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RISK MITIGATION AND BEST PRACTICES FOR
FINANCING A SOLAR PV PROJECT
BY: DANIEL BARANDALLA, SENIOR PM, DD SERVICES
Warsaw, 16 October 2019
UL and the UL logo are trademarks of UL LLC © 2018. Proprietary & Confidential. 1
2
100+Country locations of
UL renewable energy
customers
500+ UL Renewable
Energy Experts
Independent / Owner’s
Engineer on
450+ wind & solar projects*
*since 2012
200,000+ MWTotal renewable energy megawatts (MW) assessed
55+
ADVISED
90%of the wind and solar
industry’s top PROJECT
DEVELOPERS and
PLANT OWNERS
FORECAST PROVIDER for
72+ GWof installed renewable energy projects
Years of combined experience
in the renewable energy
industry
UL and the UL logo are trademarks of UL LLC © 2019. Proprietary & Confidential. 3
1
International Presence500+Renewable
Energy
Experts
44 Countries with
UL offices
159 UL sites
(offices, labs)
WIND SOLAR
UL DRIVES TRUST IN RENEWABLES
E-MOBILITYENERGY STORAGE
UL and the UL logo are trademarks of UL LLC © 2018. Proprietary & Confidential. 5
Project
Development
Support
Asset
ManagementGrid
SolutionsDue Diligence
& Bankability
Testing &
InspectionCertification
Cybersecurity
Software &
DataEnergy
Storage
Solutions
Research &
Advanced
Studies
GLOBAL CONTEXT SOLAR PV
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• Europe installed 11.3GW in 2018 (21% increase compared to 2017)
Last year, 22 of the 28 EU markets showed higher installation numbers than
the year before.
• Sustainable FIT free growth
• First Projects without subsidies are already connected to the Grid in EU
countries
DISTRIBUTION OF RISK ACROSS PROJECT
LIFETIME
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Stakeholder Risk
Developer/Owner/
Operator
• Meeting investor expectation
• Rising operating costs
Investor/Lenders• Inaccurate risk assessment
• Declining Cash Flow
EPC/Contractors
• Rising costs
• Project delays
• Quality of work
Insurer• Performance uncertainty
• Equipment failures and lost production
Manufacturer • Warranty
• Accurate and bankable energy
estimates
• Technology roadmap and best
practices
• Independent design verification
• Minimum contractual
requirements
• Cost projectionsUL and the UL logo are trademarks of UL LLC © 2019. Proprietary &
Confidential. 8
ON-SITE MONITORING EQUIPMENT
Typical Monitoring equipment
• Two secondary-standard pyranometers
(Kipp & Zonen, Hukseflux)
• Supporting met measurements (temp,
wind speed, etc.)
• Reference cells for soiling
• Albedometers for bifacial applications
• Heating and ventilation in cold climates
System providers
• Campbell Scientific
• NRG Systems (2016)
9
WHEN TO USE ON-SITE MONITORING
Recommended when
1. Minimal regional data is available or depending on Project size
2. Satellite models tend to have higher uncertainty (dynamic weather variability, snow
cover, areas with microclimates due to topography)
3. Low resource locations (financial margins are narrower)
4. Local off-taker requirements
5. Larger projects (50-500 MW) when financers may be more conservative with larger
investment capital.
10
MODELED SOLAR DATA
Modeled Solar Data
• Bankable from high-quality data providers
• Regional and seasonal biases still exist
Resource Uncertainty
• Uncertainty should include validation reference
uncertainty
• Monte Carlo sampling approach under predicts
inter-annual variability
• CPR TGYs are raw (scaling and rebalancing
needed)
11
VALUE OF ON-SITE MEASUREMENTS
12
ENERGY MODELING
APPROACHES
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ENERGY PRODUCTION ESTIMATES
Energy Modeling Approach
• Loss factors inputs
calibrated to plant design
and site-specific conditions.
• PVSYST used for
simulation.
• Results post-processed to
address operational and
long term loss factors.
14
ENERGY MODELING TOOLS
PVSYST
• Recognized market leader. Most common software and accepted by all banks.
• More accurate calculations due to the large amount of algorithms for each
timestep.
• Responsive technical support.
Alternate Modeling Tools
• Utility-Scale: SAM, PlantPredict, PVSol, SolarFarmer
• Residential and C&I models in web-based platforms
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DETAILED PROJECT DESIGN INTEGRATION
• Determination of exclusions
and developable area
• Project-specific optimization
and configuration details (DC-
AC ratio, pitch, tilt, etc.)
• Modelling of PV array and
inverter locations
• Detailed configuration and
layout drawings
16
STANDARD LOSS ASSUMPTIONS:
EFFECTIVE IRRADIATION
Effective irradiation losses are associated with sunlight reaching and entering the DC collector
area (i.e., the modules).
Horizon Shading
Near Shading
Incident Angle Modifier Factor (Reflection)
Environmental Loss (Soiling and Snow)
17
STANDARD LOSS ASSUMPTIONS:
PHOTOVOLTAIC CONVERSION
Photovoltaic conversion losses are associated with the PV modules’ performance, actual power
capability, and ability to convert sunlight into DC electricity.
Initial Light Induced Degradation (ILID)
Non-STC Operation (Irradiance Level and Temp)
Module Quality
Module Mismatch
18
STANDARD LOSS ASSUMPTIONS:
OPERATIONAL
Operational losses are associated with the overall system’s performance, availability, consumption,
operational strategy, and operational limitations.
Tracking System Performance
DC System Performance (Module/String Failures)
Availability of System
• Availability of AC System (Inverters and
Medium-Voltage Transformers)
• Availability of Collection, High-Voltage
Transformer, and Substation
• Availability of Utility Grid
PPA Curtailment , HVAC & Auxiliary Consumption
19
SOILING AND SNOW LOSSES
Model predicts soiling and snow loss, accounting for:
• Soil accumulation, rain event power reclamation
• Cleaning events and schedule optimization
• Snow totals at different temperatures
• Snow melting and sliding
• Model relies on TMY to predict precipitation days
20
STANDARD LOSS ASSUMPTIONS:
ANNUAL PERFORMANCE DEGRADATIONAnnual performance degradation estimates the impact of material and system degradation on
future-year energy production.
Material Degradation
System Degradation
• Inverter and Curtailment Loss Reclamation
• DC System Performance Loss Increase
• Mismatch Loss Increase
(Calculation Approach)
21
Technology Roadmap
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PV TECHNOLOGY ROADMAP
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• Crystalline Silicon
Technologies keep
dominating the Global
Market.
• Mono and poly accounted
95% of the capacity in
2017 (roughly 65% of the
installed capacity was poly
crystalline)
• Thin film represented a
5% of the technology
market share in 2017
BIFACIAL TECHNOLOGY
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• Bifacial product are mostly based on mono
PERC technologies.
• Passivated Emitter Rear Contact (PERC)
solar cell technology brings 0.5-1% higher
efficiency with little more cost for additional
production equipment.
• Manufacturing from conventional mono to
mono PERC is relatively easy and sets the
base for future bifacial technology
development.
• It is expected that 60% of crystalline silicone
modules will be bifacial by 2029.
BIFACIAL VS MONOFACIAL TECHNOLOGY
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• Conventional crystalline monofacial setup vs bifacial module setup
• Typical module layup for bifacial are based on a glass-glass structure with/without frame.
• Some suppliers are already commercializing glass-transparent tedlar modules (less
weight/easier to install)
TECHNOLOGY TRENDS
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The trend at the moment is to use half cells,
to increase module power.
By cutting a fully processed cell into two
parts, resistance losses can be reduced,
providing a power boost of about 5 to 6 W on
the module level.
Modules have better behaviour against
shading effects.
Resistance losses of solar cells are also
reduced by adding busbars. The standard at
the moment is to use 5-BB design or multi
bus bars (MBB).
Module efficiencies range 17 – 19 %Mono PERC half cut cells Mono PERC standard cells
TECHNOLOGY TRENDS
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Mono PERC products are providing
already:
• Higher product warranties;
• Better degradation warranties
(0.45 – 0.50% annual degradation
rates)
• Longer degradation warranty
terms (30 year period).
Design Verification
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CIVIL REVIEW RISKS AND RECOMMENDATIONS
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Associate Risk Mitigation and Recommendations
Incomplete Geotechnical
Investigation for Foundation
Installation
Evaluate the subsurface conditions at the proposed module locations to determine soil
engineering parameters and to develop geotechnical design requirements.
Soil characterization tests, pull out/driven test, and chemical tests.
Seismic refraction surveys, geophysical measurements, and standard penetration tests
The ultimate goal of a solar-specific geotechnical analysis is to use site research, soil
investigation and empirical load-test data to optimize the foundation for the specific site.
Bad Structural Calculations.
Structural Design Not
Performed for a Specific
Location
Proper design loads verification, considering local wind data and the loads transmitted from
the mounting system own weight. In most cases the design of a solar structure will be
governed by local wind specifications and loading.
Proper construction recommendations for areas where weak soils were identified. Also
proper treatments for frost effects like thawing cycles, snow presence, etc.
Bad Foundation Installation
Procedures
Some foundation types and geometries better suit specific soil or site conditions than
others. On smaller projects, it often makes sense to design around a single foundation type
to simplify project logistics. However, an optimized design for larger sites often eschews a
one-size-fits-all approach in favor of multiple pile profiles, embedment depths or even
foundation types.
FIELD EXAMPLES
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Limited erosion control Remediation
STRUCTURAL DESIGN CONSIDERATIONS: WIND
• ASCE-7: Minimum Design Loads and Associated Criteria for Buildings and Other Structures
• Use modules that are designed for maximum design wind loading, including extreme events such
as hurricanes
• Design structures for higher wind loading
• Deeper pilings around edges of array field
• Module connection points
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STRUCTURAL CONSIDERATIONS: COLD WEATHER
Snow loads
• Withstand weight of snow and ice
• Shorter spans, larger beams, more
support
Frost Mitigation
• Pilings deep enough with enough
mass to resist uplift from frost
• Good drainage around piers to prevent water
accumulation
• Special coatings on piers to minimize frost uplift
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STRUCTURAL CONSIDERATIONS: FOOTING
Loose Soils
• Compaction
• Mass (concrete)
• Longer piers to pass through loose soils
• Ballasted systems
Seismic loads
Hail etc.
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ASPECTS OF ELECTRICAL SYSTEM DESIGN
General Design
• 30+ year design life
• Good wire management
• Minimize line losses (AC and DC)
• Robust components
• Overdesign for conditions
• Design in accessibility to major components
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Contractual Requirements
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EPC BEST PRACTICES (1)
• Experience is everything
• Challenges with the “oversight and subcontract model”
• Short timelines
• Capability oversight
• Align Schedule across all contract requirements (very few “Full Wrap” contracts)
• Interconnection requirements
• PPA cliff dates
• Supply agreements
• O&M scope
• Regular Construction Monitoring
• Ensure all construction is inline with warranty requirements
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EPC BEST PRACTICES (2)
• Clear testing protocols
• Commissioning testing to confirm proper operation
• Performance test to validate committed energy production
• Overlap period defined between EPC and O&M provider
• Project benefits when EPC is the O&M for at least 2-3 years
• Warranties
• 1-5 years in workmanship
• Performance guarantees and LDs are key to identify and implement claims
• Challenges in defining fault (equipment, installation, design, etc.)
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O&M SCOPE OF WORK
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• Comparisons are challenging
as scope buckets vary widely
• Scheduled/PM
• 2-4 visits per year
• Lower level labor
• Unscheduled/CM
• All about response time
and qualified labor
* Source: Green Tech Media Research
O&M/AM BEST PRACTICES (1)
• Experience is everything
• Clearly defined scope of work across all contracts
• Adequate visual inspection protocol for PM visits
• Response time guarantees for downtime events
• Monitoring and data analysis
• A strong Asset Management team can offset a weaker O&M team
• Monitoring system for advanced fault detections and issue isolation
• Performance calculation equation and assumptions
• Correcting for actual environmental conditions (irradiance, soiling,
snow, temperature)
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O&M/AM BEST PRACTICES (2)
• Cost savings of using same development team for O&M and AM are often
offset by
• conflict of interest around plant performance issues
• increased vendor bankability risk
• Intelligent cleaning of modules (snow and dirt)
• Alignment between AM and O&M teams on spare part management
• Warranties
• Availability and performance guarantees are crucial to optimal yield
• Very limited beyond contract term
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INVERTER RESERVES
Inverter costs are treated differently in financial models as they are a large
capex and are highly variable.
Price * Percent replaced * # of replacements
Price:
• String is market price
~$0.07 to $0.10/W
• Central excludes
skids/pads etc.
~$0.06/W to $0.08/W
Percent replaced
• 60% of the core central
inverter is expected to
need replacement
• String inverters are
plug & play so 100% of
price
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# of replacements
• Central Inverters have
5 year warranty + 10
year life (2X)
• String inverters have
10 year warranty + 15
year life (1-2X
depending on model
length)
COMMON OPERATING ISSUES
• Modules
• Breaking (improper installation, hail, edge
cracks)
• Delamination/yellowing
• Hot Spots
• Snail trails
• Inverter
• Overheating (mfg defects or design flaws)
• Control systems not working
• Misc. Trips offline
• Trackers
• Structural failures
• Improper Stow
• Poor tracking alignment
• Shading
• Row to row (design issue)
• Poor vegetation management (in
field and off field)
• Soiling
• Infrequent washing/underestimation
of dust
• Snow fall buildup and residue
during fall-off
• Change in AR coatings over time
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THANK YOU!
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