Electricity Industry Participation Code 2010

• (1) A distributor must create an ICP identifier for each ICP on each network for which the distributor is responsible in accordance with the following format:

• (2) The ICP identifier must be used by a participant in all communications with the registry manager to identify—
  • (a) the point at which a trader is deemed to convey electricity to a consumer or from an embedded generating station; and
  • (b) the point of connection between an embedded network and its parent network, or the point of connection between a shared unmetered load and its network.
• (3) Despite any clause to the contrary, only the obligations in this clause and clauses 2, 6 and 7(1)(a) to (e), (l) and (m) apply if an ICP identifier is used to identify a—
  • (a) point of connection between an embedded network and its parent network; or
  • (b) point of connection between shared unmetered load and its network.
• (4) If an ICP identifier is used in the management of the status of the ICP, the obligations in clauses 13, 16 and 20 also apply.

• (1) Each ICP identifier must have a location address that allows the ICP to be readily located.
• (2) Despite subclause (1), the address of an ICP identifier for distributed unmetered load may be the location of the distributed unmetered load database.

• (1) Subject to subclause (2), a distributor must not create an ICP identifier or connect an ICP created after 7 October 2002 unless—
  • (a) the ICP identifier is for an ICP that can be electrically disconnected without electrically disconnecting another ICP; and
  • (b) the ICP can be electrically disconnected without electrically disconnecting another ICP.
• (2) Subclause (1) does not apply if the ICP is—
  • (a) the point of connection between a network and an embedded network; or
  • (b) an ICP that represents the consumption calculated by the difference between the total consumption for the embedded network and all other ICPs on the embedded network.
• (3) A distributor must not—
  • (a) connect a new ICP to an existing ICP in series unless the existing ICP is of the type described in subclause (2)(a) or (2)(b); or
  • (b) create a new ICP identifier for a new or existing ICP in series with an existing ICP unless the existing ICP is of the type described in subclause (2)(a) or (2)(b) and the distributor is responsible for both the new and existing ICPs.

• The Authority may, by giving written notice, grant a dispensation from the requirements of clause 3 for an ICP that cannot be electrically disconnected without electrically disconnecting another ICP.

• The electrical load associated with an ICP is deemed to be supplied through 1 network supply point only.

• An ICP must have a single loss category code that is referenced in such a way as to identify the associated loss factors.

• (1) A distributor must, for each ICP on the distributor’s network, provide the following information to the registry manager:
  • (a) the location address of the ICP identifier:
  • (b) subject to subclause (4), the NSP identifier of the NSP to which the ICP is usually connected:
  • (c) the installation type code assigned to the ICP:
  • (d) the reconciliation type code assigned to the ICP:
  • (e) the loss category code and loss factors for each loss category code assigned to the ICP:
  • (f) if the ICP connects the distributor's network to an embedded generating station that has a capacity of 10 MW or more, the information required by subclause (6), in accordance with subclause (7):
  • (g) the price category code assigned to the ICP, which may be a placeholder price category code only if the distributor is unable to assign the actual price category code because the capacity or volume information required to assign the actual price category code cannot be determined before electricity is traded at the ICP:
  • (h) if the price category code assigned under paragraph (g) requires one or more values for the capacity of the ICP, the chargeable capacity of the ICP, as follows:
    • (i) if the chargeable capacity cannot be determined before electricity is traded at the ICP, a placeholder chargeable capacity:
    • (ii) if the capacity value or values can be determined for a billing period from the metering information collected for that billing period, no chargeable capacity:
    • (iia) if there is more than one capacity value at the ICP, and one or more, but not all, of those capacity values can be determined for a billing period from the metering information collected for that billing period—
      • (A) no capacity value recorded in the registry field for the chargeable capacity; and
      • (B) either the term "POA" or all other capacity values, recorded in the registry field in which the distributor installation details are also recorded:
    • (iib) if there is more than one capacity value at the ICP, and none of those capacity values can be determined for a billing period from the metering information collected for that billing period—
      • (A) the annual capacity value recorded in the registry field for the chargeable capacity; and
      • (B) either the term "POA" or all other capacity values, recorded in the registry field in which the distributor installation details are also recorded:
    • (iii) in any other case, the actual chargeable capacity:
  • (i) the distributor installation details of the ICP determined by the price category code assigned to the ICP (if any), which may be placeholder distributor installation details only if the distributor is unable to assign the actual distributor installation details because the capacity or volume information required to assign the actual distributor installation details cannot be determined before electricity is traded at the ICP:
  • (j) the participant identifier of the first trader who has entered into an arrangement with a customer or an embedded generator to sell or purchase electricity at the ICP (only if the information is provided by the first trader):
  • (k) the status of the ICP determined in accordance with clauses 12 to 20:
  • (l) designation of the ICP as "Dedicated" if the ICP is located in a balancing area that has more than 1 NSP located within it, and—
    • (i) the ICP will be supplied only from the NSP with the NSP identifier provided under paragraph (b); or
    • (ii) the ICP is a point of connection between a network and an embedded network:
  • (m) if unmetered load, other than distributed unmetered load, is associated with the ICP, the type and capacity in kW of the unmetered load (if the distributor knows that information):
  • (n) if shared unmetered load is associated with the ICP, a list of the ICP identifiers of the ICPs that are associated with the unmetered load:
  • (o) if the ICP connects the distributor’s network to distributed generation,—
    • (i) the nameplate capacity of the distributed generation; and
    • (ii) the generation fuel type of the distributed generation:
  • (p) the date on which the ICP is initially electrically connected.
• (1A) For the purposes of subclause (1)(h), if the price category assigned to the ICP requires information additional to chargeable capacity to unambiguously define the line charges, the additional information may be contained in the distributor installation details field of the registry.
• (2) The distributor must provide the information specified in subclauses (1)(a) to (1)(o) to the registry manager as soon as practicable after the ICP identifier for the ICP to which the information relates is created, and before electricity is traded at the ICP.
• (2A) The distributor must provide the information specified in subclause (1)(p) to the registry manager no later than 10 business days after the date on which the ICP is initially electrically connected.
• (2B) Despite subclause (2A), the distributor is not required to provide the information specified in subclause (1)(p) if the date on which the ICP is initially electrically connected is earlier than 29 August 2013.
• (3) The distributor must provide the following information to the registry manager no later than 10 business days after the trading of electricity at the ICP commences:
  • (a) the actual price category code assigned to the ICP:
  • (b) the actual chargeable capacity of the ICP determined by the price category code assigned to the ICP (if any):
  • (c) the actual distributor installation details of the ICP determined by the price category code assigned to the ICP (if any).
• (4) If a distributor cannot identify the NSP that is connected to an ICP, the distributor must nominate the NSP that the distributor thinks is most likely to be connected to the ICP, taking into account the flow of electricity within the distributor’s network.
• (5) An ICP is deemed to be connected to the NSP nominated by the distributor under subclause (1)(b).
• (6) If a distributor assigns a loss category code to an ICP on the distributor’s network that connects the distributor’s network to an embedded generating station that has a capacity of 10MW or more—
  • (a) the loss category code assigned to the ICP must be unique and must not be assigned to any other ICP on the distributor’s network; and
  • (b) the distributor must provide the following information to the reconciliation manager:
    • (i) the unique loss category code assigned to the ICP:
    • (ii) the ICP identifier of the ICP:
    • (iii) the NSP identifier of the NSP to which the ICP is connected:
    • (iv) the plant name of the embedded generating station.
• (7) The distributor must provide the information in subclause (6) no later than 5 business days before the distributor assigns the loss category code.
• (8) A distributor may provide the registry manager with global positioning system coordinates for each ICP on the distributor’s network.
• (9) If a distributor provides the global positioning system coordinates of an ICP to the registry manager under subclause (8), it must provide the coordinates—
  • (a) as New Zealand Transverse Mercator 2000 (NZTM2000) coordinates as defined in Land Information New Zealand’s LINZS25002 standard (Standard for New Zealand Geodetic Datum 2000 Projections); or
  • (b) in a format specified by the Authority.

• (1) If information about an ICP provided to the registry manager in accordance with clause 7 changes, the distributor in whose network the ICP is located must give written notice to the registry manager of the change.
• (2) Subject to subclause (2A), the distributor must give the notice—
  • (a) in the case of a change to the information referred to in clause 7(1)(b) (other than a change that is the result of the commissioning or decommissioning of an NSP), no later than 8 business days after the change takes effect; and
  • (aa) in the case of a change to the information provided under clauses 7(1)(g), 7(1)(h) and 7(1)(i), where the change is backdated, no later than 3 business days after the distributor and the trader responsible for the ICP have agreed on the change; and
  • (ab) in the case of decommissioning an ICP, by the later of—
    • (i) 3 business days after the registry manager has advised the distributor under clause 11.29 that the ICP is ready to be decommissioned; and
    • (ii) 3 business days after the distributor has decommissioned the ICP; and
  • (b) in every other case, no later than 3 business days after the change takes effect.
• (2A) Where the functioning of the registry prevents the distributor from updating the registry until after a metering equipment provider has completed its obligations relating to the ICP in accordance with Schedule 11.4, the timeframes in subclause (2) start from the day the metering equipment provider completes those obligations.
• (3) A distributor is not required to give written notice if information provided in accordance with clause 7(1)(b) changes, and applies for less than 10 business days.
• (4) If information provided under clause 7(1)(b) changes, and applies for 10 business days or more, the distributor must—
  • (a) give the notice under subclause (1) no later than 13 business days after the change takes effect; and
  • (b) include in the notice the date the change occurred as the effective date for the change.

• (1) Each trader must provide the following information to the registry manager for each ICP for which it is recorded in the registry as having responsibility:
  • (a) the participant identifier of the trader:
  • (b) the profile code of each profile at that ICP approved by the Authority in accordance with clause 13 of Schedule 15.5:
  • (c) the participant identifier of the metering equipment provider for each category 1 metering installation, or higher category metering installation, for the ICP:
  • (d) [Revoked]
  • (e) [Revoked]
  • (ea) the type of submission information that the trader will provide to the reconciliation manager for the ICP:
  • (f) if the settlement type UNM is assigned to the ICP—
    • (i) if the load is profiled through an engineering profile in accordance with profile class 2.1, the code ENG; or
    • (ii) in all other cases, the daily average unmetered load in kWh at the ICP:
  • (g) the type and capacity of the unmetered load at the ICP (if any):
  • (h) [Revoked]
  • (i) [Revoked]
  • (j) the status of the ICP determined in accordance with clauses 12 to 20.
  • (k) except as provided in subclause (1A), the relevant business classification code applicable to the customer at the ICP, in accordance with business classification codes published by the Authority.
• (1A) A trader must not provide the information specified in subclause (1)(k) if—
  • (a) the ICP exists for the purpose of reconciling embedded network residual load; or
  • (b) the ICP has "Distributor" status as specified in clause 16.
• (2) The trader must provide the information specified in subclause (1)(a) to subclause (1)(j) to the registry manager no later than 5 business days after the trader commences trading at the ICP to which the information relates.
• (3) The trader must provide the information specified in subclause (1)(k) to the registry manager no later than 20 business days after the trader commences trading at the ICP to which the information relates.

• (1) If information about an ICP provided to the registry manager in accordance with clause 9 changes, the trader who trades at the ICP must give written notice to the registry manager of the change.
• (2) Subject to subclause (2A) the trader must give the notice no later than 5 business days after the change.
• (2A) Where the functioning of the registry prevents the trader from updating the registry until after the metering equipment provider has completed its obligations relating to the ICP in accordance with Schedule 11.4, the timeframes in subclause (2) start from the day the metering equipment provider has completed those obligations.
• (3) [Revoked]
• (4) [Revoked]

• (1) By 0900 hours on the 1^st business day of each reconciliation period, the registry manager must provide to each participant who is required to submit submission information, the following:
  • (a) a list of the ICPs at which the participant is recorded on the registry as trading during each consumption period being revised in the reconciliation period:
  • (b) all information associated with the participant’s participant identifier, including the profiles for each ICP.
• (2) If there is an error in the information provided under subclause (1), the participant must change the information in the registry as soon as practicable after becoming aware of the error.

The status of an ICP, as recorded on the registry, must be managed by distributors and traders in accordance with clauses 13 to 20.

• The ICP status of “New” must be managed by the relevant distributor and indicates that—
  • (a) the associated electrical facilities are in the construction phase; and
  • (b) the ICP is not ready for the trader to authorise the electrical connection of the ICP.

• (1) The ICP status of “Ready” must be managed by the relevant distributor and indicates that—
  • (a) the associated electrical facilities are ready for connecting to the electricity supply; or
  • (b) the ICP is ready for the trader to authorise the electrical connection of the ICP.
• (2) Before an ICP is given the "Ready" status, the relevant distributor must—
  • (a) identify the trader that has taken responsibility for the ICP; and
  • (b) ensure that the ICP has a single price category code.

• (1) Subclause (2) applies if—
  • (a) an ICP has had the status of "New" for 24 months or more; or
  • (b) an ICP has had the status of "Ready" for 24 months or more.
• (2) The distributor must—
  • (a) ask the trader who intends to trade at the ICP whether the ICP should continue to have that status; and
  • (b) decommission the ICP if the trader advises that the ICP should not continue to have that status.

• (1) The ICP status of “Distributor” must be managed by the relevant distributor and indicates that the ICP record represents a shared unmetered load installation or the point of connection between an embedded network and its parent network.
• (2) A trader cannot change the status of an ICP record with the ICP status of “Distributor”.

• (1) The ICP identifier status of “Active” must be managed by the relevant trader and indicates that—
  • (a) the associated electrical facilities are electrically connected; and
  • (b) a trader must provide information related to the ICP identifier, in accordance with Part 15, to the reconciliation manager for the purpose of compiling reconciliation information.
• (2) Before an ICP is given the “Active” status, the trader must ensure that—
  • (a) the ICP identifier has only 1 embedded generator, direct purchaser, or customer of a retailer; and
  • (b) the electricity consumed is quantified by a metering installation or a method of calculation approved by the Authority.

• (1) Except as provided in subclause (2), the ICP status of “Inactive” must be managed by the relevant trader and indicates that—
  • (a) the ICP is electrically disconnected; or
  • (b) submission information related to the ICP is not required by the reconciliation manager for the purpose of compiling reconciliation information.
• (2) The ICP status of “Inactive” may be managed by the relevant distributor only to indicate that—
  • (a) there has been an interruption in electricity supply affecting the ICP; or
  • (b) the ICP cannot be electrically disconnected following a request for electrical disconnection.

• (1) The ICP status of “Decommissioned” must be managed by the relevant distributor and indicates that the ICP is permanently removed from future switching and reconciliation processes.
• (2) Decommissioning occurs when—
  • (a) electrical facilities associated with the ICP are physically removed; or
  • (b) there is a change in the allocation of electrical loads between ICPs with the effect of making the ICP obsolete; or
  • (c) in the case of a distributor-only ICP for an embedded network, the embedded network no longer exists.

• (1) Each distributor must keep up to date the table in the registry of the loss category codes that may be assigned to ICPs on each distributor’s network, by entering in the table any new loss category codes that may be assigned to an ICP on the distributor’s network.
• (2) Each entry in the table must specify the date on which each loss category code takes effect.
• (3) The date that a loss category code takes effect must not be earlier than 2 months after the date on which the loss category code is entered in the table.
• (4) A loss category code takes effect on the specified date.
• (5) To avoid doubt, subclause (3) does not apply to the creation of an ICP or to the transfer of an ICP from 1 distributor's network to another distributor's network.

• (1) A distributor must enter loss factors in the registry for each loss category code entered on the table in the registry under clause 21.
• (2) A distributor must ensure that—
  • (a) each loss category code has no more than 2 loss factors in a calendar month; and
  • (b) each loss factor covers a range of trading periods within that month so that all trading periods have a single applicable loss factor.
• (3) A distributor who wishes to replace an existing loss factor on the table in the registry must enter the replaced loss factor on the table in the registry.
• (4) Each entry in the table must specify the date on which the replaced loss factor takes effect.
• (5) The date that a loss factor takes effect must not be earlier than 2 months after the date on which the loss factor is entered in the table.
• (6) A replaced loss factor takes effect on the specified date.
• (7) To avoid doubt, subclause (5) does not apply to the creation of an ICP or to the transfer of an ICP from 1 distributor's network to another distributor's network.
• (8) The registry manager must publish an updated schedule of all loss category codes and the loss factors for each loss category code no later than 1 business day after receiving notice of a change.

• (1) Each distributor must keep up to date the table in the registry of the price category codes that may be assigned to ICPs on each distributor’s network, by entering in the table any new price category codes that may be assigned to an ICP on the distributor’s network.
• (2) Each entry in the table must specify the date on which each price category code takes effect.
• (3) The date that a price category code takes effect must not be earlier than 2 months after the date on which the price category code is entered in the table.
• (4) A price category code takes effect on the specified date.
• (5) To avoid doubt, subclause (3) does not apply to the creation of an ICP or to the transfer of an ICP from 1 distributor's network to another distributor's network.

• (1) A distributor must give written notice to the reconciliation manager of the establishment of a balancing area associated with an NSP supplying the distributor’s network, in accordance with clause 26.
• (2) A distributor must give written notice to the reconciliation manager of any change to the information provided under subclause (1).
• (3) The notice must―
  • (a) specify the date and trading period from which the change takes effect; and
  • (b) be given no later than 3 business days after the change takes effect.
• (4) The reconciliation manager must give written notice to the registry manager of changes to balancing areas within 1 business day after receiving the notice.
• (5) The registry manager must publish an updated schedule of the mapping between NSPs and balancing areas within 1 business day after receiving the notice.
• (6) The schedule must specify the date and trading period from which the change took effect.

• (1) If an NSP is to be created or decommissioned,—
  • (a) the participant specified in subclause (3) in relation to the NSP must give written notice to the reconciliation manager of the creation or decommissioning; and
  • (b) the reconciliation manager must give written notice to the Authority and affected reconciliation participants of the creation or decommissioning no later than 1 business day after receiving the notice in paragraph (a).
• (2) If a distributor wishes to change the record in the registry of an ICP that is not recorded as being usually connected to an NSP in the distributor’s network, to transfer the ICP so that it is recorded as being usually connected to an NSP in the distributor’s network, the distributor must give written notice to the reconciliation manager, the Authority, and each affected reconciliation participant of the transfer.
• (3) The notice required by subclause (1) must be given by—
  • (a) the grid owner, if—
    • (i) the NSP is a point of connection between the grid and a local network; or
    • (ii) if the NSP is a point of connection between a generator and the grid; or
  • (b) the distributor for the local network who initiated the creation or decommissioning, if the NSP is an interconnection point between 2 local networks; or
  • (c) the embedded network owner who initiated the creation or decommissioning, if the NSP is an interconnection point between 2 embedded networks; or
  • (d) the distributor for the embedded network, if the NSP is a point of connection between an embedded network and another network.
• (4) A distributor who is required to give written notice of a transfer under subclause (2) or subclause (3)(d) must comply with Schedule 11.2.
• (5) The participant required to give notice under subclause (1) must give notice no later than 30 days prior to the intended date of creation or decommissioning of the NSP.
• (6) If a participant changes the intended date of creation or decommissioning after giving notice under subclause (1), the new intended date of creation or decommissioning must not be earlier than the original intended date of creation or decommissioning given in the notice under subclause (1), and the participant must give a replacement notice advising the new intended date of creation or decommissioning, as soon as possible after the participant decides to change the intended date.
• (7) An embedded network owner must not give written notice of decommissioning an NSP under subclause (3)(c) or subclause (3)(d) unless—
  • (a) the embedded network owner has changed the status in the registry of all ICPs recorded as being usually connected to the NSP to ‘Decommissioned’; or
  • (b) a distributor has changed the record in the registry of each ICP previously recorded as being usually connected to the NSP, and with a status in the registry of ‘Active’ or ‘Inactive’, to record the ICP as being usually connected to an NSP in the distributor’s network; or
  • (c) a combination of the changes described in paragraphs (a) and (b) has occurred, so that no ICP with a status in the registry of ‘Active’ or ‘Inactive’ is recorded as being connected to the NSP that is to be decommissioned.

• (1) If a participant gives notice under clause 25(1) or (2) of the creation of an NSP or the transfer of an ICP from 1 distributor's network to another distributor's network, the participant must request that the reconciliation manager create a unique NSP identifier for the NSP.
• (2) The participant must make the request―
  • (a) in the case of notice given under clause 25(3)(b) or (c), at least 10 business days before the NSP is electrically connected; and
  • (b) in every other case, at least 1 month before the NSP is electrically connected or the ICP is transferred.
• (3) If a participant gives notice under clause 25(1) of the creation of an NSP, the distributor on whose network the NSP is located must give the reconciliation manager the following information:
  • (a) if the NSP is to be located in a new balancing area to be created—
    • (i) all relevant details necessary for the balancing area to be created; and
    • (ii) notice that the NSP to be created is to be assigned to the new balancing area; and
  • (b) in every other case, notice of the balancing area in which the NSP is located.
• (4) If a participant gives notice under clause 25(1) or (2) of a creation or transfer that relates to an NSP between a network and an embedded network, the distributor who owns the embedded network must give written notice to the reconciliation manager of the following:
  • (a) the network on which the NSP will be located after the creation or transfer:
  • (b) the ICP identifier for the ICP that connects the network and the embedded network:
  • (c) the date on which the creation or transfer will take effect.
• (5) The distributor must give the notice at least 1 month before the creation or transfer.

• (1) If a transfer for which notice is given under clause 25 results in an ICP becoming an NSP at which an embedded network connects to a network, or in an ICP becoming an NSP that is an interconnection point, the distributor who owns the network on which the NSP will be located after the change must give written notice to any trader trading at the ICP of the transfer.
• (2) The distributor must give the notice at least 1 month before the transfer.

• The reconciliation manager must, within 1 business day of receiving notice under clause 25(1) or (2), allocate a unique NSP identifier to each point of connection or interconnection point to which the notice relates in accordance with the following format:

• (1) If a network owner acquires all or part of an existing network, the network owner must give written notice to the following of the acquisition:
  • (a) the previous network owner:
  • (b) the reconciliation manager:
  • (c) the Authority:
  • (d) every reconciliation participant who trades at an ICP connected to the network or part of the network acquired.
• (2) The network owner must give the notice at least 1 month before the acquisition.
• (3) The notice must specify―
  • (a) the ICP identifiers for which the network owner’s participant identifier must be amended to reflect the acquisition of the network or part of the network by the network owner; and
  • (b) the effective date of the acquisition.
• (4) A network owner who acquires all or part of an existing network must comply with Schedule 11.2.

• (1) The reconciliation manager must—
  • (a) advise the registry manager of any new or deleted NSP identifier no later than 1 business day after receiving notice of its creation or deletion; and
  • (b) advise the registry manager of any changes to supporting NSP information provided by a distributor in accordance with clause 26(4) no later than 1 business day after receiving the notice.
• (2) The registry manager must publish an updated schedule of all NSP identifiers and supporting information within 1 business day of receiving notice in accordance with subclause (1).

This Schedule applies if a distributor (the applicant distributor) wishes to change the record in the registry of an ICP that is not recorded as being usually connected to an NSP in the distributor's network, to transfer the ICP so that it is recorded as being usually connected to an NSP in the applicant distributor’s network.

The applicant distributor must give written notice to the Authority of the transfer.

The notice must be in the prescribed form.

The notice must be given no later than 3 business days before the transfer takes effect.

The applicant distributor must give the Authority confirmation that the applicant distributor has received written consent to the proposed transfer from—

• (a) the distributor whose network is associated with the NSP to which the ICP is recorded as being connected immediately before the notice, except if the notice relates to the creation of an embedded network; and
• (b) every trader who trades electricity at any ICP nominated at the time of notice as being supplied from the same NSP to which the notice relates.

For the purposes of clause 5, the distributor (under subclause 5(a)) or the trader (under subclause 5(b)) is deemed to have consented to the proposed transfer if the applicant distributor has requested in writing the distributor’s or trader’s written consent and—

• (a) the distributor or trader (as the case may be)—
  • (i) has not provided written consent; and
  • (ii) has not indicated in writing that it refuses to give written consent; and
• (b) more than 40 business days (or such other period as the applicant distributor agrees with the distributor or trader) have passed since the applicant distributor requested the distributor’s or trader’s written consent; and
• (c) during the 40 business days (or such other period as the applicant distributor agrees with the distributor or trader) the applicant distributor has—
  • (i) checked the registry to ensure it has sought consent from the correct distributor or trader; and
  • (ii) made reasonable endeavours to contact the distributor or trader and obtain a response.

For the purposes of clause 5, the distributor (under subclause 5(a)) or the trader (under subclause 5(b)) must not unreasonably withhold consent to the proposed transfer.

If a notice relates to an embedded network, it must relate to every ICP on the embedded network.

The Authority must not authorise the change of any information in the registry if clauses 2 to 5 are not complied with.

Despite clause 7, the Authority may authorise the change if the applicant distributor has not given written notice to the Authority within the time frame required under clause 4, if—

• (a) the applicant distributor has complied with clauses 2, 3 and 5; and
• (b) the Authority considers that it has not been materially disadvantaged by the applicant distributor's failure to comply with clause 4.

The notice must include any information requested by the Authority from time to time.

The registry manager must remove from the registry any information the registry manager has received under clause 7 of Schedule 11.1 if the information—

• (a) relates to an ICP for which an applicant distributor has given written notice of a transfer under this Schedule; and
• (b) was to come into effect after the date on which the Authority authorises the change of information in the registry under this Schedule.

A transfer may take effect on a date that is before the date on which the notice is given only with the consent of the Authority.

Each reconciliation participant must take a validated meter reading or permanent estimate on the date a transfer becomes effective for use in the creation of the reconciliation participant’s submission file, unless the Authority authorises the reconciliation manager to provide additional seasonal adjustment shapes under clause 12.

The Authority may authorise the reconciliation manager to provide additional seasonal adjustment shapes for use in the creation of each reconciliation participant's submission file.

• (1) This Schedule prescribes 3 processes for switching ICPs as follows:
  • (a) a standard switch process that applies in the circumstances described in clause 1(1):
  • (b) a switch move process that applies in the circumstances described in clause 8(1):
  • (c) a gaining trader switch process that applies in the circumstances described in clause 13(1).
• (2) If a trader proposes switching an ICP, the trader must use one of the switch processes set out in this Schedule.

• (1) A standard switch process applies only when a trader (the "gaining trader") has an arrangement with a customer or embedded generator to commence trading electricity with the customer or embedded generator at, or to otherwise assume responsibility under clause 11.18(1) for, an ICP at which another trader (the "losing trader") trades electricity, and the gaining trader switch process under clauses 13 to 16 does not apply.
• (1A) This clause and clauses 2 to 7 apply to a standard switch process.
• (2) If subpart 2 of Part 4A of the Fair Trading Act 1986 applies to an arrangement described in subclause (1),―
  • (a) the gaining trader must identify the period within which the customer or embedded generator may cancel the arrangement in accordance with section 36M of the Fair Trading Act 1986; and
  • b) for the purpose of this Schedule, the arrangement is deemed to come into effect on the day after the expiry of the period.

• (1) For each ICP to which a switch relates, the gaining trader must advise the registry manager of the switch no later than 2 business days after the arrangement to trade electricity with the customer or the embedded generator comes into effect.
• (2) The gaining trader must include in its advice to the registry manager—
  • (a) [Revoked]
  • (b) that the switch type is TR; and
  • (c) 1 or more profile codes of a profile at the ICP.

• No later than 3 business days after the date on which the registry manager, under clause 22(a), makes written notice of a switch request available to the losing trader, the losing trader must,—
  • (a) either—
    • (i) acknowledge the switch request by providing the following information to the registry manager:
      • (A) the proposed event date; and
      • (B) a valid switch response code approved by the Authority; or
    • (ii) provide the final information specified in clause 5(a) to (c) to complete the switch; or
  • (b) [Revoked]
  • (c) request that the switch be withdrawn in accordance with clause 17.

• (1) The losing trader must establish event dates so that—
  • (a) no event date is more than 10 business days after the date on which the registry manager, under clause 22(a), makes written notice available to the losing trader; and
  • (b) in any 12 month period at least 50% of the event dates established by the losing trader are no more than 5 business days after the date on which the registry manager, under clause 22(a), makes written notice available to the losing trader.
• (2) For the purpose of determining whether it complies with subclause (1)(b), the losing trader may disregard every event date it has established for an ICP for which, on the date on which the registry manager, under clause 22(a), made written notice available to the losing trader, the losing trader had been responsible for less than 2 months.

• If the losing trader has provided information under clause 3(a)(i) rather than under clause 3(a)(ii), no later than 5 business days after the event date, the losing trader must complete the switch by providing final information to the registry manager, including—
  • (a) the event date; and
  • (b) a switch event meter reading as at the event date for each meter or data storage device that is recorded in the registry with an accumulator type of C and a settlement indicator of Y; and
  • (c) if the switch event meter reading is not a validated meter reading, the date of the last meter reading of the meter or data storage device described in paragraph (b).

• (1) The losing trader and the gaining trader must both use the same switch event meter reading for the event date as determined by the following procedure:
  • (a) if the switch event meter reading provided by the losing trader differs by less than 200 kWh from a value established by the gaining trader, the gaining trader must use the losing trader’s switch event meter reading; or
  • (b) if the switch event meter reading provided by the losing trader differs by 200 kWh or more from a value established by the gaining trader, the gaining trader may dispute the switch event meter reading.
• (2) Despite subclause (1), subclause (3) applies if—
  • (a) the losing trader trades electricity at the ICP through a metering installation with a submission type of non half hour in the registry; and
  • (b) the gaining trader will trade electricity at the ICP through a metering installation with a submission type of half hour in the registry, as a result of the gaining trader’s arrangement to trade electricity with the customer or the embedded generator; and
  • (c) a switch event meter reading provided by the losing trader under subclause (1) has not been obtained from an interrogation of a certified metering installation with an AMI flag of Y in the registry.
• (3) No later than 5 business days after the date on which the registry manager, under clause 22(d), makes written notice of switch completion information available to the gaining trader—
  • (a) the gaining trader may provide the losing trader with a switch event meter reading obtained from an interrogation of a certified metering installation with an AMI flag of Y in the registry; and
  • (b) the losing trader must use that switch event meter reading.

• (1) If a gaining trader disputes a switch event meter reading under clause 6(1)(b), the gaining trader must, no later than 4 months after the date on which the registry manager made written notice under clause 22(d) of switch completion information available to the gaining trader, provide to the losing trader a revised switch event meter reading supported by 2 validated meter readings.
• (2) On receipt of a revised switch event meter reading from the gaining trader under subclause (1), the losing trader must either,—
  • (a) if the losing trader accepts the revised switch event meter reading, or does not respond to the gaining trader, use the revised switch event meter reading; or
  • (b) if the losing trader does not accept the revised switch event meter reading, advise the gaining trader (giving all relevant details) no later than 5 business days after receiving the revised switch event meter reading.

• (1) A losing trader or a gaining trader may give written notice to the other trader that it disputes a switch event meter reading provided under clauses 1 to 6.
• (2) The dispute must be resolved in accordance with the disputes procedure in clause 15.29 (with all necessary amendments).

• (1) A standard switch process applies only when a trader (the “gaining trader”) has an arrangement with a customer or embedded generator to commence trading electricity with the customer or embedded generator at, or to otherwise assume responsibility under clause 11.18(1) for, an ICP for which no trader has an agreement to trade electricity and the gaining trader switch process under clauses 13 to 16 does not apply.
• (1A) This clause and clauses 9 to 12 apply to a switch move process.
• (2) If subpart 2 of Part 4A of the Fair Trading Act 1986 applies to an arrangement described in subclause (1)―
  • (a) the gaining trader must identify the period within which the customer or embedded generator may cancel the arrangement in accordance with section 36M of the Fair Trading Act 1986; and
  • (b) for the purpose of this Schedule, the arrangement is deemed to come into effect on the day after the expiry of the period.

• (1) For each ICP to which a switch relates, the gaining trader must advise the registry manager of the switch request no later than 2 business days after the arrangement to trade electricity with the customer or the embedded generator comes into effect.
• (2) The gaining trader must include in its advice to the registry manager—
  • (a) a proposed event date; and
  • (b) that the switch type is MI; and
  • (c) 1 or more profile codes of a profile at the ICP.

• (1) The trader that is recorded in the registry as being responsible for an ICP that is subject to a switch request (the “losing trader”) must, no later than 5 business days after the date on which the registry manager makes written notice under clause 22(a) of the switch request available to the losing trader,—
  • (a) if the losing trader accepts the event date proposed by the gaining trader, complete the switch by providing to the registry manager—
    • (i) [Revoked]
    • (ia) confirmation of the event date; and
    • (ib) a valid switch response code approved by the Authority; and
    • (ii) final information in accordance with clause 11; or
  • (b) if the losing trader does not accept the event date proposed by the gaining trader, acknowledge the switch request to the registry manager and determine a different event date that—
    • (i) is not earlier than the gaining trader’s proposed event date; and
    • (ii) is no later than 10 business days after the date on which the registry manager, under clause 22(a), made written notice of the switch request available to the losing trader; or
  • (c) request that the switch be withdrawn in accordance with clause 17.
• (2) If the losing trader determines a different event date under subclause (1)(b), the losing trader must, no later than 10 business days after the date on which the registry manager made written notice referred to in subclause (1) available to the losing trader, also complete the switch by providing to the registry manager the information described in subclause (1)(a), but in that case the event date is the event date determined by the losing trader.

• The losing trader must provide final information to the registry manager for the purposes of clause 10(1)(a)(ii), including—
  • (a) the event date; and
  • (b) a switch event meter reading as at the event date for each meter or data storage device that is recorded in the registry with an accumulator type of C and a settlement indicator of Y; and
  • (c) if the switch event meter reading is not a validated meter reading, the date of the last meter reading of the meter or data storage device described in paragraph (b).

• (1) The gaining trader may use the switch event meter reading supplied by the losing trader or may, at its own cost, obtain its own switch event meter reading.
• (2) If the gaining trader elects to use the new switch event meter reading, the gaining trader must advise the losing trader of the new switch event meter reading and the event date to which it refers as follows:
  • (a) if the switch event meter reading established by the gaining trader differs by less than 200 kWh from that provided by the losing trader, both traders must use the switch event meter reading provided by the gaining trader; or
  • (b) if the switch event meter reading provided by the losing trader differs by 200 kWh or more from a value established by the gaining trader, the gaining trader may dispute the switch event meter reading.
• (2A) Despite subclauses (1) and (2), subclause (2B) applies if—
  • (a) the losing trader trades electricity at the ICP through a metering installation with a submission type of non half hour in the registry; and
  • (b) the gaining trader will trade electricity at the ICP through a metering installation with a submission type of half hour in the registry, as a result of the gaining trader’s arrangement with the customer or embedded generator; and
  • (c) a switch event meter reading provided by the losing trader under subclause (1) has not been obtained from an interrogation of a certified metering installation with an AMI flag of Y in the registry.
• (2B) No later than 5 business days after the date on which the registry manager, under clause 22(d), makes written notice,—
  • (a) the gaining trader may provide the losing trader with a switch event meter reading obtained from an interrogation of a certified metering installation with an AMI flag of Y in the registry; and
  • (b) the losing trader must use that switch event meter reading
• (3) If the gaining trader disputes a switch event meter reading under subclause (2)(b), the gaining trader must, no later than 4 months after the date on which the registry manager, under clause 22(d), made written notice of switch completion information available to the gainer trader, provide to the losing trader a revised validated meter reading or a permanent estimate supported by 2 validated meter readings, and the losing trader must either,—
  • (a) no later than 5 business days after receiving the switch event meter reading from the gaining trader, the losing trader, if it does not accept the switch event meter reading, must advise the gaining trader (giving all relevant details), and the losing trader and the gaining trader must use reasonable endeavours to resolve the dispute in accordance with the disputes procedure contained in clause 15.29 (with all necessary amendments); or
  • (b) if the losing trader advises its acceptance of the switch event meter reading received from the gaining trader, or does not provide any response, the losing trader must use the switch event meter reading supplied by the gaining trader.

• (1) A gaining trader switch process applies only when a trader (the “gaining trader”) has an arrangement with a customer or embedded generator to―
  • (a) trade electricity with the customer or embedded generator at an ICP at which another trader (the “losing trader”) trades electricity with the customer or embedded generator, and one of subparagraphs (i) to (iii) applies—
    • (i) at the ICP, the gaining trader will trade electricity through a half-hour metering installation that is a category 3 or higher metering installation; or
    • (ii) at the ICP—
      • (A) the gaining trader will trade electricity through a half-hour metering installation, and in the registry the ICP will have a submission type of half hour and an AMI flag of “N”; and
      • (B) the losing trader trades electricity through a non half-hour metering installation, and in the registry the ICP has a submission type of non half hour and an AMI flag of “N”; or
    • (iii) at the ICP—
      • (A) the gaining trader will trade electricity through a non half-hour metering installation, and the ICP will have a submission type of non half hour in the registry; and
      • (B) the losing trader trades electricity through a half-hour metering installation, and in the registry the ICP has a submission type of half hour and an AMI flag of “N”; or
  • (b) assume responsibility under clause 11.18(1) for an ICP described in subparagraph (a)(i), (a)(ii), or (a)(iii).
• (1A) This clause and clauses 14 to 16 apply to a gaining trader switch process.
• (2) If subpart 2 of Part 4A of the Fair Trading Act 1986 applies to an arrangement described in subclause (1)―
  • (a) the gaining trader must identify the period within which the customer or embedded generator may cancel the arrangement in accordance with section 36M of the Fair Trading Act 1986; and
  • (b) for the purpose of this Schedule, the arrangement is deemed to come into effect on the day after the expiry of the period.