1990, Photovoltaic Engineering Handbook. Taylor & Francis, New York. 9 US EPA, 2013, AERSURFACE User’s guide, EPA-454/B-08-001. 10 Sandia National Laboratories, 2014, Solar Glare Hazard Analysis Tool (SGHAT) User’s Manual v. 2F, Appendix

E


Section 6, Analysis Results

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6 ANALYSIS RESULTS The Project does not reveal any red-grade glare.

Solas identified yellow-grade glare at the residence (OP9) northwest of the Project using the

GlareGauge model results. Solas calibrated the model results with the solar PV tracking limits of

60 degrees from horizontal. The final result indicates that glare occurrence will be eliminated at

OP9 as a result of tracker rotation being limited to 60 degrees from horizontal. Solas expects that

reflected light will therefore pass above the residence at OP9 for the associated sun elevations.


Section 7, Conclusions and Discussion

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7 CONCLUSIONS AND DISCUSSION Based on the assumptions, the results of the analysis indicate that the Project is likely free of hazards

due to glare at the observation points evaluated. Residents near the Project, drivers using

Highway 3 (Crowsnest Highway), and trains passing south of the Project will not likely experience

glare from the array based on the assumptions used in this analysis.

Based on the information associated with the geographic configuration of the solar modules, the

Project has a low potential to result in hazardous glare conditions. Changes to the Project layout

or specifications will affect the results of the analysis.

These results are based on the assumptions provided by the Client. Should any one of these

assumptions be altered over time, the results of this glare analysis are considered invalid and will

need to be revised.


Section 7, Conclusions and Discussion

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Appendix A ForgeSolar Modelling Assumptions

Axis tracking: Dual

Module material: Smooth glass with Anti-Reflective coating

Vary reflectivity with sun position? Yes

Ground elevation: 798 metres to 801 metres

Height above ground: Assessed at 1.15 metres, 2.15 metres, and 3.51 metres

Maximum Tilt Angle: 60 degrees from horizontal

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