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Huawei SUN2000 Inverter Technical Review and Comparative Study
Phase 2: Case Study Comparison
Huawei Technologies UK Co., Ltd.
November 2017 01627 - v1.2
Huawei SUN2000 Inverter Technical Review and Comparative Study
November 2017 │ 01627 - v1.2
Issue and Revision Record
Revision Date Originator Checker Approver Narrative
1.0 13/09/2017 JKH SG JH Draft
1.1 20/10/2017 JKH SG RSJA Update following client
comments
1.2 13/11/2017 MMS ## ## Final. Cover photo update
Disclaimer
This document has been prepared for the titled project or named part thereof and should not be
relied upon or used for any other project without an independent check being carried out as to its
suitability and prior written authority of RINA Consulting being obtained. RINA Consulting accepts
no responsibility or liability for the consequence of this document being used for a purpose other
than those for which it was commissioned. Any person using or relying on the document for such
other purpose will by such use or reliance be taken to confirm his agreement to indemnify RINA
Consulting for all loss or damage resulting therefrom. RINA Consulting accepts no responsibility
or liability for this document to any party other than the person by whom it was commissioned.
As provided for in RINA Consulting’s proposal, to the extent that this report is based on
information supplied by other parties, RINA Consulting accepts no liability for any loss or damage
suffered by the client, whether contractual or tortious, stemming from any conclusions based on
data supplied by parties other than RINA Consulting and used by RINA Consulting in preparing
this report.
Awards and Recognitions
RINA Consulting’s reputation as one of the world’s most experienced technical advisors has led to us working on over 30 GW of renewable energy projects world-wide and maintaining strong
long-term global relationships with major investors, lenders and developers.
Our commitment to excellence in our work has been recognised through a series of annual
awards from our foundation in 2008 to today, including recently:
For further information, visit our website www.ostenergy.com
Huawei SUN2000 Inverter Technical Review and Comparative Study
November 2017 │ 01627 - v1.2
Contents
Executive Summary .......................................................................................................................... 4
1 Introduction ................................................................................................................................ 7
2 Plant Design Comparison ......................................................................................................... 8
2.1 Key plant details .............................................................................................................. 8
2.2 System configuration ....................................................................................................... 9
2.3 Plant layout .................................................................................................................... 10
2.3.1 Huawei SUN2000 string inverter variant: low voltage design .......................... 10
2.3.2 Central inverter variant: low voltage design ...................................................... 11
3 Yield Study .............................................................................................................................. 13
3.1 Irradiation ....................................................................................................................... 13
3.2 Plant Availability ........................................................................................................... 14
3.3 PR calculation................................................................................................................ 14
3.4 PR losses ...................................................................................................................... 16
3.5 Yield estimations ........................................................................................................... 24
4 CAPEX Comparison ................................................................................................................ 26
4.1 CAPEX results ............................................................................................................... 26
5 OPEX Comparison .................................................................................................................. 28
5.1 Modelling Inputs and Assumptions ............................................................................... 28
5.1.1 O&M coverage .................................................................................................. 28
5.1.2 Modelling approach ........................................................................................... 29
5.2 Qualitative and quantitative OPEX results .................................................................... 29
5.2.1 Inverter repair expectations .............................................................................. 31
Huawei SUN2000 Inverter Technical Review and Comparative Study
November 2017 │ 01627 - v1.2 4
Executive Summary
Huawei Technologies (UK) Co., Ltd. has appointed RINA Consulting Ltd. (‘RINA’) to perform a
technical review of Huawei SUN2000 33KTL inverters and a case study comparison of one PV
plant using the Huawei inverters with the same configuration using central inverters. This report
covers the case study comparison, with the technical review in a separate report. This report,
containing the second phase of work, should be considered in its entirety and RINA does not
endorse specific statements being extracted and used for marketing purposes.
This study compares the energy yield, capital expenditure (CAPEX) and operational expenditure
(OPEX) for two variants of one PV plant design: one using Huawei SUN2000 33KTL inverters
and the other, a comparable inverter from a market-leading brand of central inverters. The PV
plant which forms the basis of comparison is the Cowdown PV plant in the UK, which has a
capacity of 39.9 MWp and was chosen by Huawei to be representative of their UK PV plants. The
first variant is the as-built design, which uses Huawei SUN2000 33KTL string inverters and a mix
of Canadian Solar and Neo Solar Power PV modules. The one modification RINA has made to
the Huawei variant is to assume Power Line Communications (PLC) were used, rather than the
standard RS-485 communications system that was actually installed. The second variant is an
equivalent configuration that uses a market-leading brand of central inverters, which was
designed by RINA. Specifically, RINA undertook a preliminary design exercise to determine a
module string configuration for the central inverter systems; assumed cable lengths and cable
cross sections for both variants that would create equivalent cable voltage drops between the two
variants; and assumed DC combiner box specifications, numbers and locations in keeping with
experience of similar projects and in order to create an equivalent design to the Huawei string
inverter variant. We note that the central inverter variant is not necessarily fully optimised.
Yield Study
Plant Performance Ratios (PRs) and energy yields have been calculated for both system design
variants.
The Huawei string inverter variant has a PR of 86.4% for the Cowdown PV plant, which is higher
than that of the central inverter variant, which has a PR of 85.6%. PV plant losses change based
on various factors, including site specific, technology and component specific characteristics and
therefore and cannot necessarily be directly extrapolated to another location or project. Loss
factors which contribute to the difference in this PR calculation are: mismatch, inverter efficiency
and MPPT performance. We note that on a PV plant with a more homogeneous design, the
mismatch loss difference between the two variants might reduce slightly. We further note that the
inverter efficiency and MPPT performance losses are manufacturer, rather than technology
specific, although the Huawei performance is at the high-end of the market.
The yield calculations give a year one specific yield of 1,026 kWh/kWp for the Huawei SUN2000-
33KTL string inverter variant and 1,017 kWh/kWp for the central inverter variant, for this specific
site.
CAPEX
The Capital Expenditure (CAPEX) costs identified in this comparison exclude costs that we would
consider to be directly comparable between the two configurations. Also excluded from the
Huawei SUN2000 Inverter Technical Review and Comparative Study
November 2017 │ 01627 - v1.2 5
CAPEX comparison are inverter and transformer costs. Inverter costs are excluded because they
are commercially sensitive and do not necessarily have a fixed price per unit. As the central
inverter comes within a power station that includes the transformer, transformer prices are also
excluded from both scenarios. Main components considered for each configuration are
summarised as:
AC and DC combiner box requirements, including monitoring equipment
Foundations for inverter and combiner boxes
AC and DC low voltage cabling requirements
The total CAPEX costs, for the components considered are:
£64.41 per kWp for the Huawei string inverter variant
£64.67 per kWp for the central inverter variant
The difference in CAPEX costs is almost negligible between the two systems. The difference
between the two systems could be greater if inverter and transformer costs were to be included
and both prices are sensitive to commercial negotiations and plant design factors. The string
inverter solution offers savings in some areas, namely: combiner boxes and by use of the PLC
system rather than a standard communications system.
OPEX
RINA’s proprietary lifecycle cost model was used to evaluate DC and AC component
repair/replacement costs which are categorised as corrective maintenance tasks and therefore
typically billed to project owners. Preventative maintenance requirements and corrective
maintenance labour costs are assumed to be included in a fixed price O&M agreement and not
considered in this OPEX calculation.
The model performs statistical failure calculations for key components and takes defect
warranties into account. The system design is a key factor in determining project-specific failure
expectations and provides a more accurate approach to cost modelling than a more simplistic
forecast on a ‘cost-per-MW’ basis.
For the purpose of the OPEX comparison, RINA consider that some plant components will vary
between the two system variants and others will be common to both. Similarly to the CAPEX
assessment, those components that are common between the two systems are excluded from
the comparative OPEX analysis. At the request of the Client we are excluding inverter and
transformer costs from the OPEX comparison, instead presenting an analysis of the qualitative
differences between the two systems.
For the Cowdown PV plant, the central inverter system has higher DC and AC component
corrective maintenance costs, with the costs per kilowatt peak over the 25-year plant lifetime
being:
£2.80 per kWp for the DC and AC component corrective maintenance costs for the Huawei
string inverter variant, excluding inverter and transformer maintenance costs
£3.77 per kWp for the DC and AC component corrective maintenance costs for the central
inverter variant, excluding inverter and transformer maintenance costs
These differences stem mainly from the assumed relative price increase of DC combiner boxes
used on the central inverter plant due to more internal components than the AC combiner boxes
used on the string inverter plant. There are also slightly more DC combiner boxes required than
Huawei SUN2000 Inverter Technical Review and Comparative Study
November 2017 │ 01627 - v1.2 6
AC combiner boxes leading to increased amount of repairs. The communications system costs
are expected to be a little lower for the Huawei PLC Smartlogger solution than the standard RS-
485 communications system, due to the additional monitoring equipment included in the DC
combiner boxes. These prices are specific to the plant design, component costs available at the
time of repair and component lifetime.
The failure profiles of both inverter technologies are presented in the body of the report, which
are indicative only and will depend on project specifics, such as the duration and specifications of
manufacturer warranty, the sub-component replacement schedules (in the case of central
inverters) and the O&M contract specifications. The lifetime of the inverters will have a large
impact on plant running costs, as it will influence how often you need to replace or repair the fleet
of inverters. As an example, the replacement ratio (number of times an inverter must be replaced
in the 25-year plant lifetime) is 1.76 when the Huawei string inverter lifetime is 12.5 years
compared with 1.20 when the inverter lifetime is 17.5 years.
Huawei SUN2000 Inverter Technical Review and Comparative Study
November 2017 │ 01627 - v1.2 7
1 Introduction
RINA Consulting Ltd. (‘RINA’) has been appointed by Huawei Technologies (UK) Co., Ltd. as
Technical Advisor (‘TA’) to perform a two-part study of Huawei string inverters, of which the
second part is a case study comparison of Huawei SUN2000 33KTL string inverters against
central inverters.
RINA Consulting is the engineering consultancy division of the RINA Group, the result of the
integration of a number of internationally respected RINA companies including OST Energy,
D’Appolonia, Edif ERA (ERA Technology), Centro Sviluppo Materiali, G.E.T., Logmarin Advisors,
Polaris, SC Sembenelli Consulting and Seatech. RINA Consulting brings together a rich heritage
of engineering consultancy expertise into one unique organisation.
Huawei is a global Information and Communications Technology (ICT) company who also
manufacture solar PV inverter products.
Huawei manufactures a range of solar PV inverters and this review focusses on the SUN2000
33KTL model, part of the second series, “V2.1” of the SUN20000 string inverter product series.
This study will compare the design of an existing PV plant (Cowdown PV plant) in the UK using
Huawei SUN2000 33KTL inverters with an equivalent configuration that uses a market-leading
brand of central inverters, which shall not be named. The study is split into two parts. The first
report (Phase 1) consists of a technical review of the Huawei inverters used on the Cowdown PV
plant. The findings of the Phase 1 technical inverter review feed into the yield study and
CAPEX/OPEX comparison, which is the subject of this second report (Phase 2). The two reports
should be considered together.
The main scope of the case study comparison is as follows:
Yield Study
– A comparison of yield analyses of each variant. Each yield analysis will be carried out
according to OST’s standard methodology with focus in the losses related with the inverter
option
Qualitative and quantitative plant comparison
– Including comment on procurement, installation, maintenance, reliability, after sales
services, replacement schedule and CAPEX/OPEX evaluation.
Our opinions are contained throughout the report and issues of most significance are discussed
in the executive summary
This report should be considered in its entirety. RINA does not endorse specific statements being
used for marketing purposes.
Huawei SUN2000 Inverter Technical Review and Comparative Study
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2 Plant Design Comparison
2.1 Key plant details
The Cowdown PV plant is a 39.9 MWdc photovoltaic power plant in the UK, which has been
constructed with 1,068 x Huawei SUN2000 33KTL string inverters. At the initial design stage, we
understand that following a design assessment the EPC contractor selected the Huawei string
inverter over a specific model of central inverter. The central inverter designs were not made
available to RINA and therefore, for the purposes of this comparison exercise, RINA has
designed an equivalent PV plant with the brand of central inverter we understand was originally
considered and rejected. The chosen inverter has a nominal AC power output of 1000 kVA,
housed in pairs within a 2000 kVA power station. RINA consider this central inverter brand to be
market-leading, but for reasons of confidentiality we have not disclosed which inverter this was
within this report.
Huawei provided various details of the as-built specifications of the plant at Cowdown. RINA used
this information to define a high level design for the central inverter plant variant. RINA designed
the central inverter variant to achieve a similar AC capacity to the Huawei string inverter variant.
The general description of the two plant variants is shown in Table 1. It should be noted that
RINA has provided a high level design for the purpose of comparison, however the central
inverter design should not be considered fully optimised, nevertheless we consider the design
adequate to highlight the differences between the using the Huawei string inverter and a central
inverter at this plant.
For both plant variants, nominal inverter capacity has been considered, although at 25°C, both
inverters can output a maximum AC power of 110% of nominal power. The nominal and
maximum power outputs are considered within the yield study. The overall DC:AC ratios for the
two plants only show minor variation, and both are within the range permitted by the
manufacturers.
Table 1: General plant details
Variant Huawei String Central
Overview
Location Cowdown, UK (51.196° N, 1.459° W)
DC capacity (Wp) 39,860,040
AC capacity (VA) (nominal) 32,040,000 32,000,000
DC:AC ratio 1.24 1.24
Site details
Site inclination Several slopes present, as per topographical map.
Near shading objects Small trees and bushes (4m to 6m) to the south of the plant
Overhead lines, with a tower height of 24m running in NE-SW
direction dividing the site in two main subarrays.
Module tables will mutually shade each other at certain times
of the day/year.
Metering point location At 33kV connection point
Huawei SUN2000 Inverter Technical Review and Comparative Study
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Variant Huawei String Central
DC specifications
PV modules 153,792 in total:
42,912 x Neo Solar Power, NSP 260 W
13,536 x Neo Solar Power, NSP 255 W
85,824 x Canadian Solar, CS 260 W
11,520 x Canadian Solar, CS 255 W
Mounting Structure System Ground mount fixed tilt
Module tilt 18 degrees
Module azimuth South
Table configuration 1 table = 24 x 6 modules in landscape
Row spacing 10 m
AC specifications
Inverters 1068 x
Huawei SUN2000 30KTL
32 x
1000 kW central inverters
Power factor Unity
2.2 System configuration
The PV modules are connected in strings (a number of panels connected in series). A number of
strings may then be connected in parallel to an inverter. String and panel arrangements are
determined by the following factors:
The maximum power point (MPP) voltage range of the inverter
The highest MPP current capacity of the inverter and
The maximum system voltage of the panels.
The string and panel arrangement in the Huawei string inverter system variant was provided by
Huawei. RINA designed an arrangement for the central inverter variant. To ensure that the plant
variants were suitably designed, the electric characteristics of the strings and array are calculated
for 55°C and -5°C module temperature, as appropriate for the climatic conditions at Cowdown,
and compared against the above parameters.
A summary of the string configuration and power ratio of the string arrangements for the string
and central inverter configurations are detailed in Table 2 and Table 3 respectively. It should be
noted that 24 PV modules per module string was found to be suitable for both string and central
inverter configurations.
Table 2: System configuration for the Huawei string inverter variant
Array size (Wp) No. of strings of 24
modules per
inverter
No. of
inverters
Power ratio
(DC:AC)
Module
11,157,120 6 298 1.248 NSP 260
3,451,680 6 94 1.224 NSP 255
22,314,240 6 596 1.248 CS 260
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Array size (Wp) No. of strings of 24
modules per
inverter
No. of
inverters
Power ratio
(DC:AC)
Module
2,937,600 6 80 1.224 CS 255
Table 3: System configuration for the central inverter variant
Array size (Wp) No. of strings of 24
modules per
inverter
No. of
inverters
Power ratio
(DC:AC)
Module
1,422,720 114 2 1.225 NSP 260
1,028,160 84 NSP 255
2,432,520 198 2 1.212 NSP 255
9,734,400 195 8 1.217 NSP 260
12,604,800 202 10 1.260 CS 260
7,600,320 203 7 1.280 CS 260
848,640 135 1 1.278 CS 260
416,160 68 CS 255
2,521,440 206 2 1.273 CS 255
The DC:AC ratio is based on the nominal inverter power, which is in line with market standard
practices.
For both system variants, the maximum voltage of the inverters were found to be compatible with
the system designs for the climatic conditions at this site.
In the central inverter variant we note that the maximum current of the strings was higher than
that of the central inverter; however we have confirmation from the central inverter manufacturer
that this is acceptable and does not breach the warranty, provided that the DC:AC ratio is not
higher than manufacturer specifications.
Due to the different brands and power classes of modules on site, two of the central inverters
must be fed by PV modules of different power classes, which creates increased electrical
mismatch in the array feeding a central inverter. The Neo Solar Power (NSP) and Canadian Solar
(CS) PV modules have very different electrical properties, so we chose to combine modules of
the same brand but different nominal power into one inverter rather than combine NSP 260 with
CS 260 modules and NSP 255 with CS 255 modules.
2.3 Plant layout
2.3.1 Huawei SUN2000 string inverter variant: low voltage design
Details of the as-built layout for the Cowdown PV plant were provided by Huawei, a section of this
being shown in Figure 1. There are six parallel strings of modules on each table, which together
feed into one Huawei SUN2000 string inverter. The string inverters are positioned such that four
inverters are clustered at the end of each group of 24 strings of modules, as shown in the red
boxes in Figure 1, and a cluster of four inverters feeds into one AC combiner box as shown in the
blue circles in Figure 1. 17 AC combiner boxes feed into each 2 MVA substation. Cable lengths
Huawei SUN2000 Inverter Technical Review and Comparative Study
November 2017 │ 01627 - v1.2 11
were assumed by RINA based upon the information provided in the Plant layout diagrams. Cable
dimensions are assumed by RINA based upon similar plants and keeping the overall cable
voltage drop similar between the two variants.
The string inverter design is summarised below:
4 Huawei SUN2000 string inverters per AC combiner box
17 AC combiner boxes per substation
DC string cable, Cu 1 x 6mm (modules to inverters): 571,200 m (= 1,142,400m for both poles)
AC combiner box cable, Al 3 x 35mm (inverters to AC combiner box): 16,320m of 35mm
cable (= 48,960m for all three phases)
AC substation cable, Al 2 conductors x 3 x 185mm (AC combiner box to substation): 13,600m
(= 81,600m for two conductors per three phases)
We are also aware that there are communications cables on the Cowdown plant. For the
purposes of this comparison, we are considering the plant as if Power Line Communications
(PLC) were employed. In this configuration, communications would be via the AC power cables,
for further details on PLC refer to Phase 1 Section 3.
Figure 1: Cowdown PV Plant Layout (section of) – Huawei string inverter variant, as built
2.3.2 Central inverter variant: low voltage design
For the central inverter variant, we assume that one 24-input DC combiner boxes will be
positioned at the same locations as an AC combiner box in the string inverter variant. The DC
combiner boxes include string-level monitoring hardware. To ensure that different module types
are not feeding into the same combiner box, this design variant needs more DC combiner boxes:
18 DC combiner boxes per 2 MVA substation rather than 17 AC combiner boxes per substation in
the string inverter variant. We assume that optimum combiner box positioning will result in the
overall impact of the extra combiner boxes on DC cable lengths being negligible, resulting in
identical DC cable lengths to the DC string cable lengths in the string inverter variant. Cable
dimensions are assumed by RINA based upon similar plants and keeping the overall cable
voltage drop similar between the two variants.
Design assumptions are summarised below:
21-24 PV module strings per DC combiner box
9 DC combiner boxes per 1 MVA central inverter
DC cable, Cu 1 x 6mm (modules to combiner box): 571,200m (= 1,142,400m for both poles)
DC inverter cable, Al 1 x 150mm (combiner box to inverter): 13,600m (= 27,200m for both
poles)
AC substation cable, Cu 2 conductors x 3 x 300mm (inverter to transformer): 960m of 300mm
cable (= 2,800m for two conductors per three phases)
6 strings
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RS-485 communications cables: 13,600m of cable
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3 Yield Study
Energy yields and plant Performance Ratios (PRs) have been calculated for both system design
variants.
There are a number of losses associated with the harvesting of sunlight for the generation of DC
power and there are further losses in the conversion of DC power from the modules to the useful
AC power that feeds to the grid, the cumulative loss of which defines the plant PR.
These specific losses are dependent on the system design and key plant components, which
were detailed in Section 2. Each individual loss has been modelled taking into account
information provided (and considered sufficient) and RINA proprietary models or experience.
Explanations for each of the losses are provided.
RINA has taken the following steps to establish the energy yield for the Project:
Acquired and analysed Global Horizontal Irradiation (GHI) data from a range of databases
Uplifted the calculated GHI profile to establish the GII as appropriate for the plant location and
module orientation
Modelled the system configuration performance ratio and resultant first year specific yield
estimate
Calculated combined uncertainties to give specific yield estimates at various probabilities of
exceedance.
Each step is described in the following sections.
3.1 Irradiation
We have taken Global Horizontal Irradiation (GHI) values from the following databases for
comparison:
Meteonorm 7.1
SolarGIS
PV GIS (CM SAF)
Helioclim 3v5
NREL CSR
A Weighted Mean (WM) value from the above data sources has been used, weighted accounting
for the number of years of data available and inversely weighted based on the spatial resolution
of each source. The weighted mean value of 1050 kWh/m2/year has been selected for the
continuation of our irradiation assessment.
GHI values have been uplifted to Global Inclined Irradiation (GII) values using the industry
standard Perez model. For the site in question, we understand module orientation to be due
south with modules tilted at 18°. We would consider that an inclined irradiation of
1,118 kWh/m2/year can legitimately be applied to the site and this figure has been carried
forward in the analysis.
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3.2 Plant Availability
The calculated PR does not include any allowance for plant or grid availability losses. Plant
availability is often linked to, and guaranteed within, the EPC and O&M contracts for the lifetime
of the project.
A central inverter failure generally results in a higher proportion of the plant being unproductive
and the failures can be more complex to repair and may require specialist labour. The increased
complexity and generation impact from a single unit outage can lead to central inverters
contributing towards a lower overall plant availability. Conversely string inverters have an
increased component count and therefore more frequent failures may be expected on-site;
typically string inverter issues can be resolved by the O&M team by replacing the string inverter
with spares stock, assuming number of failures are within expectations and spares are available.
Plant unavailability can be mitigated through the availability guarantee provided by the O&M
contractor or separate guarantees direct with the inverter supplier. RINA notes that typical
financial model assumptions for plant availability do not typically differentiate between string and
central inverter technologies.
For the Huawei string inverters, we note that string-level I-V testing can be undertaken via the
inverter equipment, which would reduce any downtime resulting from annual I-V curve checking
as part of the O&M activities. For the central inverter system, string-level I-V curve checking
would require the string’s combiner box to be disconnected. For one 24-string combiner box, as
per the Cowdown example, approximately 30 minutes would be required to test all 24 strings,
during which time the capacity of the 24 strings – ~6.2 kWp – would be lost. Assuming that
typically 5% of strings would be I-V tested annually, the Cowdown plant would experience around
7.5 hours per year in which 6.2 kWp of capacity is lost. Actual production of the combiner box
during 30 minutes might not reach 6.2 kW; however, as I-V curve checking should be undertaken
only when irradiance levels are above 600 kW/m2, a minimum of 3.7 kW of the 6.2 kW capacity
would be lost, which results in approximately 28kWh per year. Furthermore, undertaking the
testing for the central inverter solution results in additional time and materials costs for the O&M
contractor, which may be reflected in the contract price.
3.3 PR calculation
The PR calculated in this section is modelled at the export meter. The PR calculation is
undertaken based on the design and technical specifications of the plant, PVsyst modelling and
RINA proprietary tools. Where relevant, PVsyst software (v6.52) is used, calculations are
performed using hour-by-hour irradiance and ambient temperature values generated for the site.
The shading has been estimated according to the 3D model shown in Figure 2.
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Figure 2: PVsyst near shading model
The breakdown of the losses for both system variants are reported below in Table 4.
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3.4 PR losses
Table 4: Losses breakdown
Loss String Central Description Comment
Near shadings:
irradiance loss
2.5% 2.5% Loss of irradiance affecting the
modules due to obstruction of
direct sunlight from surrounding
objects. E.g. external shading from
nearby trees or large buildings, and
mutual shading from neighbouring
modules.
Modelled using PVsyst near shading engine, according to the model in
Figure 2. The following near shading objects were noted:
Small trees and bushes along the southwestern subarrays ranging
from 4m to 6m.
Overhead lines running in NE-SW direction dividing the site in two
main subarrays, with towers of height of 24m.
Row spacing of modules is 10m.
Each PV module table comprises 6 rows of modules in landscape
orientation, tilted at 18 degrees from horizontal.
Spectral losses 0.0% 0.0% This takes into account the effect of
operating at a different air mass
and solar spectrum than those at
STC.
These losses are considered to be effectively zero for crystalline
silicon modules.
Angular / IAM 2.0% 2.0% The loss due to times when the sun
is not 90° to the module. This
causes an increase in the reflection
of light from the front glass.
Modelled through the modules’ PAN files which have been modified to
match the information reported on the datasheets and laboratory
testing data where available.
Soiling 1.0% 1.0% Loss of light reaching the cells.
Over its working life the module will
collect dust, dirt, bird droppings and
vegetation on its surface.
Potential soiling loss has been estimated based on local precipitation
records. We would recommend that soiling is monitored and limited
under O&M.
Low irradiance
performance
2.2% 2.2% This loss considers the relative
efficiency of the module when
Modelled through the modules’ PAN files which have been modified to
match the information reported on the datasheets and laboratory
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Loss String Central Description Comment
operating at an irradiance level
other than STC.
testing data where available.
Light Induced
Degradation
(LID)
0.7% 0.7% This degradation causes
performance loss and occurs
during a module’s first operating hours in outdoor conditions and will
reduce the module’s performance when compared to the standard
values measured at STC.
Estimated based on the review of the available literature on LID
effects in p-type polycrystalline modules.
Module quality /
power tolerance
-1.0% -1.0% The loss / gain due to the module
power tolerance is a result of the
deviation in the average effective
module efficiency with respect to
manufacturer specifications.
Estimated based on the datasheet module tolerance information.
Module
temperature
losses
1.0% 1.0% This takes into account of the loss
when operating at a temperature
other than STC.
Modelled within PVsyst using module datasheet information and
based on ambient temperature information taken from Meteonorm 7.
Near shadings:
Electrical effect
0.5% 0.5% Loss due to the current of a string
of modules / cells being reduced to
the current in the most shaded
module / cell, this loss identifies the
electrical effect due to the near
shadings described above in the
first row of this table.
Modelled using PVsyst near shading engine, according to Figure 2
As both variants have the same PV module configuration with the
same number of modules per string, the loss arising from shading-
induced variations in current along the string is similar in both cases.
Scenarios such as passing clouds over the area of a large array or
part of an array being shaded by external objects can cause partial
shading effects, whereby some module strings are shaded and others
unshaded. If unshaded and shaded module strings are feeding into
the same MPPT input of an inverter there will be a temporary
mismatch between the parallel strings. The loss will depend on the
location, shading objects and the number of strings per MPPT input. In
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Loss String Central Description Comment
the comparison considered here, there are 2 strings per MPPT for the
Huawei string inverter and approximately 200 strings per MPPT for the
central inverter. The maximum difference between the two Cowdown
plant variants was estimated by using PVsyst to model the section of
the plant with most external shading objects around it. The electrical
shading loss was higher for the central inverter system with the
maximum loss difference between the two variants being less than
0.05%.
Mismatch 0.3% 0.6% Similar to the previous loss, this
effect takes place when combining
modules with varied characteristics,
such as variations between
allowable manufacturing
tolerances, which will again limit
the current and ultimately the
power for all the modules linked in
the string.
Mismatch arises from any source
which will cause an imbalance in
the current or voltage across the
modules. Current mismatch is more
impacting than voltage mismatch.
Sources of mismatch include
thermal gradients across modules,
uneven soiling, uneven module
degradation, mismatched modules
on a string, mismatched strings into
This loss is based on:
inverter type
DC system configuration, informed by a review of relevant literature
PV module power tolerance, informed by our experience of module
flash test data.
Current mismatch: in the two plant variants here, both inverters have
the same number of modules per string so the current mismatch along
module strings is similar in both cases.
Voltage mismatch: shading of part of an array can induce mismatch
across array sections.
In the comparison considered here, the terrain contains slopes,
resulting in different inter-row shading for different parts of the plant,
which can increase mismatch.
Partial shading events can be caused by, for example, passing clouds,
which is dependent on site location, external shading objects and
differences in inter-row shading between parts of the array, with the
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Loss String Central Description Comment
an MPPT input and partial shading.
Specifically, current mismatch
manifests as the mismatch
between modules connected in
series in a string. We note that
uneven degradation of modules
could lead to mismatch losses
increasing over time. Voltage
mismatch is the difference in
voltages across parallel strings
running into one MPPT input.
overall electrical loss dependent on the number of strings per MPPT
input.
There are 2 strings per MPPT for the Huawei string inverter and
approximately 200 strings per MPPT for the central inverter, which will
slightly increase the mismatch loss for the central inverter variant, as
taken into account in the Near shadings: Electrical effect loss, as
described in the table row, above.
Voltage drops across different lengths of cables to the combiner
box/inverter input can be a source of voltage mismatch also. We have
modelled both system variants to have the same voltage drop
between PV panels and transformers; however, due to the nature of
the string and central inverter configurations, the cable length between
the PV modules and the string inverter are shorter than the total cable
length between the PV modules and the central inverter. For this
reason, the central inverter variant has more potential for mismatch
due to voltage drops.
In addition, due to the different brands and power classes of modules
on site, two of the central inverters must be fed by strings of different
power classes. This has been taken into account and results in a
slight rise in mismatch loss for the central inverter variant.
Ohmics, DC
wiring
0.5% 1.2% Electrical loss due to the Joule
Effect proportional to the voltage
drop along the wiring between the
modules and the inverters.
A max. voltage drop of 2.5% at STC has been estimated based on
RINA’s experience for this type of project design and site conditions. As the central inverter variant has a larger volume of DC wiring, there
is more power DC wiring loss for this variant.
More detailed analysis can be applied if cable loss calculations are
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Loss String Central Description Comment
provided for review.
Inverter
efficiency
1.5% 1.7% Loss due to inverter inefficiencies
in converting DC power from the
modules to an AC power the grid
can accept.
Modelled in PVsyst based on datasheet inverter efficiency information.
We have simulated as close as possible the efficiency values reported
on the datasheets provided. The Huawei string inverter values were
validated by third party laboratory reports, with relatively high
efficiencies presented.
It is important to remember that these values are manufacturer- and
product-specific and is not purely driven by differences in string or
central inverter technology.
Under sizing of
the inverter
0.2% 0.1% This power loss is caused when
inverter power is determined by the
AC output power rating of the
inverter components rather than
available DC power at its input from
the PV system. This loss typically
occurs due to the DC field being
oversized with respect to the AC
rated output of the inverter.
Modelled in PVsyst based on module and inverter datasheet
information as well as the electrical design for the site.
The values of this loss depend on the array design and
temperature/power characteristics of the inverters, as such, it is
possible through plant design to achieve the same value for both the
cases, and is therefore not purely driven by differences in string or
central inverter technology.
MPPT
performance
0.2% 0.8% Loss due to accuracy of the
maximum power point tracking
algorithm of the inverter. As
operating conditions change, the
inverter must determine the
maximum power available from the
modules and adjusts the operating
point as required. The accuracy of
We have developed a methodology to estimate the MPPT loss, based
on climatic information for the site region, and detailed static and
dynamic MPPT inverter efficiency information provided. The Huawei
string inverter has been tested by a third party laboratory and found to
have MPPT system efficiency at the high end of the market.
For the central inverter, we have not been provided with detailed
information on the dynamic and static MPPT efficiencies. Therefore,
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Loss String Central Description Comment
this control algorithm incurs a loss.
This loss is purely related to the
ability of the inverters to track the
maximum power point as tested
according to standard EN50530,
refer to RINA Phase 1 report for
detailed Huawei test results.
Mismatch losses for the projects
are considered separately, see
above.
we have used a standard assumption for the central inverter.
It is important to remember that these values are manufacturer- and
product-specific rather than being purely driven by differences in string
or central inverter technology.
Ohmics, AC LV
wiring
0.9% 0.1% Electrical loss due to the Joule
Effect proportional to the voltage
drop along the wiring between the
inverters and the transformers.
The loss has been estimated based on RINA’s experience for this type of project design and site conditions. RINA’s has assumed a highly
efficient short run low load loss cable connection from the central
inverters to the LV:MV transformers. As the string inverter variant has
a larger volume of AC wiring, the AC wiring loss is greater for this
variant.
More detailed analysis can be applied if cable loss calculations are
provided for review.
Ohmics, AC MV
wiring
0.2% 0.2% Electrical loss due to the Joule
Effect proportional to the voltage
drop along the wiring between the
transformers and point of
connection.
Estimated based on our experience for this type of project design and
site conditions.
More detailed analysis can be applied if cable loss calculations are
provided for review.
LV-MV
transformer
1.2% 1.2% Loss due to how efficiently the
transformer is able to convert the
power from LV to MV for
compliance with the connection
Estimated based on our experience for this type of project design and
site conditions.
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Loss String Central Description Comment
characteristics of the grid.
Power factor loss 0.0% 0.0% Loss due to operating the plant at a
power factor other than unity.
For the purpose of this yield RINA has assumed a power factor of
unity at the inverter level. There is likely to be a small amount of
reactive power required to overcome the inductive losses of the
electrical transmission from the inverters to obtain unity power factor
at the connection point. We note that if a non-unity power factor were
chosen, both Huawei string inverters and the central inverter have
similar power factor capabilities.
Self-consumption 0.4% 0.4% Loss due to energy consumption
from the site deducted from the
generation, which can include fans,
heaters, air conditioning, CCTV,
lights, etc. This loss does not
account for the imported energy
when the plant is not producing
energy, i.e. self-consumption
during standby and night-time is
excluded.
Estimated based on our experience for this type of project.
This loss is also exclusive of any large on site loads.
In the two system variants examined here, we have assumed
equivalent features for the site. The central inverters used are outdoor
inverters so self-consumption is expected to be low, furthermore any
imported energy from the grid is not considered as a loss in
production.
Module
degradation
0.2% 0.2% Loss due to natural degradation of
the modules performance during its
operating life.
RINA has undertaken a literature review on module degradation, and
considers a linear annual degradation rate of 0.4% to be an
appropriate assumption for crystalline silicon modules.
For year one, we take the average degradation of 0% at the starting
point and 0.4% at the end of year 1. Therefore, for the purposes of
modelling first year PR numbers a value of 0.2% has been used.
We note that modules within a string may degrade at different rates
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Loss String Central Description Comment
around an average value so, over time, power mismatch of modules
along each module string may increase. Similarly, the overall output of
each string will change with time and might contribute to the voltage
mismatch.
PR 86.4% 85.6%
It can be seen that the string inverter variant has a higher PR than the central inverter variant for the Cowdown PV plant. PV plant losses change
based on various factors, including site specific, technology and component specific characteristics and therefore and cannot be directly extrapolated
to another location or project. For example, the mismatch loss difference between the two variants would reduce if the plant only comprised of one
type and power class of PV module, whereas in this case, the plant design favours string inverters with regards to mismatch loss. Furthermore, many
losses are manufacturer specific, for example inverter efficiency and MPPT performance. Comments on Huawei’s efficiency metrics can be found in Phase 1 Section 2.2
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3.5 Yield estimations
Specific yield is a measure of the output of a PV system per unit of installed capacity (kWh/kWp).
It is a function of the irradiance experienced by a system, and its PR. Year one specific yield
calculations for the Project are shown in Table 4 and Table 5.
Table 4: Year one energy yield for the Huawei string inverter system
PR Installed
Capacity (kWp)
Probability of
Exceedence
Spec. Yield
kWh/kWp
1st Year Production
(kWh)
86.4% 39,860.64 P50 1,026 40,892,170
P75 988 39,364,132
P90 953 37,988,850
P99 894 35,621,892
Table 5: Year one energy yield for the central inverter system variant
PR Installed
Capacity (kWp)
Probability of
Exceedence
Spec. Yield
kWh/kWp
1st Year Production
(kWh)
85.6% 39,860.64 P50 1,017 40,532,487
P75 979 39,015,424
P90 945 37,650,020
P99 886 35,300,063
The yield calculations give a year one specific yield of 1,026 kWh/kWp for the Huawei SUN2000-
33KTL string inverter and 1,017 kWh/kWp for the central inverter. It should be noted that the
energy yield calculation is site specific and cannot be directly extrapolated to another location.
Various factors will alter these yield values including choice of PV components and plant layout.
Plant and grid availability has been excluded from our year one specific yield figures in Table 4
and 5.
P75 and P90 numbers are based on the uncertainties feeding into our yield analysis, which can
be separated into three discrete parts:
Variation in year on year irradiation
Duration of forward modelling period irradiation variability
Uncertainties in the PR modelling assumptions.
The three uncertainties listed above are combined using the common standard error approach.
The overall combined uncertainty for a one year period for the two system variants are shown in
Table 6.
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Table 6: Combined uncertainties over a one year modelling time period
Uncertainty Uncertainties –
Huawei string case
study
Uncertainties –
central inverter case
study
Standard error historic irradiation uncertainty 0.8%
Standard error irradiation uncertainty over time 3.1%
Standard error PR uncertainty 4.5% 4.6%
Combined uncertainty 5.5% 5.5%
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4 CAPEX Comparison
The Capital Expenditure (CAPEX) costs identified in this report are considered to be the upfront
costs to procure, construct and commission the associated PV plant.
Many costs between the two plants will be identical, for example:
PV modules and string cabling
PV module mounting structure
High voltage components
For the purposes of this comparison, we also assume that trenching and conduits for cables will
be identical.
As the aim of the report is to compare the CAPEX costs of the two designs, RINA will only
compare costs that differ between the string and central PV plant designs and will thus exclude
the components listed above. Also excluded from the CAPEX comparison are inverter and
transformer costs. Inverter costs are excluded because they are commercially sensitive and each
piece of equipment does not necessarily have a fixed price per unit. The central inverter comes
within a power station that includes the transformer. For this reason, transformer prices are also
excluded from both scenarios.
We are aware that for the Cowdown PV plant being assessed, the communications system is a
standard RS-485 communications system. Despite this, for the purposes of this study, we will
consider the Huawei string inverter variant as having the power line communications (PLC)
system implemented as this is Huawei’s preferred solution. We are, however, aware that the PLC
might not be suitable for all designs as the length of the AC power cables must be limited
depending on the type of cable, and we are not aware of why PLC was not implemented on the
Cowdown project.
The CAPEX figures come from a variety of sources. The primary source was a price list for a
Huawei SUN2000 string inverter plant and an equivalent central inverter plant that Huawei have
stated is from an EPC contractor. RINA has not verified the provenance of the price list but did
check that the numbers used for the CAPEX comparison were in line with our general pricing
expectations. As the site details were different from the Cowdown site, e.g. the cable lengths and
size of combiner boxes, some of the prices were scaled accordingly. Prices from our sources,
were sometimes in euros and US dollars. In these cases we converted to pounds sterling using
an exchange rate correct for the time the price was quoted.
4.1 CAPEX results
The result of the CAPEX comparison for specific components is summarised in Table 7. The two
sets of CAPEX figures are based on the design assumptions stated in Section 2.3.
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Table 7: CAPEX summary for the two plant variants
Huawei string inverter variant Central inverter variant
Equipment Total cost (£) Equipment Total cost (£)
Major equipment Major equipment
AC Combiner Boxes 130,036 DC Combiner Boxes
inclusive of monitoring
hardware
429,660
Smart logger and
associated equipment.
32,000
Foundations Foundations
Inverter, combiner box and
substation foundations/piles
224,135 inverter/transformer station
and combiner box
foundations/piles
81,984
Electrical (Drop. Volt. 2.19% at STC) (cable
details found in Section 2.3)
Electrical (Drop. Volt. 2.16% at STC) (cable
details found in Section 2.3)
DC string cables (modules
inverters)
1,882,447 DC string cables (modules
combiner boxes)
1,882,447
AC LV cables (inverters
combiner boxes)
49,386 DC cables (combiner boxes
inverters)
96,761
AC LV cables (combiner
boxes substation
248,814 AC cables (inverters
transformers)
60,274
RS-485 cable for
communications
26,599
Total (£)£ £ 2,566,818 £ 2,577,725
Total (£/kWp) £64.40/kWp £64.67/kWp
Delta 0 +0.1%
Based on the assumptions made here, it can be seen that the string and central inverter variants
have negligible difference in CAPEX values, taking into account only the components listed in the
above table. It should be noted that inverter costs are excluded which form a high proportion of
project costs. We note that the key variables and cost differences between the two variants are
very sensitive to component price negotiated with suppliers, general design optimisation and
component quality and absolute prices for both variants are sensitive to fluctuations in material
prices and currency exchange rates.
The string inverter solution offers particular savings in some areas, namely:
combiner boxes: AC combiner boxes may be cheaper than DC combiner boxes as they have
fewer internal components
communications system: communication wiring is not required for PLC, resulting in costs and
installation time savings
The central inverter variant can offer savings in cabling as shorter lengths of more expensive AC
cabling are required than in the string inverter design.
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5 OPEX Comparison
A major part of the expenditure associated with the operation of a PV plant is in repair and
replacement of the failed equipment to ensure high performance and availability of plant during
operation.
Maintenance activities will depend upon several factors including the specifications of O&M
contract, any after-sales services available from component manufacturers, preventative
maintenance plans and the reliability, complexity and overall lifespan of plant components.
5.1 Modelling Inputs and Assumptions
For the purpose of predicting future operating expenditure associated with maintenance activities,
RINA has developed a comprehensive lifecycle costing model for PV plants (the ‘Model’), taking into account extensive and up-to-date failure analysis of the components used on a PV plant.
Using this Model, Corrective Maintenance (CM) costs are calculated.
The Model:
Performs statistical failure calculations for key components by considering:
– expected mean component lifetime (years)
– a standard deviation (in years) around that lifetime
– random failure rate (%)
Takes account of manufacturers defect warranties, EPC contractual warranties and any
known purchased extended warranty contracts for equipment
The OPEX Model is developed from a technical foundation applicable to PV systems worldwide
and regional financial assumptions have not been included in the Model, such as:
No inflation
No discount rates
Availability of spare parts at today’s prices
No import taxes and duties or non-typical shipping costs
5.1.1 O&M coverage
Maintenance activities can be divided in terms of preventative and corrective maintenance
components.
O&M costs are not included in the OPEX comparison however we expect the following to be
included in the O&M contract:
Preventative maintenance and consumables
Corrective maintenance:
– Equipment failure diagnosis
– Labour time required for equipment procurement and repair.
O&M costs can often be slightly higher for central inverter systems than string inverter systems,
mainly because central inverter maintenance activities can be more complex than those of string
inverters, sometimes require specific scheduled maintenance activities and require more highly
skilled technicians, who will have a higher cost of labour. Furthermore we note that the Huawei
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string inverters offer string-level I-V curve tracing and analysis, which can be done without the
need of the strings being disconnected. For the central inverter variant, the combiner box would
need to be disconnected before annual I-V curve tracing is carried out. Therefore savings may be
found with fixed price O&M contracts for string inverter sites compared with equivalent contracts
for central inverter sites. The O&M cost, and any differences to be found between string and
central inverter sites, will depend on project specifics.
We expect material costs for replacement components to be excluded from the O&M contract. As
such, RINA’S OPEX analysis considers only the replacement component costs, i.e. the
components are billed to the project owner by the O&M contractor.
5.1.2 Modelling approach
The system design is a key factor in determining project-specific failure expectations and
provides a more accurate approach to cost modelling than a more simplistic forecast on a ‘cost-per-MW’ basis.
Similarly to the CAPEX comparison above, for the purpose of the OPEX comparison, RINA
consider that some plant components will vary between the two system variants and others will
be common to both. Those components that are common between the two system variants are
excluded from the comparative OPEX analysis.
Plant components that are common to both plants are:
PV modules and string cabling
PV module mounting structure
High voltage system.
Plant components that differ between the two plants:
DC and AC cabling (excluding string cabling)
Communications systems
Inverter type
Transformer ratings are the same between the two plants; however the central inverter
solution contains the transformer within the inverter.
At the request of the Client we are excluding inverter and transformer costs from the OPEX
comparison, instead presenting an analysis of the qualitative differences between the two
systems.
5.2 Qualitative and quantitative OPEX results
The DC and AC component repair/replacement costs are shown in Figure 3. These figures are
excluding the inverter and transformer. The main reactive maintenance tasks that contribute
towards these costs are summarised below;
Central inverter:
– DC main distribution cables – insulation faults
– DC Combiner box replacement:
DC Combiner box component replacement, such as; Combiner box surge protection
DC isolators
Monitoring hardware
Fuse holders
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String inverter:
– AC LV distribution cables – insulation faults
– AC Combiner box replacements and repairs
– AC Combiner box component replacement, such as;
Combiner box AC surge protection
Circuit breakers
Smartlogger communications box replacements
We assumed a 2 year warranty for all of the above components.
Figure 3: DC and AC component corrective maintenance costs
The resulting costs per kilowatt peak over the 25-year plant lifetime, for the components analysed
are:
£2.80 per kWp for the Huawei string variant
£3.77 per kWp for the central variant.
The higher costs for the DC subsystem in the central inverter configuration are primarily the
following:
the DC combiner boxes having more internal components than the AC combiner boxes used
on the string inverter plant
the slightly greater number of DC combiner boxes than AC combiner boxes
The standard RS-485 communications system costs being a little higher than for the Huawei
PLC Smartlogger solution, which does not require an additional RS-485 cable present which
might require repair. We note, however that there is a limited track record for the Smartlogger
solution so reliability cannot be vouched for as easily as for a standard communications
system.
The costs above are specific to Cowdown PV plant and are sensitive to the following
assumptions:
Plant design: specific number of components and dimensions of cables
Cost of each component
Lifetime of components.
If the plant design is optimised, component numbers can be reduced, which may decrease plant
maintenance activities over the plant lifetime (depending on other component specifications,
0
2,000
4,000
6,000
8,000
10,000
12,000
14,000
16,000
18,000
20,000
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25
Co
st (
£)
Year
Central inverter String Inverter
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failure rates etc.). RINA has used standard cost and lifetime assumptions for the DC and AC
component OPEX analysis, with the exception of the Smartlogger, for which we have considered
the price as given by Huawei. Lifetime of components will change with each different component
brand and model and costs may be dependent on commercial factors rather than being a
standard fixed item.
5.2.1 Inverter repair expectations
Figure 4 shows the modelled failure profile for string inverters across the plant’s 25-year lifetime.
Figure 5 shows the modelled failure profile for the central inverters. These profiles were
calculated based on expected mean inverter lifetimes (or those of their components), the
standard deviation around that lifetime and a random failure rate. Whilst the products are under
manufacturer warranty, no costs are expected to be incurred by the Client. The warranty period
for both inverters is considered to be 5 years, which can be extended in both systems, typically in
5 year intervals up to 20 years. The failure profiles shown are qualitative only, with actual OPEX
costs for the inverters dependent on several commercial factors.
Figure 4: String inverter corrective maintenance cost profile at different inverter mean
lifetimes
For the string inverter, we expect some minor preventative maintenance tasks might be required,
e.g. cleaning of heat sinks, however the full unit is swapped out upon failure which falls under
corrective maintenance. Failure rate data provided by Huawei for the Phase 1 report (see Phase
1 Section 4) indicated relatively low failure rates, averaging at around 0.3% per annum. From the
various pieces of failure and reliability evidence presented by Huawei, we consider that a lifetime
in the region of 15 to 20 years could be reasonably assumed, which is greater than our standard
assumption of 12.5 years. Huawei claim that the lifetime is 25 years, however we have not seen
the calculation that demonstrates this lifetime.
As can be seen from Figure 4, the lifetime of the Huawei string inverter is a key consideration
when it comes to plant running costs. The replacement ratio (number of times an inverter must be
replaced in the 25-year plant lifetime) 1.76 when the inverter lifetime is 12.5 years compared with
1.20 when the inverter lifetime is 17.5 years. The difference between these two replacement
ratios stresses the importance of obtaining failure rate and lifetime testing data when considering
OPEX costs.
0%
2%
4%
6%
8%
10%
12%
14%
16%
18%
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25An
nu
al
cost
of
inve
rte
r re
pla
cem
en
ts
(% o
f to
tal co
st o
ve
r p
lan
t li
feti
me
)
Year
12.5 yr mean lifetime, 5 yr warranty 17.5 yr mean lifetime, 5 yr warranty
Huawei SUN2000 Inverter Technical Review and Comparative Study
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Figure 5: Central inverter corrective maintenance cost profile
The OPEX costs for the central inverter system are based on corrective maintenance, i.e.
replacement of central inverter sub-components at the time those sub-components fail. We are
aware that another common approach to central inverter maintenance is to have a refurbishment
schedule, whereby the inverter manufacturer recommends an overhaul and service including the
replacement of key components at certain intervals during the plant lifetime. Different central
inverter components have different lifetimes and thus different replacement frequencies. A
corrective maintenance cost profile of an inverter with a planned refurbishment schedule would
look different from Figure 5 and there would be more concentrated expenditure during the
planned refurbishment time.
In both cases, the total maintenance costs are sensitive to the assumed lifetime of components:
lifetime assumptions of string inverters and central inverter component replacement frequencies
have a considerable impact on the corrective maintenance expenditure for a project.
Furthermore, the duration and specifications of manufacturer warranty and after-sales packages,
the preventative maintenance plans and the O&M contract specifications will have a large impact
on the OPEX costs.
0%
2%
4%
6%
8%
10%
12%
14%
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25An
nu
al
cost
of
inve
rte
r re
pa
irs
(% o
f to
tal co
st o
ve
r p
lan
t li
feti
me
)
Year
5 yr warranty
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RINA Consulting Ltd.
2nd Floor Offices
Nile House, Nile Street
Brighton, BN1 1HW, UK
+44 (0)1273 819 429
www.rinaconsulting.org