U.S. patent application number 14/799365 was filed with the patent office on 2016-02-04 for photovoltaic systems and related techniques.
This patent application is currently assigned to Fraunhofer USA, Inc.. The applicant listed for this patent is Fraunhofer USA, Inc.. Invention is credited to Jacquie Ashmore Chakrabarty, Christian Hoepfner, Matthew Alan Kromer, Dirk E. Mahling, James R. Perkinson.
Application Number | 20160036373 14/799365 |
Document ID | / |
Family ID | 55181015 |
Filed Date | 2016-02-04 |
United States Patent
Application |
20160036373 |
Kind Code |
A1 |
Hoepfner; Christian ; et
al. |
February 4, 2016 |
PHOTOVOLTAIC SYSTEMS AND RELATED TECHNIQUES
Abstract
Photovoltaic systems and related techniques are provided. A
method for commissioning a photovoltaic (PV) system may include
obtaining data describing an arrangement of two or more components
of the PV system; performing a test of the PV system, wherein
performing the test includes determining whether the PV system
complies with at least one PV system criterion based, at least in
part, on at least a portion of the data describing the arrangement
of the two or more components of the PV system; and in response to
determining that the PV system complies with the at least one PV
system criterion, activating the PV system and/or notifying a user
of the PV system that the PV system complies with the at least one
PV system criterion. The method may further include sending
information associated with the PV system to a regulatory entity
and/or an operator of an electrical grid.
Inventors: |
Hoepfner; Christian;
(Cambridge, MA) ; Kromer; Matthew Alan;
(Arlington, MA) ; Chakrabarty; Jacquie Ashmore;
(Arlington, MA) ; Mahling; Dirk E.; (Bainbridge
Island, WA) ; Perkinson; James R.; (Winchester,
MA) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Fraunhofer USA, Inc. |
Plymouth |
MI |
US |
|
|
Assignee: |
Fraunhofer USA, Inc.
Plymouth
MI
|
Family ID: |
55181015 |
Appl. No.: |
14/799365 |
Filed: |
July 14, 2015 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
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62081440 |
Nov 18, 2014 |
|
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|
62066334 |
Oct 20, 2014 |
|
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62031840 |
Jul 31, 2014 |
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Current U.S.
Class: |
700/287 |
Current CPC
Class: |
H02S 50/10 20141201;
Y02B 10/14 20130101; Y02B 10/10 20130101; H02J 3/383 20130101; G05B
17/00 20130101; H02S 50/00 20130101; H02S 40/34 20141201; H02S
40/38 20141201; Y02E 10/563 20130101; H02S 40/36 20141201; H02J
3/381 20130101; Y02E 10/56 20130101; G05B 15/02 20130101; H02J
2300/24 20200101; Y02B 10/12 20130101; H02S 10/00 20130101 |
International
Class: |
H01L 31/04 20060101
H01L031/04; G05B 15/02 20060101 G05B015/02; H02S 50/10 20060101
H02S050/10 |
Claims
1. An apparatus for controlling operation of a photovoltaic (PV)
system to be installed at a premises, the PV system comprising a
plurality of PV panels and electrical components to connect the
plurality of PV panels and an electrical grid, the apparatus
comprising: at least one processor; at least one transceiver to
communicate from the PV system to one or more devices outside the
premises; and at least one storage medium having encoded thereon
executable instructions that, when executed by the at least one
processor, cause the at least one processor to carry out a method
comprising: in response to determining that criteria for proper
installation of a PV system have been met by the PV system,
communicating, via the at least one transceiver and to a first
computing device associated with an authority having jurisdiction
over the premises, first information indicating that the PV system
has been properly installed at the premises; communicating, via the
at least one transceiver and to a second computing device
associated with an operator of an electrical grid to which the
premises are connected, second information indicating that the PV
system has been properly installed at the premises; and in response
to receiving from the first computing device and the second
computing device authorization to activate the PV system,
configuring the PV system to permit a user to activate the PV
system and connect the PV system to the electrical grid.
2. The apparatus of claim 1, wherein communicating to the first
computing device associated with the authority having jurisdiction
comprises communicating via a server disposed outside the
premises.
3. The apparatus of claim 2, wherein communicating to the second
computing device associated with the operator of the electrical
grid comprises communicating via the server disposed outside the
premises.
4. The apparatus of claim 1, wherein: determining that the criteria
for proper installation of a PV system have been met comprises
performing, with the apparatus, one or more tests on components of
the PV system; and communicating to the first computing device
associated with the authority having jurisdiction comprises
communicating to the first computing device a specification of
components of the PV system and/or one or more results of the one
or more tests.
5. The apparatus of claim 4, wherein communicating the
specification of components of the PV system comprises
communicating the specification in a hardware description
language.
6. The apparatus of claim 1, wherein the method further comprises:
querying a server disposed outside the premises for whether the
authority having jurisdiction preliminarily authorized installation
of the PV system at the premises.
7. The apparatus of claim 6, wherein querying the server comprises
querying the server for whether the operator of the electrical grid
preliminarily authorized installation of the PV system at the
premises.
8. The apparatus of claim 1, wherein configuring the PV system to
permit the user to activate the PV system and connect the PV system
to the electrical grid comprises, in response to receiving the
authorization, prompting the user to activate the PV system.
9. The apparatus of claim 8, wherein prompting the user to activate
the PV system comprises prompting the user to perform a physical
action to connect the PV system to the electrical grid.
10. The apparatus of claim 8, wherein configuring the PV system to
permit the user to activate the PV system and connect the PV system
to the electrical grid comprises removing an impediment that
prevents the user from activating the PV system and connecting the
PV system to the electrical grid.
11. The apparatus of claim 10, wherein the method further
comprises: prior to determining that the criteria for proper
installation of a PV system have been met by the PV system,
engaging the impediment that prevents the user from activating the
PV system and connecting the PV system to the electrical grid.
12. A method of operating a photovoltaic (PV) system controller of
a PV system to be installed at a premises, the PV system comprising
a plurality of PV panels and electrical components to connect the
plurality of PV panels and an electrical grid, the method
comprising: in response to determining that criteria for proper
installation of a PV system have been met by the PV system,
communicating, via the at least one transceiver and to a first
computing device associated with an authority having jurisdiction
over the premises, first information indicating that the PV system
has been properly installed at the premises; communicating, via the
at least one transceiver and to a second computing device
associated with an operator of an electrical grid to which the
premises are connected, second information indicating that the PV
system has been properly installed at the premises; and in response
to receiving from the first computing device and the second
computing device authorization to activate the PV system,
configuring the PV system to permit a user to activate the PV
system and connect the PV system to the electrical grid.
13. A method of authorizing a photovoltaic (PV) system for
installation at a premises, the method comprising: operating at
least one processor to execute instructions that, when executed,
cause the at least one processor to carry out a set of acts, the
set of acts comprising: receiving, from the PV system, information
indicating that the PV system has determined that the PV system has
been properly installed at the premises; communicating, to at least
one computing device, at least some of the information indicating
that the PV system has determined that the PV system has been
properly installed at the premises; and in response to receiving
from the at least one first computing device authorization to
activate the PV system, communicating to the PV system that a user
is authorized to activate the PV system and connect the PV system
to the electrical grid.
14. The method of claim 13, wherein the set of acts further
comprises: in response to receiving a specification of a proposed
PV system for the premises, communicating the specification to the
at least one first computing device; and receiving from the at
least one first computing device a preliminary authorization for
the proposed PV system to be installed at the premises.
15. A method of authorizing a photovoltaic (PV) system for
installation at a premises, the method comprising: operating at
least one processor to execute instructions that, when executed,
cause the at least one processor to carry out a set of acts, the
set of acts comprising: receiving, via at least one network,
information regarding the PV system, the information describing an
arrangement of components in the PV system; and in response to
determining, based on the information, that the PV system meets at
least one criteria, transmitting via the at least one network an
authorization for the PV system.
16. The method of claim 15, wherein: receiving the information
regarding the PV system comprises receiving a specification for a
proposed PV system; and transmitting the authorization for the PV
system comprises transmitting information regarding a permit for
the PV system to be installed at the premises.
17. The method of claim 15, wherein: receiving the information
regarding the PV system comprises receiving information regarding a
PV system that has been installed at a premises; determining, based
on the information, that the PV system meets at least one criteria
comprises determining whether an inspection of the PV system is to
be waived; and transmitting the authorization for the PV system
comprises transmitting information indicating that an inspection of
the PV system has been waived.
18. The method of claim 17, wherein receiving the information
comprises receiving information indicating results of a self-test
of the PV system, conducted by the PV system, demonstrating that
the PV system has been properly installed.
19. The method of claim 18, wherein receiving the information
comprises receiving a specification of components of the PV system
and an arrangement of components in the PV system, wherein the
specification is formatted in a hardware description language.
20. The method of claim 15, wherein transmitting the authorization
for the PV system comprises transmitting an authorization, by a
local regulatory entity having jurisdiction over the premises, for
activation of the PV system.
21. The method of claim 15, wherein transmitting the authorization
for the PV system comprises transmitting an authorization, by an
operator of an electrical grid to which the premises are connected,
for activation of the PV system.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application claims priority under 35 U.S.C.
.sctn.119(e) to U.S. Provisional Application Ser. No. 62/031,840,
titled "Plug and play solar energy system" and filed on Jul. 31,
2014, U.S. Provisional Application Ser. No. 62/066,334, titled
"Photovoltaic systems and related techniques" and filed on Oct. 20,
2014, and U.S. Provisional Application Ser. No. 62/081,440, titled
"Photovoltaic systems and related techniques" and filed on Nov. 18,
2014, each of which is herein incorporated by reference in its
entirety.
BACKGROUND
[0002] 1. Technical Field
[0003] The techniques described herein relate generally to
photovoltaic (PV) systems. Some embodiments relate to apparatus and
techniques for commissioning premises PV systems.
[0004] 2. Discussion of the Related Art
[0005] Photovoltaic power systems ("PV power systems" or "PV
systems") generate electrical power by converting sunlight into
electricity. PV systems typically use photovoltaic panels ("PV
panels," "solar panels," or "panels") of photosensitive cells to
convert sunlight into direct current (DC) electricity. In a
premises PV system, the PV panels may be mounted on the ground or
on the roof of a premises (e.g., a residential house), and the
electricity generated by the PV panels may be used to provide power
to electrical loads on the premises. The amount of electrical power
generated by a premises PV system may exceed the power demands of
the premises during the day. Some premises PV systems provide power
to the electrical grid at times when the PV system generates more
power than the premises needs.
SUMMARY
[0006] In one embodiment, there is provided an apparatus for
controlling operation of a photovoltaic (PV) system to be installed
at a premises. The PV system comprises a plurality of PV panels and
electrical components to connect the plurality of PV panels and an
electrical grid. The apparatus comprises at least one processor, at
least one transceiver to communicate from the PV system to one or
more devices outside the premises, and at least one storage medium
having encoded thereon executable instructions that, when executed
by the at least one processor, cause the at least one processor to
carry out a method. The method comprises, in response to
determining that criteria for proper installation of a PV system
have been met by the PV system, communicating, via the at least one
transceiver and to a first computing device associated with an
authority having jurisdiction over the premises, first information
indicating that the PV system has been properly installed at the
premises, and communicating, via the at least one transceiver and
to a second computing device associated with an operator of an
electrical grid to which the premises are connected, second
information indicating that the PV system has been properly
installed at the premises. The method further comprises, in
response to receiving from the first computing device and the
second computing device authorization to activate the PV system,
configuring the PV system to permit a user to activate the PV
system and connect the PV system to the electrical grid.
[0007] In another embodiment, there is provided a method of
operating a photovoltaic (PV) system controller of a PV system to
be installed at a premises. The PV system comprises a plurality of
PV panels and electrical components to connect the plurality of PV
panels and an electrical grid. The method comprises, in response to
determining that criteria for proper installation of a PV system
have been met by the PV system, communicating, via the at least one
transceiver and to a first computing device associated with an
authority having jurisdiction over the premises, first information
indicating that the PV system has been properly installed at the
premises, and communicating, via the at least one transceiver and
to a second computing device associated with an operator of an
electrical grid to which the premises are connected, second
information indicating that the PV system has been properly
installed at the premises. The method further comprises, in
response to receiving from the first computing device and the
second computing device authorization to activate the PV system,
configuring the PV system to permit a user to activate the PV
system and connect the PV system to the electrical grid.
[0008] In a further embodiment, there is provided a method of
authorizing a photovoltaic (PV) system for installation at a
premises. The method comprises operating at least one processor to
execute instructions that, when executed, cause the at least one
processor to carry out a set of acts. The set of acts comprises
receiving, from the PV system, information indicating that the PV
system has determined that the PV system has been properly
installed at the premises, communicating, to at least one computing
device, at least some of the information indicating that the PV
system has determined that the PV system has been properly
installed at the premises, and, in response to receiving from the
at least one first computing device authorization to activate the
PV system, communicating to the PV system that a user is authorized
to activate the PV system and connect the PV system to the
electrical grid.
[0009] In another embodiment, there is provided a method of
authorizing a photovoltaic (PV) system for installation at a
premises. The method comprises operating at least one processor to
execute instructions that, when executed, cause the at least one
processor to carry out a set of acts. The set of acts comprises
receiving, via at least one network, information regarding the PV
system, the information describing an arrangement of components in
the PV system, and, in response to determining, based on the
information, that the PV system meets at least one criteria,
transmitting via the at least one network an authorization for the
PV system.
BRIEF DESCRIPTION OF THE DRAWINGS
[0010] Various aspects and embodiments will be described with
reference to the following figures. It should be appreciated that
the figures are not necessarily drawn to scale. Items appearing in
multiple figures are indicated by the same reference number in all
the figures in which they appear. For purposes of clarity, not
every component may be labeled in every drawing. In the
drawings:
[0011] FIG. 1 is a block diagram illustrating a premises
photovoltaic (PV) system, according to some embodiments;
[0012] FIG. 2 is a block diagram illustrating components of a
premises PV system, according to some embodiments;
[0013] FIG. 3A is a flowchart of a method for commissioning a
premises PV system, according to some embodiments;
[0014] FIGS. 3B-3D are flowcharts of methods for testing a premises
PV system for compliance with one or more applicable codes, which
may be implemented in some embodiments;
[0015] FIG. 4 is a sketch of an example of a cable assembly with
which some embodiments may operate;
[0016] FIG. 5 is a block diagram of some examples of components
that may be included in some embodiments of a cable assembly;
and
[0017] FIG. 6 is a block diagram illustrating a computing device,
according to some embodiments.
DETAILED DESCRIPTION
[0018] As the cost of purchasing and installing PV systems
continues to decrease, the use of PV systems to convert solar power
into electrical power continues to increase. However, the "soft
costs" associated with purchasing and installing PV systems remain
substantial, and are a significant barrier to more widespread
adoption of solar power technologies. These "soft costs" include
any costs other than the cost of the physical components of the PV
system (e.g., the costs of designing, installing, and commissioning
the PV system). Notable examples of soft costs include compensation
for laborers (e.g., electricians, building contractors) who install
a PV system on a premises, administrative expenses associated with
obtaining a permit from a local regulatory entity (e.g., a building
and/or electrical inspector, zoning board, or other department or
agency associated with a municipality, county, state, military
base, or other authority having jurisdiction over a premises) to
install and operate a PV system (including, for example, expenses
associated with demonstrating that the PV system is in compliance
with applicable regulations and codes), and administrative expenses
associated with obtaining approval to connect a PV system to the
electrical grid, and the costs associated with obtaining permits.
Such soft costs may account for over half the cost of purchasing
and installing a conventional residential PV system.
[0019] A typical process of purchasing and installing a
conventional residential PV system may include five phases: design,
pre-installation permitting, installation, inspection, and
connection to the electrical grid.
[0020] In the design phase for a residential system, a residential
PV system provider inspects a prospective purchaser's house to
determine how to configure a PV system to provide the house with
the desired power generation capacity (e.g., how many panels to
use, where to install the panels, etc.). The provider generates a
proposed PV system specification, which identifies the proposed PV
system's components and specifies how those components are to be
configured and interconnected.
[0021] In the pre-installation permitting phase, the specification
for the proposed PV system is submitted to a local regulatory
entity to obtain a permit for installing the PV system. The local
regulatory entity's decision to grant or deny the permit is
typically based on a determination as to whether the proposed PV
system complies with applicable codes (e.g., building safety codes,
electrical safety codes, ordinances, regulations, and/or other
applicable standards). In the United States, different authorities
(e.g., towns, cities, counties, states, military bases) may use
different codes (e.g., building codes and/or electrical codes) or
standards, such that a permit for a given PV system might be
granted in one jurisdiction and denied in another. The inventors
have observed that the uncertainty and non-uniformity of the
permitting process curb the market for residential PV systems and
the prevalence of solar power generation by increasing the expense
associated with designing a code-compliant PV system.
[0022] If the purchaser of the PV system wishes to connect the PV
system to the electrical grid (e.g., to deliver the PV system's
excess electrical power to the electrical grid), an interconnection
request may be submitted to the grid's operator (e.g., a utility
company). In some cases, the grid operator's process for evaluation
of such a request may take months to complete and/or may require
the PV system user to submit lengthy technical documentation of the
system's configuration. In some cases, the grid operator may
compensate the PV system user for the electrical power delivered to
the electrical grid, but in other cases, the PV system user may
receive no compensation.
[0023] After a permit and interconnection request for a proposed PV
system have been granted, the installation of the PV system begins.
Several tasks in the installation process may be difficult for a
typical lay person to perform, and if performed incorrectly, may
damage the structural integrity of the residence and/or create a
significant safety hazard. For example, during installation, a
metallic rack for the PV panels is typically installed on the roof
of the residence, and the PV panels are attached to the rack. If
installed improperly, the metallic rack may damage the structural
integrity of the roof or may cause the roof to leak. If not
properly grounded, the metallic rack may pose an electrical safety
hazard. As another example, simply carrying the PV panels to the
roof may be difficult for many lay persons, because the panels are
typically large (e.g., 1.6 m by 1 m) and heavy (e.g., 40 lb). As
yet another example, the components of the PV system are wired
together during installation. If wired improperly, the PV system
may not deliver power to the premises and/or may create significant
electrical safety hazards. For these reasons, many purchasers of
residential PV systems hire skilled workers to install the systems.
In some cases, a local regulatory entity may require that skilled
workers perform the installation. Accordingly, for a typical
residential PV system, the installation process may be performed by
one or more skilled workers (e.g., electricians, building
contractors) over a period of 10-20 or more labor hours, which may
be spread over a period of weeks or months to allow for multiple
inspections (e.g., on-site inspections) by local regulatory
entities.
[0024] During installation and/or after the PV system is installed,
a local regulatory entity may perform one or more on-site
inspections to determine whether the PV system has been installed
properly and is operating safely. In some jurisdictions, the local
regulatory entity's inspection process may be quite onerous. For
example, some local regulatory entities may require the PV system
user to submit lengthy technical documentation of the PV system's
installed configuration. Some local regulatory entities may charge
a substantial permitting fee to cover the cost of the inspections.
In some jurisdictions, the local regulatory entity's inspection
process may be lengthy and/or may require unexpected or costly
alterations to the PV system's configuration. The inventors have
observed that the duration, inconvenience, expense, and
inconsistency of the inspections may curb the market for
residential PV systems and the prevalence of solar power generation
by increasing the expense associated with installing a
code-compliant PV system.
[0025] The inventors have developed devices and techniques which
may be used to reduce the soft costs associated with purchasing and
installing a PV system for a premises (e.g., a residential house).
According to an aspect of the present disclosure, a "plug-and-play
PV system" for a premises is provided. In some embodiments, the
plug-and-play PV system may be installed on a premise, connected to
the electrical grid, and commissioned for operation quickly,
safely, and easily (e.g., by a lay person), and the plug-and-play
PV system's compliance with applicable codes may be demonstrated
quickly and easily.
[0026] In some embodiments, a plug-and-play PV system may be
configured to eliminate potential safety hazards associated with
conventional PV systems. Applicable codes may address such hazards
in conventional PV systems by requiring one or more inspections
(e.g., on-site inspections) to be performed and/or by requiring the
PV system to be modified to mitigate the potential safety hazard.
For example, applicable codes may require the metal racking of a
conventional PV system to be electrically grounded, to mitigate the
risk of electrocution. Connecting the metal racking to equipment
ground and demonstrating that the metal racking is connected to
equipment ground may be time-consuming and/or expensive. As another
example, in a conventional PV system, the PV panels and the metal
racking may be relatively heavy (e.g., heavier than a layer of
asphalt shingles). Applicable codes may require a structural
inspection of the structure on which the PV system is mounted, to
determine whether the structure can safely support the weight of
the PV system.
[0027] Eliminating potential safety hazards (e.g., the safety
hazards described above) may reduce the costs of installation
and/or permitting. In some embodiments, a plug-and-play PV system
may use PV panels which adhere to the roof of a residential
structure (e.g., by adhering to the roof sheathing or to a layer of
shingles), thereby eliminating the metal racking, the safety
hazards associated with the metal racking, and the components used
in conventional PV systems to mitigate those hazards. In some
embodiments, the panels may be mounted without forming penetrations
into the roof. In some embodiments, the panels may include panels
manufactured by Lumeta (e.g., the panels described in U.S. Pat. No.
7,531,740).
[0028] Applicable codes may not require a structural review when
light-weight PV panels are used. Many building codes allow
installation of a second layer of asphalt shingles on top of an
existing layer of shingles without requiring a structural
inspection, because the weight of the second layer of shingles is
not considered a safety hazard. In some embodiments, a
plug-and-play PV system may include lightweight PV panels which
weigh no more than a layer of shingles (e.g., less than or equal to
approximately two pounds per square foot). Accordingly, the
installation (e.g., adhesive mounting) of such lightweight PV
panels onto roof sheathing or onto a first layer of asphalt may not
be a structural safety hazard, and applicable codes may not require
a structural inspection when such panels are installed.
[0029] In some embodiments, a plug-and-play PV system may be
configured to facilitate the system's installation. For example
standardized cables and connectors may be used in some embodiments
to facilitate proper and safe interconnection of the components of
the PV system.
[0030] In some embodiments, a plug-and-play PV system may be
configured to facilitate demonstration of compliance with
applicable codes. For example, some embodiments of a plug-and-play
PV system may be configured to obtain data describing the system.
For example, a control device (also referred to herein as a
"controller") of the plug-and-play PV system may be configured to
probe the PV system, including by communicating with components of
the PV system, to obtain data describing components of the system,
the arrangement of the system's components, the system's operation,
and/or the system's configuration, or other data describing the PV
system. The obtained data may indicate a manner in which components
are connected or a manner in which the PV system operates. In some
such embodiments, this data may be used (e.g., by the PV system
itself, by a local regulatory entity, by the PV system's user, by
an operator of an electrical grid, and/or by any other suitable
entity) to determine whether the PV system is compliant with
applicable codes. For example, the plug-and-play PV system may
include a control device which determines whether one or more PV
system criteria are met by the PV system, including by using the
data to determine whether the system complies with the
criteria.
[0031] The PV system criteria may relate to preliminary
authorization of the PV system. For example, the PV system control
device may communicate with one or more devices outside the PV
system and the premises at which the PV system is installed to
determine whether the PV system was, before installation,
authorized to be installed. As discussed below, during a design
phase, a provider of PV systems may determine--through a process
that may be manual, automatic, or a blend of both manual and
automatic--whether a PV system may be installed at the premises and
receive preliminary authorization for the PV system to be
installed. Such a process may confirm that a PV system, or a
particular proposed PV system (e.g., one with certain size or
voltage parameters) would be, if installed properly at a premises,
compliant with local zoning regulations, local historical district
regulations, local building codes, or other regulations, and would
be compatible with the electrical grid at the premises. The
preliminary authorization may be in the form of a building permit
from a local regulatory entity, as one specific example.
Accordingly, during the process preliminary authorization(s) may be
received from a local regulatory entity and/or an operator of an
electrical grid. Information regarding the preliminary
authorizations may be stored in a data store accessible to one or
more computing devices, and the PV system control device may
communicate with the computing device(s) to determine whether the
PV system was preliminarily authorized.
[0032] The PV system criteria that may be evaluated by the PV
system control device may include safety criteria that are
applicable to PV systems and that, when met by a PV system,
indicate that a PV system has been safely installed. Some such
safety criteria may be commensurate with safety codes or other
codes to which the PV system and/or the premises are subject. The
safety codes may include electrical codes, such as the National
Electric Code (NEC) or other applicable codes. The safety criteria
may include criteria related to the components included in the
system and compatibility of the components. Such criteria related
to the components may include criteria related to whether the
arrangement of components in an installed system matches a proposed
arrangement of components for the system that was determined during
a design phase, or criteria relating to whether physical
connections between components are secure. The safety criteria may
include criteria related to whether the PV system operating
properly, including whether the system as a whole is operating
properly, whether individual components are operating properly, and
whether sets of two or more components are working properly in
aggregate.
[0033] The PV system criteria may additionally or alternatively
include local regulatory criteria that are applicable to the
premises and/or to PV systems installed at the premises, such as
local zoning or building codes. As another example, the
plug-and-play PV system may include a control device which
transmits the data and/or the control device's determinations
regarding compliance with PV system criteria to a local regulatory
entity. As another example, the plug-and-play PV system may
generate a document describing the data and/or the control device's
determinations regarding compliance with PV system criteria, and
the document may be submitted (e.g., by the system's user) to a
local regulatory entity. The local regulatory entity, including in
one or more automated processes executing on one or more computing
devices operated by the local regulatory entity, may use the
information provided by the plug-and-play PV system to grant
permits and/or to determine whether the system complies one or more
PV system criteria. In some cases, the regulatory entity's use of
the information provided by the plug-and-play PV system may
streamline the permitting process, reduce the number of
inspections, decrease the duration, invasiveness, and/or expense of
the inspections, and/or eliminate the on-site inspections
completely. In other words, some embodiments of the plug-and-play
PV system may automate at least some portions of the permitting
and/or inspection processes.
[0034] The PV system criteria may additionally or alternatively
include electrical grid criteria that are applicable to the
premises and/or to PV systems installed at the premises. The
electrical grid criteria may relate to compatibility between the PV
system and the electrical grid of the premises, such as
compatibility of components, operating ranges for voltage, current,
or other power parameters, or whether the electrical grid can
support increased load and/or power that may accompany the
connection of the PV system to the electrical grid. The electrical
grid criteria may also relate to whether the operator is willing to
reimburse an owner of the premises and/or of the PV system for
power provided to the electrical grid from the PV system. In some
embodiments, the plug-and-play PV system may be configured to
facilitate the system's interconnection to the electrical grid. For
example, some embodiments of the plug-and-play PV system may
include a control device configured to send data to an electrical
grid's operator, which may use the data, including in one or more
automated processes executing on one or more computing device
operated by the operator, to determine whether PV system criteria
are met and whether to grant or deny a request to connect to the
system to the grid. The operator, or the computing device of the
operator, may convey the determination to the PV system controller,
which may respond to the determination by either permitting the
connection to be made to the electrical grid or not. In some
embodiments, the plug-and-play PV system may automate at least some
steps of the grid interconnection process.
[0035] In some embodiments, once the PV controller (and/or other
entities) determines that the PV system complies with the PV system
criteria, the PV controller may energize the PV system and may
additionally permit a connection to be made between the PV system
and the electrical grid. In some embodiments, the PV system
controller may be configured, or may configure the PV system, not
to permit a connection to be made between the PV system and the
electrical grid until it has been determined that the PV system
criteria are met. For example, the PV controller may control a
locking mechanism that mechanically prevents a physical connection
to be made between the PV system and the electrical grid. The PV
controller, during installation of the PV system and while
determining whether the PV system criteria are met, may operate the
locking mechanism or other tool to prevent a connection. Once the
PV system controller determines that the PV system criteria are
met, the PV system controller may configure the PV system to permit
the connection, such as by controlling the locking mechanism or
other tool to enable a physical connection. In some embodiments,
the PV system may require a physical input from a user to connect
or disconnect the system, such as a push of a physical button or
movement of a physical lever. In some embodiments, such a physical
button or lever may, through a mechanism, cause a physical and
electrical connection between a connector of the PV system and a
connector of the electrical grid. In some embodiments, the locking
mechanism or other tool may interact with the physical button or
lever to prevent operation of the button/lever before the PV
controller determines that the PV system criteria are met. It
should be appreciated that embodiments are not limited to using
such a physical input from a user to cause a connection between the
PV system and the electrical grid.
[0036] In some embodiments, a plug-and-play PV system may be
configured to detect fault conditions (e.g., failure or improper
configuration of one or more components within the PV system)
during the installation process, during a commissioning process,
during the system's operation, and/or at any other suitable time.
The PV system may output information indicating the existence of
these fault conditions and may, in some embodiments, additionally
output a diagnosis of the fault condition. The output from the PV
system may be in any suitable manner, including to a user interface
of a device operated by an owner of the PV system and/or of the
premises, or to an installer of the PV system.
[0037] The inventors have additionally recognized and appreciated
the advantages of a plug-and-play style of photovoltaic system that
includes interconnecting cable assemblies that are able to monitor
and manage the photovoltaic system, including photovoltaic panels
of the system. The inventors have recognized and appreciated that
integrating monitoring and management functionality with each
individual panel may significantly increase the cost of purchasing
and servicing the panels, and implementing the functionality as
standalone devices connected to each of the panels may
significantly increase the complexity of installation and servicing
of a photovoltaic system. The inventors have recognized and
appreciated, however, that integrating such control circuits and
functionality into a cable assembly, interconnected with the panels
and a DC network via a limited set of removably coupled connectors,
may be advantageous in embodiments. Such a cable assembly may
permit the monitoring and management functionality to be included
in photovoltaic systems while increasing the ease of installation
and servicing of the systems.
[0038] In some embodiments, a "smart cable" may interconnect a set
of photovoltaic panels and a DC network of a photovoltaic system.
In addition to delivering power produced by the panels to the DC
network via a power bus, the cable assembly may include control
circuits corresponding to each of the photovoltaic panels of the
set, or to two or more panels of the set. The control circuits may
be distributed along a length of the cable assembly and integrated
with the cable assembly, and connected via a single connector (or,
in some embodiments, via multiple connectors). The control circuits
may include circuitry to monitor a performance of a panel and
convey that information to a central, premises photovoltaic system
controller and, in response to an instruction from that controller,
operate one or more switches to add or remove the panel from set.
The control circuits may additionally include circuitry to identify
a panel and/or identify whether the panel is properly connected to
the cable assembly, and convey that information to the premises
photovoltaic system controller.
[0039] The aspects and embodiments described above, as well as
additional aspects and embodiments, are described further below.
These aspects and/or embodiments may be used individually, all
together, or in any combination, as the application is not limited
in this respect.
[0040] FIG. 1 shows a premises photovoltaic (PV) system 101,
according to some embodiments. In some embodiments, premises PV
system 101 may include a set of photovoltaic and electrical
components for converting sunlight to electrical power (e.g.,
alternating current ("AC") power) and delivering the power to an
electrical system 108 of a premises and/or to an electrical grid
110.
[0041] In some embodiments, premises PV system 101 may be
electrically coupled to a premises electrical system 108, which may
comprise an electrical system for a premises (e.g., a residential
building, house, apartment, commercial building, and/or any other
suitable structure or portion thereof). Premises electrical system
108 may include a circuit breaker box ("breaker box," "fuse box,"
"AC mains panel," or "AC distribution panel") configured to receive
AC power delivered by premises PV system 101 and/or AC power
delivered by electrical grid 110.
[0042] In some embodiments, premises PV system 101 may be
electrically coupled to electrical grid 110. Electrical grid 110
may comprise a system for generating electrical power and managing
delivery of the electrical power to premises electrical system 108,
or any suitable portion of such a system. Electrical grid 110 may
be configured to receive electrical power (e.g. AC electrical
power) generated by premises PV system 101. In some embodiments,
electrical grid 110 or premises PV system 101 may include an
electrical meter for metering power provided to premises electrical
system 108 by electrical grid 110 and/or for metering power
provided to electrical grid 110 by premises PV system 101. In some
embodiments, PV system 101 may be electrically coupled to
electrical grid 110 through a grid interconnection device for
making and/or breaking an electrical connection between premises PV
system 101 and electrical grid 110. In some embodiments, the grid
interconnection device may be coupled to or integrated with the
electrical meter.
[0043] In some embodiments, premises PV system 101 may be
configured to communicate with an operator 122 of the premises, an
operator 124 of the electrical grid, and/or a regulatory entity
126. In some embodiments, premises PV system 101 may be configured
to communicate with the premises operator through a computing
device associated with the premises operator. The premises operator
may include, without limitation, an owner of the premises, a
resident of the premises, a user of the premises, an employee or
owner of a business operated on the premises, and/or any other
suitable entity. In some embodiments, premises PV system 101 may be
configured to communicate with grid operator 124 through a
computing device associated with the grid operator. The grid
operator may include, without limitation, an entity (e.g., a
utility company) that operates at least a portion of electrical
grid 110 (e.g., the portion of electrical grid 110 that provides
power to premises electrical system 108 and/or receives power from
premises PV system 101). In some embodiments, premises PV system
101 may be configured to communicate with local regulatory entity
126 through a computing device associated with the local regulatory
entity. The local regulatory entity may be an authority having
jurisdiction over the premises, such as a person, agency, or
department of a municipality, county, state, military base, and/or
other political division or geographic area where the premises are
located. The local regulatory entity may include, without
limitation, an entity that has regulatory authority over premises
PV systems, an entity that is authorized to grant permits for
installation of premises PV systems 101, and/or an entity that is
authorized to inspect premises PV systems 101.
[0044] In some embodiments, premises PV system 101 may include a DC
network 102, an inversion system 104, an AC network 106, and
premises PV system controller 120. In some embodiments, DC network
102 may include a network of electrical and photovoltaic components
for converting sunlight into DC power and managing delivery of the
DC power to an inversion system. In some embodiments, DC network
102 may provide one or more DC power signals to inversion system
104 through an electrical connection 130. In some embodiments, DC
network 102 may be configured to communicate with premises PV
system controller 120. Embodiments of DC network 102 are described
in further detail below with reference to FIG. 2.
[0045] In some embodiments, premises PV system 101 may include an
inversion system 104. In some embodiments, inversion system 104 may
be configured to receive DC power signals from DC network 102
through electrical connection 130. In some embodiments, inversion
system 104 may include one or more components for converting DC
power into AC power. In some embodiments, inversion system 104 may
provide one or more AC power signals to AC network 106 via
electrical connection 132. In some embodiments, inversion system
104 may be configured to communicate with premises PV system
controller 120. Embodiments of inversion system 104 are described
in further detail below with reference to FIG. 2.
[0046] In some embodiments, premises PV system 101 may include an
AC network 106. In some embodiments, AC network 106 may be
configured to receive one or more AC power signals from inversion
system 104 through electrical connection 132. In some embodiments,
AC network 106 may include a network of electrical components for
managing delivery of AC power to a premises electrical system 108
and/or to an electrical grid 110. In some embodiments, AC network
106 may include an electrical meter for metering power provided to
premises electrical system 108 by electrical grid 110 and/or for
metering power provided to electrical grid 110 by premises PV
system 101. In some embodiments, PV system 101 may be electrically
coupled to electrical grid 110 through a grid interconnection
device for making and/or breaking an electrical connection between
electrical grid 110 and premises PV system 101. In some
embodiments, the grid interconnection device may be coupled to or
integrated with the electrical meter. In some embodiments, AC
network 106 may be configured to communicate with premises PV
system controller 120. Embodiments of AC network 106 are described
in further detail below with reference to FIG. 2.
[0047] In some embodiments, premises PV system may include a system
controller 120. In some embodiments, system controller 120 may be
configured to communicate with DC network 102, inversion system
104, and/or AC network 106. In some embodiments, system controller
120 may communicate with components of premises PV system 101 using
any suitable communication technique (e.g., power-line
communication, wireless communication, wired communication, the
Internet, and/or a dedicated communication infrastructure). In some
embodiments, system controller 120 may be configured to control
operation of premises PV system 101, including by controlling
operation of DC network 102, inversion system 104, and/or AC
network 106. In some embodiments, controlling operation of premises
PV system 101 may comprise changing the configuration of a
component of the PV system, activating and/or deactivating a
component of the PV system, and/or any other suitable act which
controls the operation of premises PV system 101 or any portion
thereof.
[0048] In some embodiments, system controller 120 may be configured
to obtain data associated with premises PV system 101 and/or
components thereof. In some embodiments, the data may include
signal data characterizing electrical signals in premises PV system
101, including, without limitation, data indicating the power,
voltage, current, frequency, and/or any other suitable attribute of
electrical signals in the PV system. In some embodiments, the data
may include component data characterizing the operation of one or
more components of premises PV system 101, including, without
limitation, data indicating a status, an efficiency, and/or any
other suitable attribute of a PV system component. In some
embodiments, the data may include identification data identifying
one or more components of premises PV system 101. In some
embodiments, the data may include arrangement data indicating the
manner in which components of premises PV system 101 are arranged.
Data indicating an arrangement of devices may include, for example,
data indicating the topology of an electrical network formed by the
components.
[0049] In some embodiments, system controller 120 may be configured
to commission premises PV system 101. As part of commissioning the
PV system, the controller 120 may determine whether the system's
installation and/or operation complies with applicable codes,
regulations, or other criteria relating to a PV system. Such
criteria may include criteria relating to safety, zoning,
authorization, or other factors. The criteria may be included in
standardized codes like electrical codes, including the National
Electric Code (NEC). Examples of ways in which the system
controller 120 may be configured to commission the PV system 101
are discussed below in connection with FIGS. 3A-3D.
[0050] In some embodiments, system controller 120 may be configured
to communicate with premises operator 122. For example, the
controller 120 may send data and/or messages associated with the
system to premises operator 122, and/or to receive instructions
regarding the operation of the system from premises operator 122.
In some embodiments, system controller 120 may be configured to
communicate with grid operator 124. The controller 120 may
communicate with the operator 124 to send data and/or messages
associated with the system to grid operator 124, to request
connection of premises PV system 101 to electrical grid 110, to
receive authorization from grid operator 124 to make (or break) a
connection between PV system 101 and electrical grid 110, and/or to
receive instructions from grid operator 124 to activate,
deactivate, and/or reconfigure one or more components of PV system
101. In some embodiments, system controller 120 may be configured
to communicate with local regulatory entity 126, such as to apply
for a permit to install and/or operate premises PV system 101, to
register premises PV system 101, to send data relevant to the
permitting process, to receive data associated with the permitting
process, and/or to receive instructions from regulatory entity 126
to active and/or deactivate PV system 101. In some embodiments,
system controller 120 may communicate with premises operator 122,
grid operator 124, and/or local regulatory entity 126 using any
suitable communication technique or network, including, without
limitation, the Internet and/or an Advance Metering Infrastructure
(AMI) network.
[0051] In some embodiments, system controller 120 may communicate
with premises operator 122, grid operator 124, and/or local
regulatory entity 126 through one or more intermediate servers. In
some embodiments, the intermediate server(s) may be configured to
manage communication between premises PV systems and grid
operators, and/or to manage communication between premises PV
systems and local regulatory entities. The policies and procedures
of grid operators and local regulatory entities regarding
communication with PV system controllers may vary greatly among
different jurisdictions, grid operators, and/or local regulatory
entities. For example, different regulatory entities in different
jurisdictions may require that electronic requests for permits
include different sets of data. As another example, some regulatory
entities may process and grant permit requests in real-time, and
some other regulatory entities may treat electronic requests for
permits as notifications to initiate in-person, on-site
inspections. In some embodiments, the intermediate server(s) may
shield system controller 120 from the complexity of the varying
policies and procedures of the different grid operators, regulatory
entities, and/or jurisdictions by presenting a uniform interface to
system controller 120. Upon receipt of data from a controller 120
for a premises, the intermediate server may determine what data to
communicate and a format in which to communicate the data to grid
operators and/or local regulatory entities for the premises. In
some cases, the intermediate server may additionally determine
which grid operator(s) and/or local regulatory entities have
authority over the premises, such as by evaluating a location of
the premises and locations over which various operators and/or
regulatory entities have jurisdiction. Once the data, the format,
and the destination(s) are determined, the intermediate servers may
communicate data regarding a PV system, including data that was
obtained by the PV system controller 120 and communicated to the
intermediate server, to the destination(s) in the format.
[0052] In some embodiments, system controller 120 may store a
premises PV system identifier. In some embodiments, system
controller 120 may comprise a circuit configured to generate a
premises PV system identifier. In some embodiments, the premises PV
system identifier may be used to identify the premises PV system in
a database or registry of PV systems. In some embodiments, such a
database may be maintained in an off-premises server, such as one
of the intermediate servers discussed above, for the convenience of
entities seeking information about a PV system (e.g., for the
convenience of grid operators, regulatory entities, PV system
providers, PV system installers, PV system users, etc.).
[0053] In some embodiments, system controller 120 may communicate
with one or more servers (e.g., the intermediate server(s)
described above and/or other server(s)) to retrieve information
regarding PV systems and/or components of PV systems. In some
embodiments, system controller 120 may send the server(s) data
identifying a PV system (e.g., a PV system identifier or any other
suitable identifying information) and/or components of the PV
system (e.g., component serial numbers, component model numbers,
and/or any other suitable identifying information). In response,
the server(s) may send to system controller 120 data describing the
identified PV system (e.g., the PV system specification and/or any
other suitable information describing the PV system) and/or the
identified components (e.g., ratings, specifications, and/or any
other suitable information describing the components).
[0054] FIG. 2 shows components of a premises PV system 201,
according to some embodiments. In some embodiments, premises PV
system 201 includes a DC network 202, an inversion system 204, an
AC network 206, and a premises PV system controller 220.
[0055] In some embodiments, DC network 202 includes a network of
electrical and photovoltaic components for converting sunlight into
DC power and managing delivery of the DC power to an inversion
system. In some embodiments, the components of DC network 202 may
include one or more PV panels 240 for converting sunlight into DC
power. In some embodiments, a PV panel may have one or more
terminals (e.g., a positive power terminal, a negative power
terminal, and/or a communication terminal). In some embodiments,
the terminals may be disposed in or coupled to one or more adapters
(e.g., one or more plugs and/or receptacles). In some embodiments,
the components of DC network 202 may include cables and/or
interconnection circuitry (241, 242, 244) for combining the DC
power signals generated by multiple PV panels into a combined DC
power signal and delivering the combined DC power signal to
inversion system 204.
[0056] In the example of FIG. 2, DC network 202 includes eight PV
panels 240a-240h, with panels 240a-d being organized in a string
241a, and with panels 240e-h being organized in a string 241b. In
some embodiments, a string 241 may include two or more
series-connected PV panels. In some embodiments, the panels in a
string may be series-connected using a smart cable harness, as
described in further detail below. Although the example of FIG. 2
illustrates eight panels organized in two strings of four panels, a
DC network may, in some embodiments, include any suitable number of
panels arranged in any suitable configuration (e.g., a single
panel, a single string of two or more panels, two or more strings
of panels, etc.).
[0057] In some embodiments, DC network 202 may include one or more
combiner components 242. In some embodiments, a combiner component
may combine the power signals provided by multiple PV panels,
strings, and/or other combiner components to generate a combined
power signal. In the example of FIG. 2, combiner component 242
combines the power signals provided by strings 241a and 241b. In
some embodiments, a DC network 202 may include no combiner
components or any suitable number of combiner components arranged
in any suitable configuration.
[0058] In some embodiments, DC network 202 may include a DC
disconnect device ("DC disconnect") 244. In some embodiments, DC
disconnect 244 may be configured to controllably make and/or break
a connection between (1) DC network 202 and (2) inversion system
204, AC network 206, a premises electrical system, and/or an
electrical grid. In some embodiments, DC disconnect 244 may
comprise a manually operated (e.g., mechanical) switch. In some
embodiments, DC disconnect 244 may comprise an electronically
operated (e.g., remotely controlled) switch. In some embodiments,
DC disconnect 244 may use any suitable components to make and/or
break an electrical connection (e.g., a fuse, a circuit breaker, a
ground fault interrupter, etc.).
[0059] In some embodiments, DC network 202 may include a
communication interface 246. In some embodiments, communication
interface 246 may be integrated in whole or in part into other
components of DC network 202. In some embodiments, communication
interface 246 may be communicatively coupled to system controller
220. In some embodiments, communication interface 246 may receive
requests for data from system controller 220, and may respond to
such requests. In some embodiments, communication interface 246 may
receive instructions from system controller 220. In some
embodiments, communication interface 246 may relay those
instructions to suitable components of DC network 202, and/or may
perform the instructed task (e.g., activating a component of DC
network 202, deactivating a component of DC network 202, obtaining
requested data from a component of DC network 202, etc.).
[0060] FIG. 2 illustrates just one example of a DC network 202. In
some embodiments, a DC network 202 may include any suitable
arrangement of panels and/or circuitry for managing delivery of DC
power to an inversion system. In some embodiments, a DC network may
include any suitable device(s) for communicating with premises PV
system controller 220.
[0061] Inversion system 204 may be configured to convert DC
electricity into AC electricity of any suitable voltage (e.g.,
240V, 208V 3-phase) and/or frequency (e.g., 60 Hz). In some
embodiments, inversion system 204 may include one or more DC/AC
inverters 250. In some embodiments, an inverter 250 may be
configured to receive DC power signals from DC network 202 via one
or more connectors 230, to convert the DC power signals into AC
power signals, and to provide the AC power signals to AC network
206 via one or more connectors 232. An inverter 250 may be
implemented using any suitable arrangement of any suitable
components.
[0062] In the example of FIG. 2, inversion system 204 includes a
single inverter 250. In some embodiments, an inversion system 204
may include any suitable number of inverters. In some embodiments,
inversion system 204 may include one or more central inverters
and/or one or more micro-inverters. In embodiments where inversion
system 204 includes multiple inverters (e.g., multiple
micro-inverters), the outputs of the inverters may be combined
using any suitable technique (e.g., by arranging the outputs of the
inverters in parallel through a junction box or any other suitable
AC combiner component). In some embodiments, a central inverter may
be configured to receive DC power signals generated by a relatively
large number of panels (e.g., a relatively long string of panels or
multiple strings of panels). In some embodiments, a micro-inverter
may be configured to receive DC power signals generated by a
relatively small number of panels (e.g., one panel or a short
string of panels). In some embodiments, a micro-inverter may
comprise an AC Module and/or may be integrated with a PV panel.
[0063] In some embodiments, inversion system 204 may include a
communication interface 252. In some embodiments, communication
interface 252 may be integrated in whole or in part into one or
more other components of inversion system 204. In some embodiments,
communication interface 252 may be communicatively coupled to
system controller 220. In some embodiments, communication interface
252 may receive requests for data from system controller 220, and
may respond to such requests. In some embodiments, communication
interface 252 may receive instructions from system controller 220.
In some embodiments, communication interface 252 may relay those
instructions to one or more inverters 250, and/or may perform the
instructed task (e.g., activating one or more inverters 250,
deactivating one or more inverters 250, obtaining requested data
from one or more inverters 250, etc.).
[0064] AC network 206 may be configured to manage delivery of AC
power to a premises electrical system and/or to an electrical grid.
In some embodiments, AC network 206 may include an AC
interconnection device ("AC interconnect") 260. In some
embodiments, AC interconnect 260 may be configured to controllably
make and/or break a connection between (1) AC network 206 and (2) a
premises electrical system and/or an electrical grid. In some
embodiments, AC interconnect 260 may comprise a manually operated
(e.g., mechanical) switch. In some embodiments, AC interconnect 260
may comprise an electronically operated (e.g., remotely controlled)
switch. In some embodiments, AC interconnect 260 may use any
suitable components to make and/or break an electrical connection
(e.g., an AC Disconnect, one or more fuses, circuit breakers,
switches, and/or any other suitable components).
[0065] In some embodiments, AC interconnect 260 may provide over
current protection. The over current protection may be provided
using any suitable techniques and/or components, including, without
limitation, one or more ground-fault interrupter devices.
[0066] In some embodiments, AC interconnect 260 may include an
adapter for connecting AC network 206 to other components of the PV
system (e.g., to inversion system 204). In some embodiments, the
adapter may include one or more plugs and/or receptacles suitable
for mating to a corresponding adapter included in another portion
of the PV system (e.g., in inversion system 204). In some
embodiments, an electrical coupling between AC interconnect 260 and
other components of the PV system may be formed by mating the
adapter of AC interconnect 260 with the adapter included in the
other portion of the PV system. In some embodiments, AC
interconnect 260 may lock the mated adapters together in response
to a command from system controller 220.
[0067] In some embodiments, AC interconnect 260 may include an
adapter for connecting AC network 206 to a premises electrical
system. In some embodiments, the adapter may include one or more
plugs and/or receptacles suitable for mating to a corresponding
adapter included in the premises electrical system (e.g., an
adapter integrated in or coupled to the premises electrical
system's AC distribution panel). In some embodiments, an electrical
coupling between premises PV system 201 and the premises electrical
system may be formed by mating the adapter of AC interconnect 260
with the adapter of the premises electrical system. In some
embodiments, AC interconnect 260 may lock the mated adapters
together in response to a command from system controller 220.
[0068] In some embodiments, AC interconnect 260 may include an
adapter for connecting AC network 206 to an electrical grid. In
some embodiments, the adapter may include one or more plugs and/or
receptacles suitable for mating to a corresponding adapter coupled
to the electrical grid (e.g., an adapter integrated with or coupled
to the grid interconnection device). In some embodiments, an
electrical coupling between premises PV system 201 and the
electrical grid may be formed by mating the adapter of AC
interconnect 260 with the adapter of the grid interconnection
device. In some embodiments, AC interconnect 260 may lock the mated
adapters together in response to a command from system controller
220 and/or in response to a command from the grid's operator.
[0069] In some embodiments, AC network 206 may include a
communication interface 262. In some embodiments, communication
interface 262 may be integrated in whole or in part into other
components of AC network 206. In some embodiments, communication
interface 262 may be communicatively coupled to system controller
220. In some embodiments, communication interface 262 may receive
requests for data from system controller 220, and may respond to
such requests. In some embodiments, communication interface 262 may
receive instructions from system controller 220. In some
embodiments, communication interface 262 may relay those
instructions to AC disconnect 260, and/or may perform the
instructed task (e.g., activating AC disconnect 260, deactivating
AC disconnect 260, obtaining requested data from AC disconnect 260,
etc.).
[0070] In some embodiments, premises PV system 201 may include one
or more devices for storing electrical charge (e.g., batteries)
(not shown). In some embodiments, PV system 201 may include a
charge controller (not shown) for controlling the charging and
discharging of the charge-storage device(s). In some embodiments,
the charge controller may be configured to charge the
charge-storage device(s) when the system's panels produce more
electrical power than the premises electrical system demands. In
some embodiments, the charge controller may be configured to
discharge the charge-storage device(s) when the system's panels
produce less electrical power than the premises electrical system
demands. In some embodiments, charge-storage device(s) may be added
to the PV system to import electrical power into the system, and/or
removed from the PV system to export electrical power to other
premises.
[0071] According to an aspect of the present disclosure, premises
PV system 201 may include a premises PV system controller 220
configured to commission the PV system. In some embodiments, the
commissioning process may include a system identification process
and/or a system validation process.
[0072] In some embodiments, the system identification process may
include any suitable acts for identifying the components of PV
system 201 and/or the arrangement of the system's components. In
some embodiments, during the system identification process, data
indicative of some or all of the following information may be
obtained by system controller 220:
[0073] (1) serial numbers, model numbers, safety ratings (e.g.,
voltage ratings, current ratings, power ratings, etc.), and/or any
other information describing or identifying components of PV system
201 (e.g., panels, strings, combiner components, DC disconnects,
inverters, central inverters, micro-inverters, AC disconnects, a
grid interconnection device, cables, and/or any other suitable
components);
[0074] (2) the number of components in PV system 201 (e.g., the
number of PV panels, strings, combiner components, DC disconnects,
inverters, AC disconnects, cables, and/or any other suitable
components);
[0075] (3) the types (e.g., "makes" and/or "models") of components
in PV system 201 (e.g., the types of PV panels, strings, combiner
components, DC disconnects, inverters, AC disconnects, cables,
and/or any other suitable components);
[0076] (4) the arrangement of the PV system's components (e.g., the
topology of electrical couplings between the components, the number
of PV panels in a string, the positions and/or identifiers of
individual panels in a string, the number of inputs to a combiner
component, the positions and/or identifiers of inputs (e.g.,
panels, strings, and/or other combiner components) to a combiner
component; and/or
[0077] (5) any other suitable information describing and/or
identifying components of PV system 201.
[0078] In some embodiments, the-above described system
identification data may be obtained using any suitable technique,
including, but not limited to, (1) querying a component through a
corresponding communication interface and receiving, in response to
the query, the component's identification data, and/or (2) testing
a component to determine the component's electrical attributes and
identifying the component based on the determined electrical
attributes. For example, the type of cable used to connect two
components may be determined, in some embodiments, by measuring the
impedance of the cable at one or more frequencies and by comparing
the measured values to expected values for various cables. As
another example, a dedicated identification circuit may be
integrated with the cable, and the type of cable may be determined,
in some embodiments, by measuring an electrical characteristic
(e.g., impedance) of the dedicated ID circuit.
[0079] In some embodiments, the system validation process may
include any acts suitable for determining whether PV system 201
complies with the at least one PV system criterion. In some
embodiments, during the system validation process, one or more
tests may be performed to determine (1) whether individual
components comply with PV system criteria, (2) whether strings of
PV panels comply with PV system criteria, (3) whether connections
or couplings between components comply with PV system criteria,
and/or (4) whether sets of components (including, but not limited
to, the entire set of components forming the PV system) comply with
PV system criteria.
[0080] In some embodiments, tests may be performed on individual
components of PV system 201 to determine whether the individual
components comply with PV system criteria. In some embodiments,
suitable tests may include, but are not limited to, the following
tests: [0081] (1) A test to determine whether a component's type is
approved or unapproved. In some embodiments, such a test may be
performed by determining a component's type and comparing the
determined type to a set of types approved for use in PV systems by
the appropriate regulatory entity. [0082] (2) A test to determine
whether a component is rated for the conditions the component may
experience in the PV system. In some embodiments, such a test may
be performed by identifying the component or determining the
component's type, using the component's identifying information or
type to determine the component's ratings (e.g., by querying a
database of component data for rating information corresponding to
the component), and comparing the component's ratings (e.g.,
current rating, voltage rating, power rating, and/or any other
suitable rating) to the conditions the component may experience in
the PV system. [0083] (3) A test to determine whether a component
possesses a specified feature. In some embodiments, such a test may
be performed by identifying the component or determining the
component's type, and using the component's identifying information
or type to determine the component's features (e.g., by querying a
database of component data for features of the component). [0084]
(4) A test of an isolated PV panel. In some embodiments, such a
test may comprise selectively energizing the panel, such as in
isolation (e.g., with or without energizing other panels),
measuring the panel's output voltage, and comparing the panel's
output voltage to an expected value. In some embodiments, such a
test may comprise performing a voltage-current sweep of the
isolated PV panel. In some embodiments, such tests may be performed
for each of multiple PV panels in isolation, as well as for groups
of panels (e.g., all panels in a string, or all panels of the PV
system, or any other combination of panels). [0085] (5) A suitable
test to determine whether a component is grounded. [0086] (6) A
suitable test to determine whether a component is installed
correctly, or is installed incorrectly or is damaged. In some
embodiments, such a test may comprise a test to detect conductors
with damaged conductor insulation. In some embodiments, a test to
detect damaged conductor insulation may comprise applying a
high-frequency test signal to the conductor. [0087] (7) Any
suitable test to determine whether current, voltage, and/or power
limits of a component are exceeded when the PV system (or a portion
of the PV system) is energized. In some embodiments, the current,
voltage, and/or power limits for the component may be specified by
a regulatory entity and/or by the component's manufacturer. [0088]
(8) A test to determine whether a component reports that it is
operating properly. [0089] (9) Any other suitable test.
[0090] In some embodiments, tests may be performed on strings of PV
panels to determine whether the strings comply with PV system
criteria. In some embodiments, suitable tests may include, but are
not limited to, the following tests: [0091] (1) A test to determine
whether the number of panels connected in series in a string is
greater than a maximum limit or less than a minimum limit. [0092]
(2) A test to determine whether the sizes of two or more strings
are mismatched. In some embodiments, the sizes of two strings may
be mismatched if the number of panels in the first string differs
from the number of panels in the second string by more than a
specified number of panels. [0093] (3) A test to determine whether
the output voltage of a string exceeds the maximum output voltage
for a string. In some embodiments, the actual output voltage of a
string may be measured and compared to a maximum string voltage. In
some embodiments, the output voltage of a string may be determined
based on the number of panels in the string, and compared to a
maximum string voltage. [0094] (4) Any other suitable test.
[0095] In some embodiments, tests may be performed on connections
between or among components of PV system 201 to determine whether
the connections comply with PV system criteria. In some
embodiments, suitable tests may include, but are not limited to,
the following tests: [0096] (1) A test to determine whether the
ratings of components on opposite sides of a connection point match
or are compatible. In some embodiments, such a test may comprise
comparing the ratings (e.g., voltage, current, and/or power
ratings) of components at a connection point to determine whether a
signal provided by a first component to a second component at the
connection point may exceed the second component's ratings. [0097]
(2) A test to determine whether adapters used to form connections
between components are properly terminated and seated. In some
embodiments, such a test may comprise determining the status of a
last-make, first-break pin of an adapter used to form the
connection. In some embodiments, such a test may comprise
determining whether components connected downstream from the
connection point are functioning properly. [0098] (3) Any other
suitable test.
[0099] In some embodiments, tests may be performed on a set of
components (including, but not limited to, the entire set of
components forming the PV system) to determine whether the set of
components complies with PV system criteria. In some embodiments,
suitable tests may include, but are not limited to, the following
tests: [0100] (1) A test to determine whether the components are
arranged in an approved configuration. In some embodiments, such a
test may comprise comparing the arrangement of the set of
components (e.g., the arrangement of components in PV system 201)
to one or more approved PV system specifications, such as a system
specification that had been specifically proposed for the PV
system. In some embodiments, an approved PV system specification
may be generated by the designer of the PV system, by a regulatory
entity, and/or by any other suitable entity. In some embodiments,
the approved PV system specification(s) may include a customized
specification corresponding to PV system 201. In some embodiments,
the approved PV system specification(s) may include one or more
standard specifications. In some embodiments, the approved PV
system specification(s) may be stored on system controller 220, on
an intermediate server communicatively coupled to system controller
220, and/or in any other suitable location. [0101] (2) A test to
determine whether one or more components of the PV system are
properly grounded. For example, a test may be performed to
determine whether compliance with PV system criteria requires a
particular component to be grounded, and/or a test to determine
whether a particular component includes a grounding conductor.
[0102] (3) A test to determine whether the voltages, currents, and
power levels provided to inversion system 204 and provided by
inversion system 204 are within specified ranges. [0103] (4) A test
to determine whether the voltage and frequency of electricity
received from the utility grid are within specified ranges. [0104]
(5) A test to determine whether the voltage, currents, power
levels, and frequencies of electrical signals provided to AC
network 206 and/or provided by AC network 206 are within specified
ranges. [0105] (6) A test to determine whether any DC voltage is
present in DC network 202 when all panels 240 are deactivated.
[0106] (7) Any other suitable test.
[0107] In cases where PV system 201 is successfully commissioned,
system controller 220 may, in some embodiments, activate PV system
201 and/or send a message to a user of PV system 201 indicating
that the system is commissioned and ready for operation. In some
embodiments, system controller 220 may not permit the activated PV
system 201 to be connected to a premises electrical system or to an
electrical grid until the system is successfully commissioned.
[0108] In cases where system controller 220 is not successfully
commissioned, system controller 220 may, in some embodiments, (1)
display a warning or send a warning message to a user of the PV
system and/or to a regulatory entity, (2) hobble the PV system
(e.g., de-energize the portion of the system that failed to satisfy
a PV system criterion, but activate other portions of the system),
and/or (3) deactivate the system.
[0109] In some embodiments, PV system controller 220 may be
configured to facilitate permitting and/or inspection of the PV
system. For example, the system controller may, in some
embodiments, send at least a portion of the data obtained during
the commissioning process to the appropriate regulatory entity. In
some embodiments, the system controller may generate a document
including at least a portion of the data obtained during the
commissioning process, and a user of the PV system may submit the
document to the appropriate regulatory entity. As discussed above,
to submit the document to the regulatory entity (including to
determine the appropriate entity), the controller 220 may
communicate data about the PV system to an intermediate server,
which may select which data to communicate to a regulatory entity
and/or a format in which to communicate that data.
[0110] In some embodiments, PV system controller 220 may be
configured to facilitate connection of the PV system to an
electrical grid. For example, the system controller may, in some
embodiments, send at least a portion of the data obtained during
the commissioning process to the grid's operator. In some
embodiments, the system controller may generate a document
including at least a portion of the data obtained during the
commissioning process, and a user of the PV system may submit the
document to the grid's operator. In some embodiments, the system
controller may send power generation information to the grid's
operator, including, without limitation, the PV system's power
rating (e.g., power generation capacity), the PV system's address
(e.g., the address of the premises on which the PV system is
located and/or to which the PV system provides electrical power),
an account number corresponding to a customer of the electrical
grid at the PV system's address, information describing the PV
system's inversion system (e.g., the make(s) and model(s) of the
system's inverter(s)), and/or data which the grid operator may use
to remotely control (e.g., deactivate) one or more components of
the PV system (e.g., the grid interconnection device). Such data
may include, in some embodiments, data required by California's
Rule 21.
[0111] In some embodiments, AC network 206 may include an adapter
(e.g., a plug and/or receptacle) for connecting the PV system to a
grid interconnection device suitable for connecting the PV system
to the electrical grid. In some embodiments, the grid
interconnection device may be provided by the grid operator. In
some embodiments, the grid interconnection device may be integrated
with or included in AC network 206, integrated with the electrical
meter, attached to the electrical meter, and/or electrically
coupled to the electrical meter. In some embodiments, the grid
interconnection device may comprise a meter collar attached to the
electrical meter. In some embodiments, the grid interconnection
device may be located adjacent to the electrical meter and
electrically coupled to the electrical meter. In some embodiments,
the grid interconnection device may include an adapter (e.g., a
receptacle and/or a plug) suitable for connecting to a
corresponding adapter of the AC network. In some embodiments, the
grid operator may send commands to the grid interconnection device
to make or break a connection between the PV system and the
electrical grid (e.g., in response to receiving data from system
controller 220 indicating that the commissioning of the PV system
succeeded or failed).
[0112] In some embodiments, after PV system has been commissioned
and activated, system controller 220 may monitor the PV system's
operation for faults. In some embodiments, the system controller
may monitor the PV system for faults by periodically or
intermittently performing some or all of the tests performed during
commissioning. In cases where a fault is detected, the system
controller may, in some embodiments, (1) display a warning or send
a warning message to a user of the PV system and/or to a regulatory
entity, (2) hobble the PV system (e.g., de-energize the portion of
the system that failed to satisfy a PV system criterion, but
activate other portions of the system), and/or (3) deactivate the
system.
[0113] FIG. 3A shows a method 300 for commissioning a premises PV
system, according to some embodiments. In some embodiments, method
300 may be performed by a system controller 220. In step 302, data
describing an arrangement of two or more components of the PV
system is obtained. In some embodiments, obtaining the data
describing the arrangement of the two or more components of the PV
system may comprise receiving data identifying the two or more
components of the PV system. In some embodiments, obtaining the
data describing the arrangement of the two or more components of
the PV system may comprise obtaining data describing a topology of
electrical connections among the two or more components of the PV
system.
[0114] In step 304, a test of the PV system is performed.
Performing the test may include determining whether the PV system
complies with at least one PV system criterion based, at least in
part, on at least a portion of the data describing the arrangement
of the two or more components of the PV system. In some
embodiments, determining whether the PV system complies with at
least one PV system criterion comprises comparing the arrangement
of the two or more components of the PV system to an arrangement of
components in a PV system specification, and determining whether
the arrangement of the two or more components of the PV system
matches the arrangement of components in the PV system
specification. In some embodiments, determining whether the PV
system complies with at least one PV system criterion comprises
determining whether connections between a plurality of components
of the PV system comply with the at least one PV system
criterion.
[0115] In step 306, in response to determining that the PV system
complies with the at least one PV system criterion, the PV system
may be activated, and/or a user of the PV system may be notified
that the PV system complies with the at least one PV system
criterion. In some embodiments, method 300 may further comprise
sending, to a regulatory entity, at least a portion of the data
describing the arrangement of two or more components of the PV
system and/or data indicating whether the PV system complies with
the at least one PV system criterion. In some embodiments, method
300 may further comprise sending, to an operator of an electrical
grid, at least a portion of the data describing the arrangement of
two or more components of the PV system and/or data indicating
whether the PV system complies with the at least one PV system
criterion. In some embodiments, the method may further comprise
sending power generation information to the grid's operator,
including, without limitation, the PV system's power rating (e.g.,
power generation capacity), the PV system's address (e.g., the
address of the premises on which the PV system is located and/or to
which the PV system provides electrical power), an account number
corresponding to a customer of the electrical grid at the PV
system's address, information describing the PV system's inversion
system (e.g., the make(s) and model(s) of the system's
inverter(s)), and/or data which the grid operator may use to
remotely control (e.g., deactivate) one or more components of the
PV system (e.g., the grid interconnection device). Such data may
include, in some embodiments, data required by California's Rule
21. It should be appreciated from the foregoing that embodiments
are not limited to interconnecting a premises PV system in any
particular manner. PV panels may be interconnected to one another
and to other components of a DC network and/or AC network in any
suitable manner.
[0116] FIG. 3B illustrates another example of a method that may be
used for commissioning a PV system at a premises, including for
proposing a PV system to be installed at the premises. Prior to the
start of the process 310 of FIG. 3B, an owner or operator of a
premises may request information regarding a PV system for
installation at the premises, such as by indicating a willingness
to purchase or requesting a proposal, or by purchasing a system. In
response to the indication from the owner/operator of the premises,
the process 310 may be performed to commission a PV system at the
premises. In some embodiments, the process 310 of FIG. 3B may be
carried out by a commissioning facility executing on a server
disposed outside of a premises, which may act as an "intermediate
server" as discussed above in connection with FIGS. 1-2. The
commissioning facility may be a set of executable instructions
stored in a storage medium accessible to the server, such as
integrated with the server, and executed by one or more
processor(s) or other control circuit(s) of the server. The
commissioning facility may therefore form an entirety of or a
portion of a software application, in some embodiments. In other
embodiments, the process 310 may be performed by a premises PV
system controller, acting without an intermediate server, or by any
other suitable device or entity.
[0117] The process 310 begins in block 312, in which the
commissioning facility confirms eligibility of the premises for a
plug-and-play PV system. Confirming the eligibility of the premises
for the PV system may include determining whether an operator of an
electrical grid to which the premises is connected, and/or a local
regulatory entity, permits PV system to be installed at the
premises, or if there are certain criteria that PV systems must
meet to be permitted.
[0118] For example, a grid operator and/or a local entity may ban
PV systems in their jurisdiction, or may ban PV systems in certain
areas of the jurisdiction. For example, if a grid operator is aware
that a portion of an electrical grid is old or otherwise may not
support a load imposed by PV systems in that area, the grid
operator may prohibit PV systems at the premises. As another
example, if the premises is located in a historically-significant
area, the local regulatory authority may prohibit PV systems to
preserve a historic character of the area. Grid operators and/or
local regulatory entities may have any number of other
considerations regarding prohibiting PV systems in their
jurisdiction or in certain areas of their jurisdiction. Rather than
banning PV systems, in some embodiments the grid operator and/or
the regulatory entity may impose requirements on PV systems, in
terms of criteria the PV systems must meet to be approved. For
example, a local regulatory entity may impose a limit on the size
or placement of PV systems, and a grid operator may impose a limit
on an operating voltage and/or current of PV systems.
[0119] In addition, in block 312, the commissioning system may
determine whether the grid operator and/or the local regulatory
entity permit plug-and-play PV systems of the type as described
herein, including whether the operator and/or entity permit a
plug-and-play technique for commissioning as described herein.
[0120] Accordingly, in block 312 the commissioning facility
determines, based at least on a location of the premises, whether
plug-and-play PV systems are permitted by the grid operator and/or
local regulatory entity. In some embodiments, the commissioning
facility may make the determination based on a data store of
information regarding grid operators, regulatory entities, and
areas.
[0121] If the commissioning facility determines that the premises
is not eligible for a PV system, or is not eligible for a
plug-and-play PV system, then the commissioning facility may output
information indicating that the premises is not eligible. This
information may be presented to the owner/operator of the premises
in any suitable manner, as embodiments are not limited in this
respect.
[0122] If, however, the commissioning facility determines that the
premises is eligible, or that there are criteria that PV systems
must meet, then the approval and/or criteria may be output to the
owner/operator, to a vendor or other distributor of PV systems, or
to any other party. Upon receipt of the approval and/or the
criteria, the recipient of the information may design and propose a
PV system for the premises, such as one that satisfies the criteria
(if applicable).
[0123] In block 314, the commissioning facility on the server
receives a specification of the proposed PV system for the
premises. The specification may include information on components
of the proposed system and connections between the components
(including a topology of the system), and may include information
on operating parameters of the system such as proposed voltages
and/or currents. The specification may include information on a
placement of the proposed system on the premises. The specification
may be formatted in any suitable manner, as embodiments are not
limited in this respect. In some embodiments, the specification may
be formatted according to a hardware description language or may be
translated into a hardware description language by the
commissioning facility. Following receipt of the specification in
block 314, the commissioning facility stores the specification in a
data store and forwards the specification to a local regulatory
entity and/or a grid operator to receive preliminary approval of
the proposed PV system. The commissioning facility may, as
discussed above, convey the specification to computing devices
associated with the local regulatory entity and grid operator or
may convey the specification in any other manner (e.g., on paper).
In some embodiments, the commissioning facility may use the
specification of the proposed PV system to complete one or more
forms that is/are used by the local regulatory entity and/or grid
operator, such as by electronically inserting information into a
template and creating an electronic document, such as a document in
the Portable Document Format (PDF) or other format. In cases in
which the commissioning facility creates such a form, the form may
be communicated to the local regulatory entity and/or grid
operator.
[0124] In some embodiments, the computing devices of the local
regulatory entity and/or grid operator may execute facilities to
evaluate the specification of the proposed PV system and determine
whether preliminary approval is to be granted. The facilities may
form a portion of or an entirety of a software application for
execution on those devices. Such a facility may, in the case that
criteria apply (as discussed in connection with block 312) to PV
systems for the premises, determine whether the specification meets
the criteria. The facility may make any suitable determinations,
either automatically and/or through user input, and may respond to
the commissioning facility with either a grant of preliminary
approval for the proposed PV system or a disapproval. In the case
of a disapproval, the response may indicate the basis for the
disapproval.
[0125] Upon receipt of the response, in the case of a disapproval,
the commissioning facility may provide the disapproval to the
entity that proposed the PV system in block 314 (e.g., the
owner/operator of the premises, or a vendor or distributor of PV
systems). If a basis for disapproval was provided, the
commissioning facility may also provide the basis. In some case,
the specification of the proposed PV system may be revised in view
of the basis for the disapproval, and re-submitted to the
commissioning facility. In this case, the process 310 would return
to block 314.
[0126] If, however, the commissioning facility receives in block
316 an approval from the local regulatory entity and/or grid
operator, then the facility may store the preliminary approvals in
a data store. In addition, the commissioning facility may inform
the entity that proposed the PV system in block 314 (e.g., the
owner/operator of the premises, or a vendor or distributor of PV
systems) of the approval.
[0127] At this stage (separate from the process 310), payment may
be collected from the owner/operator for the PV system as proposed
and components of the PV system may be provided to (e.g., shipped
to) the entity that will be installing the PV system, which may be
the owner/operator of the premises, the vendor, another contractor,
or any other suitable party. The installer may then install the PV
system by assembling the pieces at the position identified in the
proposal for the PV system. Once the installer has assembled the PV
system, the installer turns on the PV system, which may include
powering on the PV system controller. At initial turn-on, the PV
system controller may be configured (and other components of the PV
system may be configured) to maintain the PV system in a low-power,
idle mode, while the PV controller and the commissioning facility
determine whether the PV system was properly installed by the
installer.
[0128] Once turned on, the PV system controller may communicate
with the commissioning facility that is executing on the server.
The communication from the PV system controller may use any
suitable communication mechanism, including an Internet connection
already existing at the premises (e.g., via a wireless local area
network (WLAN) installed at the premises or other connection), a
wireless wide-area network (WWAN) connection such as a cellular
connection, an AMI connection, or any other suitable connection, as
embodiments are not limited in this respect.
[0129] The commissioning facility, in block 318, detects these
communications from the PV system controller and thereby detects
installation of the PV system. The commissioning facility may then
interact with the PV system to confirm that the PV system has been
properly installed, including by receiving data obtained by the PV
system controller regarding the PV system, such as obtained through
probing the PV system and/or interacting with the installer. The
data received from the PV system may include a specification of the
PV system, such as a description of components of the system and/or
an arrangement of the components of the PV system. The description
may, in some embodiments, be in a hardware description language.
The data received from the PV system may additionally include
information on connections of the PV system, operating parameters
of the PV system, or any other information obtained by the PV
system that describes an installation of the PV system. In some
embodiments, photographs of the PV system as installed may be
received.
[0130] In block 320, the commissioning facility, based on these
communications with the PV system controller and the information
received from the PV system controller, determines whether the PV
system is properly installed. If it is determined that the PV
system is not properly installed, the commissioning facility may
store this information and may additionally communicate this to the
installer (via the PV system controller) and/or to an
owner/operator of the premises, to a vendor of the PV system, or to
any other party. In the case that the PV system is not properly
installed, the commissioning facility may provide information
indicating how it was determined that the PV system is not properly
installed, such as information identifying what has been
incorrectly installed or how to remedy the incorrect
installation.
[0131] If, however, the commissioning facility determines, based on
the information from the PV system controller, that the PV system
is correctly installed, then in block 322 the commissioning
facility communicates with the local regulatory authority and/or
the grid operator to receive authorization to activate the PV
system. The communication to the local regulatory entity and the
grid operator, in accordance with techniques discussed herein, may
replace some or all of the on-site inspections that may be done by
the regulatory entity and/or grid operator. For example, by
informing the regulatory entity and the grid operator that the PV
system, which was previously proposed to them in block 314 and for
which preliminary authorization was received in block 316, has been
installed in a correct manner. In accordance with techniques
described herein, including techniques described below in
connection with FIGS. 3C-3D, the PV system controller may have
determined that the PV system has been installed in a safe manner,
including an electrically safe manner. The local regulatory entity
and/or the grid operator may, in this case, forego an on-site
inspection or forego some of the on-site inspections.
[0132] The communication to the local regulatory entity and/or grid
operator may include communicating data received from the PV
system, including data describing the PV system. For example, a
description of an arrangement of components in the PV system may be
provided, such as a description in a hardware description language.
Photographs of the PV system as installed may also be provided. In
some embodiments, the commissioning facility may use data received
from the PV system to complete one or more forms that is/are used
by the local regulatory entity and/or grid operator, such as by
electronically inserting information into a template and creating
an electronic document, such as a document in the Portable Document
Format (PDF) or other format. In cases in which the commissioning
facility creates such a form, the form may be communicated to the
local regulatory entity and/or grid operator.
[0133] As in blocks 314, 316, in block 322 the commissioning
facility may in some embodiments communicate to facilities
executing on devices associated with the local regulatory entity
and/or grid operator. Those facilities, upon receipt of the
information from the commissioning facility, may analyze the
information regarding the PV system in a manner that is partially
or fully automatic, or fully manual, and may return to the
commissioning facility a response. The response may indicate
whether the regulatory entity and/or the grid operator has approved
the PV system for activation, has disapproved the PV system for
activation, or will conduct an on-site inspection. In the case that
the regulatory entity and/or the grid operator has disapproved
activation, or indicated that an on-site inspection will occur, the
result may be communicated to the installer, the owner/operator of
the premises, the vendor of the PV system, or any other party.
[0134] If, however, the regulatory entity and/or the grid operator
has approved activation of the PV system, this may be communicated
to the PV system controller in block 324. In response, the PV
system controller may activate the PV system, or may configure the
PV system to be activated (including by removing any impediments to
activation, such as the locking mechanisms discussed above) and
prompting an installer to activate the PV system. Activation may
include connecting the PV system to the electrical grid. Once the
PV system is activated and is connected to the electrical grid, the
process 310 ends.
[0135] Following the process 310, the PV system may function to
generate electricity based on solar energy, and may provide that
electricity to the premises and/or to the electrical grid.
[0136] The process 310 of FIG. 3B discussed commissioning of a PV
system from the perspective of a facility executing on a server
that may be located remote from the PV system and from the premises
at which the PV system is installed. FIGS. 3C and 3D illustrate
examples of process that may be implemented by a PV system
controller to determine whether a PV system is properly
installed.
[0137] Prior to the start of the process 340 of FIG. 3C, an
installer may install a PV system at a premises, including by
assembling and interconnecting components of the system. The
installer may then power-on the PV system, such as by operating a
power switch of the PV system or the PV system controller, or
connecting the PV system controller to power. Upon start-up, the PV
system and/or PV system controller may be configured to maintain
the PV system in an idle state in which the PV panels and other
components of the PV system are not energized or are kept in a
low-power state, as opposed to a full operational state or a power
level corresponding to full operational state.
[0138] The process 340 may be implemented by a controller facility
executed by the PV system controller of the PV system. The
controller facility may be a set of executable instructions stored
in a storage medium accessible to the PV system controller, such as
integrated with the controller, and executed by one or more
processor(s) or other control circuit(s) of the controller. The
commissioning facility may therefore form an entirety of or a
portion of a software application, in some embodiments.
[0139] The process 340 begins in block 342, in which the PV system
controller communicates with a commissioning facility of a server
(e.g., the commissioning facility discussed above in connection
with FIG. 3B) to determine whether preliminary authorization was
received for a PV system to be installed at the premises. The PV
system controller may provide information, such as a location of
the premises or a location of the PV system, or an identifier for
the PV system such as a serial number, to the commissioning
facility of the server. In response, the commissioning facility may
determine whether preliminary authorization was received for a PV
system at the premises and provide a response to the PV system
indicating such.
[0140] The response from the commissioning facility may also, in
some embodiments, include information about the authorized PV
system (if the PV system was authorized). For example, a
specification for the proposed PV system may be provided,
indicating a correct (as proposed and authorized) listing of
components of the PV system and arrangement of those components.
The specification that is provided in the response may be the same
specification received by the commissioning facility, such as the
one described above in connection with block 314 of FIG. 3B.
Accordingly, in some embodiments, the specification may be set
forth in a hardware description language.
[0141] If the response from the commissioning facility of the
server indicates that the PV system was not authorized, then the PV
system controller may suspend operation of the PV system and output
a message to an installer, and/or to an owner/operator of the
premises, that the PV system is not authorized. The message may be
output in any suitable manner, including via a user interface of
the PV system controller and/or via a message transmitted, via a
computer communication network, to another computing device at the
premises, such as a computing device (e.g., mobile device, like a
tablet or mobile phone) disposed at the premises.
[0142] If, however, the response from the commissioning facility of
the server indicates that the PV system was authorized, then in
block 344 the controller facility may begin obtaining information
on the PV system as installed. In block 344, the controller
facility may determine information on components of the PV system,
such as information identifying all or some of the components that
are included in the PV system. Information on an arrangement of
components in the system may also be obtained, which may indicate
connections between the components. In block 346, the controller
facility may obtain information on the state of the connections
between the components, such as information indicating whether the
connections are secure. A secure connection may be one that is full
and proper, both mechanically and electrically, rather than one
that is loose or otherwise not fully correct. In block 346, the
controller facility may also determine information on the
functioning of at least some of the components of the PV system and
determine whether the components are functioning properly.
[0143] As discussed above, the controller facility may obtain the
information in blocks 344, 346 through communicating to components
of the PV system and/or through operating the components of the PV
system. Examples of ways in which the controller facility may
obtain this information are described in detail below in connection
with FIG. 3D.
[0144] In block 348, based on the obtained information, the
controller facility may determine whether the PV system was
properly installed. In particular, the controller facility may
compare the obtained information to applicable codes or other
criteria to determine whether the criteria are met. When the
criteria are met, the controller determines that the PV system has
been properly installed.
[0145] The applicable codes may include any suitable set of codes
that may be used to determine whether a PV system is properly
installed.
[0146] For example, the controller facility may evaluate electrical
codes, such as the National Electric Code (NEC). In some
embodiments, each of the requirements of the NEC may be expressed
in a hardware description language or other structured format, and
the controller facility may determine whether each of those
requirements is met. The controller facility may determine, for
some of the requirements, whether the requirements are met by
evaluating information obtained from the PV system, such as by
evaluating information on the functioning of components or
connections between components. The controller facility may
determine, for some of the components, whether the requirements are
met by evaluating information identifying some of the components.
For example, if a requirement is known to be met by a component, by
identifying that the component is included in the PV system, the
controller facility may conclude that the requirement is met by the
presence of that particular component in the PV system.
[0147] As another example, the applicable codes may include codes
that regulate which types of PV systems are permitted to be
installed at the premises. For example, as discussed above, a local
regulatory entity and/or a grid operator may regulate the types of
PV systems in an area, such as the size of PV systems or operating
power parameters of a PV system. The controller facility may
therefore compare components of the PV system or other information
about the PV system to these criteria to determine whether the
criteria are met.
[0148] As a further example, the controller facility may compare
information regarding the PV system as installed, such as an
arrangement of components in the system and operating parameters of
the system, to a specification of the PV system that was proposed
to be installed. As discussed above, a commissioning facility at a
server may transmit the specification for the proposed system to
the controller facility. The controller facility may compare
information on the PV system that has been determined by the
controller facility to the specification to determine that the PV
system as installed matches the specification. For example, the
controller facility may determine that a topology of the installed
system matches a proposed topology, or that components included in
the installed system match proposed components. As another example,
the controller facility may determine that operating parameters of
the installed system, such as an operating voltage or current,
matches operating parameters of a proposed system.
[0149] Any suitable criteria may be considered by the controller
facility in block 348, to determine (without the necessity of an
on-site inspection by a local regulatory entity or a grid operator)
whether a PV system is properly installed and should be authorized.
A result of the comparison may then be provided by the controller
facility to a commissioning facility on a server. The result may,
in some cases, be accompanied by information obtained by the
controller facility and on which the result was based. As discussed
above, the commissioning facility may then provide this information
to the local regulatory entity and/or to the grid operator, to
enable those parties to provide authorization for the PV system
without the need for, or with a reduced need for, an on-site
inspection of the PV system.
[0150] Once the controller facility performs the comparison of
block 348, the process 340 ends.
[0151] While in the example of FIG. 3C, the controller facility
communicates (in block 342) to an intermediate server to determine
whether preliminary authorization was received, it should be
appreciated that embodiments are not limited to operating with an
intermediate server. For example, the controller facility may
communicate directly to devices of a local regulatory entity and/or
a grid operator, or with an installer of the PV system via a user
interface, to determine whether preliminary authorization was
received. In other embodiments, the controller facility may not
determine whether preliminary authorization was received. In some
such embodiments, the controller facility may execute a process
that begins with the processing of block 344 and does not carry out
the operations described above in connection with block 342. In
other embodiments, one or more of the exemplary actions discussed
in connection with the process 340 may be omitted.
[0152] FIG. 3D illustrates an example of a process that may be
implemented in some embodiments by a controller facility to obtain
information about a PV system as installed, to collect the types of
information described above in connection with blocks 344, 346 of
FIG. 3C. The process 360 of FIG. 3D begins in block 362, in which
the controller facility probes the PV system to determine the
components included in the PV system.
[0153] Probing the PV system in block 362 may include communicating
messages to components of the PV system requesting information
about the components. For example, the controller facility may
perform power line communication (PLC) to communicate via a power
bus or other power line to components of the PV system. As another
example, the controller facility may communicate via other
connections to components of the PV system, such as dedicated
communication lines. Each of the components, or sets of two or more
components, may be provided with a chip or other device that stores
identifying information for the component(s). The controller
facility may obtain this information through communicating to the
component(s).
[0154] In some cases, identifying one component may assist the
controller facility with identifying one or more other components.
For example, based on information on compatibility of components,
the controller facility may conclude based on the presence of one
component that another component must necessarily be or are likely
to be present. These other components may be components that are
required to be included in a PV system including one component, or
that are complementary with one component, and are thus likely to
be included when the one component is identified. As a specific
example, the controller facility may determine through probing that
one type of PV panel is included in the PV system, and the
controller facility may have access to information indicating that
this type of PV panel has a proprietary connector (e.g., a terminal
having a particular shape). If the controller facility determines
that the PV panel is correctly connected to a wire/cable, and has
access to information indicating that only one wire/cable has the
complementary proprietary connector, then the controller facility
may be able to identify the wire/cable as another component of the
system. As another specific example, the controller facility may
obtain the current rating of a cable used in the system and compare
the current rating to information on other component(s) of the PV
system. For example, the controller facility may compare the
current rating to a current rating for one or more of the PV panels
installed in the system, or for all of the PV panels installed in
the system, and determine that the cable is insufficient to carry
current that is expected to be generated by the PV panel(s). Thus,
for example, the controller facility may determine, based on the
comparison, that the current rating of the cable is sufficient for
the number of PV panels installed in the PV system.
[0155] Through selectively energizing components of the PV system
and identifying those components, then identifying other components
to which those components are connected (either by querying those
components or using stored information about complementary
components), the controller facility may identify an arrangement of
components in the PV system. The information on the arrangement of
components may include information on a topology of the
components.
[0156] In block 364, the controller facility may also probe
connections between components in the PV system to determine
whether the connections are secure. In some embodiments,
connections between components may use active connectors that are
able to sense their own status, such as using pins (e.g., "last
make/first break" pins) or other structures to determine whether
the connection is complete and proper. In such cases, the
controller facility may communicate with these active connectors,
such as using PLC or another network connection, or may access
information generated by these connectors. In other embodiments,
the controller facility may probe connections using sense signals.
For example, the controller facility may apply low-power signals to
connections in the PV system and monitor how the system reacts to
the low-power signal. For example, the controller facility may
monitor impedances throughout the PV system. Impedance values may,
in some cases, indicate a connection that is not a secure
connection, such as one that is not a full and complete connection.
Similarly, the controller facility may probe whether the PV system
is properly connected to ground, by using such low-power signals to
determine whether there is a proper system ground.
[0157] In block 366, after determining in blocks 362 and 364 which
components are included in the system and confirming that the
connections are secure, the controller facility may begin switching
the PV system into full operational mode. During blocks 362 and
364, the controller facility may maintain the PV system in a
low-power state, to prevent any safety problems that may arise
through fully energizing the PV system when a component is
misconnected or otherwise incorrectly installed.
[0158] It should be appreciated that while the example of FIG. 3C
illustrated the controller facility obtaining information on the
system and, after obtaining the information, evaluating the
information with regard to criteria, in some embodiments the
obtaining of information may be interleaved with evaluation of
criteria. For example, in some embodiments, after identifying
components and an arrangement of components, the controller
facility may determine whether the components and arrangement match
the proposed specification for the PV system. If the components and
arrangements match, the controller facility may then determine
whether the connections are secure, by injecting low-power sense
signals into the PV system. If the facility determines that the
connections are secure, then the facility may begin selectively
energizing the system to a high-power state, in block 366. Through
this iterative process, safety concerns from incorrect
installations may be mitigated.
[0159] Accordingly, in block 366, the controller facility may begin
selectively energizing components of the system. For example, the
facility may energize each of the components in isolation. Upon
energizing a component, the facility may determine whether
operating parameters (e.g., voltage and current) of the panel,
based on a signal output from the panel, are within expected
ranges. The facility may also energize groups of two or more
components, such as multiple PV panels within a string or all PV
panels in a string, or all strings. By analyzing a signal output
from such a collection of components, the controller facility may
determine whether the components are interoperating correctly, and
thus whether the components are connected properly. For example,
for a string of PV panels, the controller facility may determine
whether a total voltage output from the string is within an
expected range of a sum of the voltages output from the individual
PV panels of the string.
[0160] Once the controller facility has obtained the information in
block 366, the process 360 ends.
[0161] FIGS. 4-5 illustrate an example of a cable assembly that may
be used in some embodiments to interconnect a set of multiple PV
panels and circuitry of a DC network. The cable assembly of FIGS.
4-5 may be used in some embodiments, for example, to connect a
string of PV panels (e.g., string 241a of FIG. 2) to one another
and to a DC combiner (e.g., combiner 242 of FIG. 2) of a DC
network. As should be appreciated from the foregoing and from the
discussion of the assemblies below, cable assemblies as described
in connection with FIGS. 4-5 may be advantageous in some
embodiments in which a PV system controller probes a PV system to
produce information describing a PV system.
[0162] FIG. 4 illustrates a system 400 that includes a set 402 of
PV panels, a cable assembly 404, and a DC combiner 408. The PV
panels of the set 402 may be implemented in any suitable manner,
including in accordance with examples of PV panels described above.
The DC combiner 408 may be implemented in any suitable manner,
including in accordance with examples of DC combiners discussed
above.
[0163] The cable assembly 406 interconnects the PV panels 402A,
402B, 402C and the DC combiner 408, such as by including a power
bus (discussed in more detail below in connection with FIG. 5) that
creates a series connection between the panels 402A, 402B, 402C to
the combiner 408. As illustrated in FIG. 4, the cable assembly 406
comprises multiple control circuits 406A, 406B, 406C, spaced apart
along a length of the cable assembly, that are each individually
associated with one of the panels 402A, 402B, 402C. The cable
assembly 404 further includes a cable 410 that includes the power
bus. The control circuits 406A, 406B, 406C may be integrated with
the cable 410, in that the cable assembly 404 may be constructed
and arranged such that the control circuits 406A, 406B, 406C are
not intended to be and are designed not to be separated from the
cable 410 during normal usage of the cable assembly 404.
[0164] Each of the control circuits 406A, 406B, 406C may be paired
to one of the panels 402A, 402B, 402C and may have a direct cable
connection to the paired panel. As illustrated in FIG. 4, each
control circuit may be connected to its paired panel via one or
more panel cables. Each panel cable may be terminated with one
connector of a pair 412 of connectors. The connector on the panel
cable may have a shape that is complementary to a shape of a
panel-side connector. The cable assembly 404 may also terminate
with one connector of a pair 414 of connectors. The connector on
the cable assembly 404 may have a shape that is complementary to a
shape of a connector on circuitry of a DC network, for example, a
connector of a DC combiner 408. The connectors 412, 414 may be
arranged to be removably connected and either or both may have an
environmental seal, which may make an electrical connection area
within the connectors 412, 414 watertight and/or airtight.
[0165] In some embodiments, the different connectors of a cable
assembly 404 may each be a keyed connector, such that the different
connectors have a different shapes and are incompatible with
non-corresponding connectors of other parts of a PV system. For
example, each cable-side connector of the connector pairs 412 may
have a shape that is compatible with each PV panel-side connector
of the pairs 412 and a shape that is incompatible with the
network-side connector of the pair 414. Similarly, the cable-side
connector of the pair 414 may have a shape that is incompatible
with the PV panel-side connectors of the pairs 412. In some such
embodiments, each type of connector (e.g., each connector that is
intended to connect two types of components in the PV system and/or
to convey a particular signal or set of signals, or that is
intended to convey a signal having a particular electrical
characteristic or range of electrical characteristics) included in
the cable assembly 404 may be a keyed connector such that the each
connector is only compatible with corresponding connectors, such as
only compatible in a correct orientation, and is incompatible with
non-corresponding connectors. This may ease installation of the
cable assembly 404 by preventing incorrect connections. This may
also increase a safety of installation and decrease a likelihood of
damage to the PV system from incorrect installation.
[0166] Embodiments are not limited to including any particular
number of control circuits or panel cables. In some embodiments,
however, it may be advantageous to limit a number of PV panels that
may be connected to one cable assembly. For example, to aid a
layperson in easily complying with applicable building codes or
other reasons, it may be advantageous to allow only up to a certain
number of PV panels to be connected to a single cable assembly.
Accordingly, in such embodiments, the cable assembly may include a
certain number of control circuits and/or a certain number of panel
cables (or sets of panel cables, in a case that a control circuit
is connected to a particular PV panel via more than one panel
cable).
[0167] Embodiments that include a cable assembly of the type
illustrated in FIG. 4 are not limited to implementing the cable
assembly in any particular manner. FIG. 5 illustrates an
illustrative implementation of a cable assembly, but it should be
appreciated that others are possible.
[0168] FIG. 5 illustrates an example of components that may be
included in a cable assembly and in a control circuit of a cable
assembly in some embodiments. Cable assembly 500 of FIG. 5 includes
a power bus 502, a control circuit 504 that is integrated with the
power bus 502, and at least one panel cable 506 that is designed to
connect control circuit 504 to a PV panel with which the control
circuit is to operate. The control circuit 504 may be integrated
with the panel cable(s) 506. The control circuit 504 may include a
housing in which various components are disposed and may include an
environmental seal, which may make the housing of the control
circuit 504 watertight and/or airtight. The power bus 502 and the
panel cable(s) 506 may extend from the housing and from the
environmental seal.
[0169] In the example of FIG. 5, the power bus 502 includes a
positive power bus 502A and a negative power bus 502B (which may
also be termed a ground bus), though in some embodiments the
negative/ground bus 502B may be omitted. The power bus 502 may be
disposed inside a cable housing (not shown in FIG. 5), which may be
a single cable housing that includes both the buses 502A, 502B or
may be separate cable housings.
[0170] As with the power bus 502, the panel cable 506 may include a
cable housing (not shown in FIG. 5), and may include a single cable
housing for each of the panel cables. In some embodiments, the
panel cable(s) 506 may include multiple wires that each connects to
a PV panel with which the control circuit 504 is to operate, which
may include, for example, a positive panel connection 506A and/or a
negative panel connection 506B to carry power generated by the PV
panel to the control circuit 504 and the power bus 502. In some
such embodiments, the multiple wires may be disposed together in a
single cable housing of a single panel cable 506, while in other
embodiments each wire may be provided with a separate cable
housing, or the wires may be combined in any suitable manner to
form multiple panel cables 506. Each panel cable 506 is terminated
with a connector 508, which may have a shape that is complementary
with a shape of a corresponding connector on a PV panel. The
connector 508 may be adapted to removably couple to the
corresponding connector on the PV panel. It should be appreciated
that, in embodiments that include multiple panel cables 506, the
panel cables 506 are not limited to terminating with the same
connector and that different connectors may be used.
[0171] Similarly, the power bus 502 terminates in a connector 510.
The connector 510 may have a shape that is complementary to a
connector of a DC network component, such as a DC combiner, and may
be adapted to removably couple to the corresponding connector.
[0172] FIG. 5 illustrates several examples of components that may
be included in the control circuit 504 and disposed within the
housing of the control circuit 504. As illustrated in FIG. 5, the
control circuit 504 may include one or more switches 512 that
connect the panel connections 506A, 506B to the power bus 502A,
502B. Through operation of the switch(es) 512, a PV panel with
which the control circuit 504 is paired may be added to a string of
PV panels or removed from the string of PV panels. The switch(es)
512 may be implemented in any suitable manner, as embodiments are
not limited in this respect. In some embodiments, the switch(es)
512 may be implemented such that when the paired PV panel is
removed from the string, the power bus 502 is shorted across the
control circuit 504 to electrically interconnect other panels of a
string without the paired PV panel. In other embodiments, however,
the switch(es) 512 may be implemented such that removal of the
paired PV panel leaves an open connection in the power bus 502 that
prevents electrical power from passing across the control circuit
504.
[0173] The switch(es) 512 may be controlled in any suitable manner,
including by a central controller such as the premises PV system
controller discussed above. In the example of FIG. 5, a controller
514 of the control circuit 504 controls a state of the switch(es)
512. The controller may be implemented in any suitable manner,
including as at least one processor executing instructions stored
in a storage medium. The controller 514 may control the state of
the switch(es) 512 responsive to instructions received from a
premises PV system controller. The controller 514 may receive the
instructions in any suitable manner, including via a communication
circuit 516. In some embodiments, the communication circuit 516 may
be connected to the power bus 502 and communicate via a power line
communication (PLC) protocol, and may receive instructions from the
premises PV system controller via a PLC signal received via the
power bus 502. Embodiments are not so limited, however. In other
embodiments, the communication circuit 516 may receive instructions
from the premises PV system controller via wireless communication,
via one or more wired communication links (not shown in FIG. 5)
running parallel with the power bus 502, or in any other suitable
manner.
[0174] The controller 514 may communicate any suitable information
to the premises PV system controller regarding a paired panel, and
may receive an instruction to operate the switch(es) 512 in
response to any such information. The control circuit 504 may
additionally include one or more monitoring circuits 518 that
detect information regarding the paired PV panel and/or receive
from the paired PV panel information regarding that panel, and that
provide that information to the controller 514. The monitoring
circuit(s) 518 may be implemented in any suitable manner and may,
in some embodiments, include one or more sensors to receive or
detect conditions relating to a paired PV panel as part of
monitoring the paired PV panel. For example, in some embodiments
the monitoring circuits 518 may include circuitry for monitoring a
performance of the paired PV panel. Monitoring the performance may
include monitoring one or more electrical characteristics of the
panel, such as by monitoring a power (e.g., a voltage) output by
the paired PV panel at a time or over time. Monitoring the
performance may additionally or alternatively include monitoring a
maximum power point of the panel over time. This performance
information may be indicative of whether the panel is functioning
properly and may be communicated to the premises PV system
controller for analysis to determine whether the panel is
functioning properly and/or whether a system is functioning
properly or to perform control of the PV panels and/or other
components of a PV system. For example, the premises PV system
controller and/or controller 514 of cable assembly 500 may control
a PV panel and/or components of a PV system to ensure power output
at a maximum power point. For example, the premises PV system
controller may control an impedance matching of a control circuit
504 and/or a DC network to which the cable assembly 500 connects to
ensure maximum power output from a string of PV panels and/or a
particular PV panel.
[0175] As another example, monitoring circuits 518 may include
circuitry to monitor a total voltage of a string of PV panels
(e.g., string 241a of FIG. 2) that is interconnected by the cable
assembly 500. The controller 514, in response to determining via
the monitoring circuits 518 that a total voltage is outside of a
particular voltage range, may operate the switch(es) 512 to add or
remove a PV panel from the string. This may be advantageous in some
embodiments because, by controlling a total string voltage to be
within a certain voltage by adding or removing PV panels from the
string dynamically, more panels may be added to a string than may
be advisable without such control.
[0176] As another example, in some embodiments the monitoring
circuits 518 may include an identification circuit that may receive
from the paired PV panel identifying information for the panel,
such as information identifying a brand and/or model of panel
and/or an operating specification for the panel. The identifying
information, once received by the monitoring circuit 518, may be
communicated by the controller 514 and communication circuit 516 to
the premises PV system controller, which may collect the
information as part of commissioning the premises PV system as
discussed above.
[0177] As another example, in some embodiments the monitoring
circuits 518 may include a circuit to detect whether the panel
connector is properly connected to a connector on the paired PV
panel. Any suitable technique for determining whether a connector
is properly connected may be used, including known techniques, as
embodiments are not limited in this respect. In some such
embodiments, for example, the circuit 518 may pass a signal to the
paired PV panel and analyze a signal received in response to
determine whether the response signal has characteristics expected
of a signal received via a proper connection. A determination made
by the monitoring circuit 518 may be passed to the controller 514
and communication circuit 516 for communication to the premises PV
system controller. In some embodiments, in a case that the
monitoring circuit 518 determines that the connector is not
properly connected to the paired PV panel, the controller 514 may
operate the switch(es) 512 to disconnect the paired PV panel from
the power bus 502. The controller 514 may be programmed to take
that action on its own or in response to a disconnect instruction
received from the premises PV system controller.
[0178] The monitoring circuit(s) 518 may be connected to a paired
PV panel in any suitable manner. In some embodiments, the circuits
518 may be connected via the positive and negative panel
connections 506A, 506B. In other embodiments, the panel cable(s)
506 may additionally include other wires that are specific to one
or more of the monitoring circuits 518. For example, the panel
cable(s) 506 may include one or more wires dedicated to
communicating identifying information for a panel from the panel to
a monitoring circuit 518. As another example, the panel cable(s)
506 may include one or more wires dedicated to communicating
signals regarding a connection test for a connector to determine
whether the connector is properly connected. As discussed above,
the panel cable(s) 506 are not limited to arranging wires of the
cable(s) 506 in any particular manner and the wires may be arranged
into any suitable combination of one or more cable housings with
associated connectors.
[0179] In some embodiments, the communication circuit 516 may also
communicate to a premises PV system controller, alone or together
with data generated by controller 514 and/or monitoring circuits
518, information on a location of the paired PV panel. The location
information that is transmitted may be relative location
information that identifies a location of the panel relative to
other panels in a set or relative to a string of PV panels. For
example, the control 504 circuit may store data identifying a
position of the control circuit 504 within the cable assembly, such
that the control circuit 504 is in the fourth position from the end
of the cable assembly. That information may be useful to identify a
relative position of a PV panel in a string, such as that the
paired PV panel is in the fourth position of the string. The
premises PV system controller may use the location information as
part of processing data received from the control circuit 504
regarding the paired PV panel. For example, if the data regarding
the paired PV panel indicates that the panel is malfunctioning,
then the premises PV system controller may output, via a user
interface, an indication that a panel is malfunctioning together
with the location information to assist a user in servicing the
panel that is malfunctioning.
[0180] While FIGS. 4-5 illustrated an example of a cable assembly
in which control circuits were individually paired to PV panels, it
should be appreciated that embodiments are not so limited. In some
embodiments, a control circuit of a cable assembly may be connected
to any suitable number of PV panels, including two or more. For
example, in one embodiment a cable assembly may include one control
circuit for every two PV panels. In some embodiments, a cable
assembly may connect to multiple PV panels and include only a
single control circuit.
[0181] FIG. 6 illustrates a computing device, according to some
embodiments. A premises PV system controller in accordance with the
techniques described herein may take any suitable form, as
embodiments are not limited in this respect. In some embodiments, a
premises PV system controller may be implemented using a computing
device 600 as illustrated in FIG. 6. In some embodiments, a
computing device 600 may be configured to perform one or more
aspects of a PV system commissioning method, in accordance with
some embodiments. One or more computing devices such as computing
device 600 may be used to implement any of the commissioning tasks
described above. The computing device 600 may include one or more
processors 606 and one or more computer-readable storage media 602
(i.e., tangible, non-transitory, computer-readable media), e.g.,
one or more volatile storage media and/or one or more non-volatile
storage media. The one or more processors 606 may control writing
of data to and reading of data from the storage 602 in any suitable
manner. The one or more processors 606 may control movement of data
on interconnection network 610 in any suitable manner.
[0182] To perform any of the commissioning tasks described herein,
the one or more processors 606 may execute one or more instructions
stored in one or more computer-readable storage media (e.g.,
storage 602), which may serve as tangible, non-transitory,
computer-readable media storing instructions for execution by one
or more processors 606. In some embodiments, one or more processors
606 may include one or more processing circuits, including, but not
limited to, a central processing unit (CPU), a graphics processing
unit (GPU), a field-programmable gate array (FPGA), an accelerator,
and/or any other suitable device (e.g., circuit) configured to
process data.
[0183] In some embodiments, computing device 600 may include a
network interface 608 suitable for processing communication between
computing device 600 and one or more remote computers over one or
more networks (e.g., computer networks). In some embodiments,
computing device 600 may be configured to use network interface 608
to obtain data associated with components of a PV system (e.g., by
communicating with one or more communication interfaces (246, 252,
262)). In some embodiments, computing device 600 may use network
interface 608 to communicate with a remote computer of a premises
operator 122, an electrical grid operator 124, and/or a regulatory
entity 126.
[0184] The computer network(s) over which network interface 608
communicates may include a local area network (LAN), a wide area
network (WAN), an intranet, the Internet, a power-line
communication network, a wired communication network, a wireless
communication network, and/or any other suitable network. In some
embodiments, network interface 608 may send and/or receive data
using any suitable communication protocol and/or standard,
including, without limitation, TCP/IP, UDP, HTTP, HTTPs, FTP, POP,
IMAP, ICMP, I2C. PPP, E6, SSL, SFTP, SSH, Bluetooth, WiFi, WiMAX,
GSM, 2G, 3G, 4G, LTE, and/or the IEEE 802 family of standards.
Embodiments are not limited by the manner in which computing device
600 communicates with one or more remote computing devices.
[0185] It should be appreciated from the foregoing that some
embodiments are directed to commissioning methods, as illustrated
in FIG. 3. Such methods may be performed, for example, by one or
more components of a computing device 600, although other
implementations are possible, as the methods are not limited in
this respect.
ADDITIONAL EMBODIMENTS
[0186] Techniques described may be embodied as a method, of which
at least one example has been provided. The acts performed as part
of the method may be ordered in any suitable way. Accordingly,
embodiments may be constructed in which acts are performed in an
order different than illustrated, which may include performing some
acts simultaneously, even though shown as sequential acts in
illustrative embodiments.
[0187] The above-described embodiments can be implemented in any of
numerous ways. For example, the embodiments may be implemented
using hardware, software or a combination thereof. When implemented
in software, the software code can be executed on any suitable
processor (e.g., processing circuit) or collection of processors,
whether provided in a single computer or distributed among multiple
computers. It should be appreciated that any component or
collection of components that perform the functions described above
can be generically considered as one or more controllers that
control the above-discussed functions. The one or more controllers
can be implemented in numerous ways, such as with dedicated
hardware, or with general purpose hardware (e.g., one or more
processors) that is programmed using microcode or software to
perform the functions recited above.
[0188] In this respect, various aspects may be embodied and/or
implemented at least in part as at least one computer-readable
storage medium (i.e., at least one tangible, non-transitory
computer-readable medium) encoded with a computer program (a
plurality of instructions), which, when executed on one or more
processors, cause the above-discussed steps or acts to be
performed. Examples of a computer-readable storage medium may
include, but are not limited to, a computer memory, a floppy disk,
a compact disc, an optical disc, a magnetic tape, a flash memory, a
circuit configuration in a Field Programmable Gate Array (FPGA) or
other semiconductor device, or other tangible, non-transitory
computer-readable medium. As is apparent from the foregoing
examples, a computer readable storage medium may retain information
for a sufficient time to provide computer-executable instructions
in a non-transitory form. The computer-readable storage medium may
be transportable, such that the program or programs stored thereon
can be loaded onto one or more different computers or other
processors to implement various aspects of the present technology
as discussed above. In some embodiments, processing of data and
aspects of system operation may be implemented entirely, or at
least in part, in FPGAs as hard-wired computer-executable
instructions.
[0189] Computer-executable instructions may be in any one or
combination of several forms, such as program modules, executed by
one or more computers or other devices. Generally, program modules
may include routines, programs, objects, components, data
structures, etc. that perform particular tasks or implement
particular abstract data types. Typically the functionality of the
program modules may be combined or distributed as desired in
various embodiments.
[0190] Computer-executable instructions may be executable on one or
more processors that employ any one of a variety of operating
systems or platforms. Additionally, such instructions may be
written using any of a number of suitable programming languages
and/or programming or scripting tools, and also may be compiled as
executable machine language code or intermediate code that is
executed on a framework or virtual machine.
[0191] Processors may be implemented as circuits (e.g., integrated
circuits), including commercially-available circuits known in the
art by names such as CPU chips, GPU chips, microprocessors,
microcontrollers, or co-processors. Alternatively, a processor may
be implemented in custom circuitry, such as an ASIC, or semicustom
circuitry resulting from configuring a programmable logic device.
As yet a further alternative, a processor may be a portion of a
larger circuit or semiconductor device, whether
commercially-available, semi-custom, or custom-built. As a specific
example, some commercially-available microprocessors have multiple
cores such that one or a subset of those cores may constitute a
processor suitable for implementing functionality described above.
Though, a processor may be implemented using logic circuitry in any
suitable format.
[0192] A data-processing device may be embodied in any of a number
of forms, such as a rack-mounted computer, a desktop computer, a
laptop computer, or a tablet computer. Additionally, a
data-processing device may comprise embedded data-processing
circuitry in a device not generally regarded as a computer but with
suitable processing capabilities, including a Personal Digital
Assistant (PDA), a smart phone, or any other suitable portable or
fixed electronic device.
[0193] It should be appreciated that the foregoing description is
by way of example only, and embodiments are not limited to
providing any or all of the above-described functionality, although
some embodiments may provide some or all of the functionality
described herein.
[0194] The embodiments described herein can be implemented in any
of numerous ways, and are not limited to any particular
implementation techniques. Thus, while examples of specific
implementation techniques are described below, it should be
appreciated that the examples are provided merely for purposes of
illustration, and that other implementations are possible.
[0195] The terms "program" or "software" are used in a generic
sense to refer to computer code or set of computer-executable
instructions that can be employed to program a computer or other
processor to implement various aspects of the present technology as
discussed above. Additionally, in some embodiments, one or more
computer programs that when executed perform methods of the present
technology need not reside on a single computer or processor, but
may be distributed in a modular fashion amongst a number of
different computers or processors to implement various aspects of
the present technology.
[0196] The indefinite articles "a" and "an," as used in the
specification and in the claims, unless clearly indicated to the
contrary, should be understood to mean "at least one."
[0197] The phrase "and/or," as used in the specification and in the
claims, should be understood to mean "either or both" of the
elements so conjoined, i.e., elements that are conjunctively
present in some cases and disjunctively present in other cases.
Multiple elements listed with "and/or" should be construed in the
same fashion, i.e., "one or more" of the elements so conjoined.
Other elements may optionally be present other than the elements
specifically identified by the "and/or" clause, whether related or
unrelated to those elements specifically identified. Thus, as a
non-limiting example, a reference to "A and/or B", when used in
conjunction with open-ended language such as "comprising" can
refer, in one embodiment, to A only (optionally including elements
other than B); in another embodiment, to B only (optionally
including elements other than A); in yet another embodiment, to
both A and B (optionally including other elements); etc.
[0198] As used in the specification and in the claims, "or" should
be understood to have the same meaning as "and/or" as defined
above. For example, when separating items in a list, "or" or
"and/or" shall be interpreted as being inclusive, i.e., the
inclusion of at least one, but also including more than one, of a
number or list of elements, and, optionally, additional unlisted
items. Only terms clearly indicated to the contrary, such as "only
one of" or "exactly one of," or, when used in the claims,
"consisting of," will refer to the inclusion of exactly one element
of a number or list of elements. In general, the term "or" as used
shall only be interpreted as indicating exclusive alternatives
(i.e. "one or the other but not both") when preceded by terms of
exclusivity, such as "either," "one of," "only one of," or "exactly
one of." "Consisting essentially of," when used in the claims,
shall have its ordinary meaning as used in the field of patent
law.
[0199] As used in the specification and in the claims, the phrase
"at least one," in reference to a list of one or more elements,
should be understood to mean at least one element selected from any
one or more of the elements in the list of elements, but not
necessarily including at least one of each and every element
specifically listed within the list of elements and not excluding
any combinations of elements in the list of elements. This
definition also allows that elements may optionally be present
other than the elements specifically identified within the list of
elements to which the phrase "at least one" refers, whether related
or unrelated to those elements specifically identified. Thus, as a
non-limiting example, "at least one of A and B" (or, equivalently,
"at least one of A or B," or, equivalently "at least one of A
and/or B") can refer, in one embodiment, to at least one,
optionally including more than one, A, with no B present (and
optionally including elements other than B); in another embodiment,
to at least one, optionally including more than one, B, with no A
present (and optionally including elements other than A); in yet
another embodiment, to at least one, optionally including more than
one, A, and at least one, optionally including more than one, B
(and optionally including other elements); etc.
[0200] The use of "including," "comprising," "having,"
"containing," "involving," and variations thereof, is meant to
encompass the items listed thereafter and additional items. Use of
ordinal terms such as "first," "second," "third," etc., in the
claims to modify a claim element does not by itself connote any
priority, precedence, or order of one claim element over another or
the temporal order in which acts of a method are performed. Ordinal
terms are used merely as labels to distinguish one claim element
having a certain name from another element having a same name (but
for use of the ordinal term), to distinguish the claim
elements.
[0201] Having described several embodiments of the invention in
detail, various modifications and improvements will readily occur
to those skilled in the art. Such modifications and improvements
are intended to be within the spirit and scope of the invention.
Accordingly, the foregoing description is by way of example only,
and is not intended as limiting. The invention is limited only as
defined by the following claims and the equivalents thereto.
* * * * *