Part 13: Trading arrangements

13.1 Contents of this Part

This Part provides for processes by which―
- (a) purchasers and generators submit and revise bids and offers for electricity, grid owners submit and revise information, ancillary service agents submit and revise reserve offers, the system operator forecasts demand at conforming GXPs, and the system operator collects information to enable schedules to be prepared; and
- (b) the system operator prepares and publishes information from the price-responsive schedules, non-response schedules, and dispatch schedules, and formulates and issues dispatch instructions and dispatch notifications; and
- (c) the clearing manager holds must-run dispatch auctions; and
- (d) the clearing manager produces interim prices; and
- (da) the Authority determines whether each GXP is either a conforming GXP or a non-conforming GXP; and
- (daa) pricing errors are claimed, investigated, and resolved; and
- (dab) interim prices become final prices; and
- (db) the clearing manager calculates constrained off amounts and constrained on amounts; and
- (e) generators may apply to the Authority to have 1 or more generating units approved as—
  - (i) a type A industrial co-generating station; or
  - (ii) a type B industrial co-generating station; and
- (f) information about risk management contracts is disclosed; and
- (fa) disclosing participants prepare and submit spot price risk disclosure statements; and
- (g) the FTR manager prepares and publishes the FTR allocation plan, creates and allocates FTRs, and operates the FTR register; and
- (h) the clearing manager collects and allocates FTR auction revenue; and
- (i) information about FTRs is provided; and
- (j) a device or a group of devices may be approved to be a dispatch-capable load station; and
- (k) purchasers are approved as dispatch notification purchasers; and
- (l) generators are approved as dispatch notification generators.

Compare: Electricity Governance Rules 2003 rule 1 section I part G

Clause 13.1(a) and (b): substituted, on 28 June 2012, by clause 5(a) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.1(b): amended, on 1 November 2022, by clause 11(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.1(d): amended, on 1 November 2022, by clause 11(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.1(daa) and (dab): inserted, on 1 November 2022, by clause 11(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.1(da): inserted, on 28 June 2012, by clause 5(b) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.1(db) and (fa): inserted, on 15 May 2014, by clause 37 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.1(e): substituted, on 27 May 2015, by clause 5 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.1(g)-(i): inserted, on 1 October 2011, by clause 7 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.1(j): inserted, on 15 May 2014, by clause 6 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.1(j): amended, on 1 November 2022, by clause 11(4) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.1(k) and (l): inserted, on 1 November 2022, by clause 11(5) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.2 Misleading, deceptive, or incorrect information

(1) A participant must not disclose to any person any information under this Part that, at the time the information was disclosed, was misleading or deceptive or likely to mislead or deceive when taken in the context of activities under this Part.
(1A) In assessing whether information, at the time of disclosure, is misleading or deceptive or is likely to mislead or deceive, a participant must act reasonably and prudently.
(2) If a participant discovers that information previously disclosed by it to a person under this Part was misleading, deceptive or incorrect, the participant must, as soon as reasonably practicable,—
- (a) disclose further information so that the person is not misled or deceived by the information; or
- (b) disclose corrected information to the person.

Clause 13.2: substituted, on 1 October 2013, by clause 5 of the Electricity Industry Participation (Disclosure Obligations) Code Amendment 2013.

Clause 13.2(2): amended, on 21 June 2018, by clause 4 of the Electricity Industry Participation Code Amendment (Disclosure Obligations) 2018.

13.2A

Participant must make disclosure information readily available

(1) Each participant must make all disclosure information in relation to the participant readily available to the public, free of charge, as soon as reasonably practicable after the participant becomes aware of the information.
(2) Despite subclause (1), a participant is not required to make disclosure information readily available to the public if—
- (a) the disclosure information is excluded Code information; or
- (b) [Revoked]
- (ba) a reasonable person would not expect the disclosure information to be made readily available; or
- (c) the participant is bound by a legal obligation to keep the disclosure information confidential; or
- (d) doing so will be a breach of law; or
- (e) the disclosure information is already readily available to the public; or
- (f) the disclosure information concerns an incomplete proposal or negotiation; or
- (g) the disclosure information comprises matters of supposition or is insufficiently definite to warrant being made readily available to the public; or
- (h) the participant claims legal professional privilege or privilege against self-incrimination in respect of the disclosure information; or
- (i) the disclosure information is a trade secret.
(3) A participant that relies on subclause (2) must, as soon as reasonably practicable, make the disclosure information readily available to the public, free of charge, if subclause (2) ceases to apply to the disclosure information.
(4) If information ceases to be disclosure information, a participant is no longer required to make the information readily available to the public.
(5) A participant that does not make information readily available to the public under this clause must, if required to do so by the Authority,—
- (a) satisfy the Authority that subclause (2) applies to the disclosure information, if the participant relies on subclause (2); or
- (b) satisfy the Authority that the information is not disclosure information.
(6) A participant must not enter into a confidentiality agreement with another person for the purpose of avoiding making disclosure information readily available to the public under this clause.

Clause 13.2A: inserted, on 1 October 2013, by clause 6 of the Electricity Industry Participation (Disclosure Obligations) Code Amendment 2013.

Clause 13.2A(2)(b): revoked, on 21 June 2018, by clause 5(1) of the Electricity Industry Participation Code Amendment (Disclosure Obligations) 2018.

Clause 13.2A(2)(ba): inserted, on 21 June 2018, by clause 5(2) of the Electricity Industry Participation Code Amendment (Disclosure Obligations) 2018.

13.2B

Submission of quarterly disclosure reports by major participants

(1) Each major participant must submit quarterly disclosure reports to the Authority.
(2) Each quarterly disclosure report must contain the following information relating to the major participant’s activities in each quarter beginning 1 January, 1 April, 1 July and 1 October:
- (a) whether or not it held or was aware of any disclosure information to which clause 13.2A(1) applies during the quarter:
- (b) subject to clause 13.2C(2), the means by which it made any such disclosure information readily available to the public during the quarter:
- (c) if during the quarter it decided not to make any such disclosure information readily available to the public:
  - (i) the number of times it decided to do so; and
  - (ii) subject to subclause (3), the disclosure information or a description of the disclosure information; and
  - (iii) the date on which it decided to not make the disclosure information readily available to the public; and
  - (iv) the grounds it relied on under clause 13.2A(2) to not make the disclosure information readily available to the public; and
  - (v) if it subsequently decided to make the disclosure information readily available to the public during the quarter in accordance with clause 13.2A(3), as the ground in clause 13.2A(2) no longer applies, the date on which it decided to make the disclosure information readily available to the public:
- (d) if it decided during a previous quarter not to make any disclosure information readily available to the public, and continues to not make that information readily available to the public in the quarter to which the quarterly disclosure report relates (“the current quarter”):
  - (i) subject to subclause (3), either:
    - (A) the disclosure information or a description of the disclosure information; or
    - (B) a reference to the earlier quarterly disclosure report containing the disclosure information or the description of the disclosure information sufficient to enable the Authority to identify the disclosure information or the description of the disclosure information; and
  - (ii) the grounds it is relying on under clause 13.2A(2) to not make the disclosure information readily available to the public in the current quarter:
- (e) if it decided during a previous quarter not to make any disclosure information readily available to the public but subsequently decided, upon the ground in clause 13.2A(2) no longer applying, to make that disclosure information readily available to the public in the current quarter in accordance with clause 13.2A(3):
  - (i) subject to clause 13.2C(2), the means by which it made any such disclosure information readily available to the public during the current quarter; and
  - (ii) the disclosure information; and
  - (iii) the date it made the disclosure information readily available to the public; and
  - (iv) the previous quarter or quarters it decided to not make the disclosure information readily available to the public:
- (f) whether or not it complied with clause 13.2A during the quarter:
- (g) if it did not comply with clause 13.2A at any time during the quarter, the details of that non-compliance.
(3) If the major participant has not made the disclosure information readily available to the public on one of the grounds set out in clause 13.2A(2)(h), the major participant does not need to provide the disclosure information or a description of it under subclause (2)(c)(ii) or (2)(d)(i) to the Authority if doing so would undermine the ground for not making the disclosure information readily available to the public.
(4) For the purposes of each quarterly disclosure report, each major participant—
- (a) does not breach subclause (2) if it fails to include in a quarterly disclosure report information which it did not believe was disclosure information and there was a reasonable basis for that belief; but
- (b) must treat any information that came within the definition of disclosure information to which clause 13.2A(1) applies at any time during the quarter as disclosure information, even if it ceased to be disclosure information during the quarter.
(5) Subject to clause 13.2E(3), the requirement to provide information under subclause (1)—
- (a) applies despite any legal obligation to keep the disclosure information confidential and shall not be deemed a breach of any such obligation; and
- (b) does not put the major participant in breach of any law.

Clause 13.2B: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2C

Specific requirements under clause 13.2B

(1) Each major participant who provides a description of the disclosure information for the purposes of clause 13.2B(2)(c)(ii) or 13.2B(2)(d)(i) must provide a sufficient description to reasonably enable the Authority to identify whether it is likely that the major participant held or continues to hold—
- (a) information that is disclosure information for the purposes of clause 13.2A(1); and
- (b) reasonable grounds to not make the disclosure information readily available to the public in accordance with clause 13.2A(2).
(2) Each major participant must provide sufficient information to the Authority under clauses 13.2B(2)(b) and 13.2B(2)(e)(i) to enable the Authority to find the disclosure information made readily available to the public during the quarter, including any website addresses.

Clause 13.2C: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2D

Timing and form of quarterly disclosure reports under clause 13.2B

(1) Each major participant must submit the quarterly disclosure report to the Authority together with the following:
- (a) a certification that a person to whom subclause (3)(a) applies considers, on reasonable grounds and to the best of that person’s belief, that the quarterly disclosure report is complete and is a true and correct record of the matters stated in the quarterly disclosure report; and
- (b) a report as to whether or not the major participant has a written policy, procedure and/or process for identifying and determining whether—
  - (i) any information held by the major participant is disclosure information to which clause 13.2A(1) applies; and
  - (ii) there are grounds under clause 13.2A(2) for not making that information readily available to the public.
(2) Each major participant must submit the quarterly disclosure report, the certification required by subclause (1)(a) and the report required by subclause (1)(b) to the Authority—
- (a) by the end of the month following the expiry of the quarter to which the quarterly disclosure report relates; and
- (b) in the form specified by the Authority.
(3) Each major participant must ensure that the quarterly disclosure report, the certification required by subclause (1)(a) and the report required by subclause (1)(b) are either—
- (a) signed and dated by a director, or the chief executive officer, or the chief financial officer, or a person holding a position equivalent to one of those positions, of the major participant; or
- (b) otherwise marked in a way specified by the Authority or linked in a way specified by the Authority to evidence such a person’s approval of the quarterly disclosure report and—
  - (i) the certification required by subclause (1)(a); and
  - (ii) the report required by subclause (1)(b).

Clause 13.2D: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2E

Publication of information in quarterly disclosure reports by the Authority

(1) The Authority may publish any information submitted to it in a quarterly disclosure report, the certification required by clause 13.2D(1)(a) and the report required by clause 13.2D(1)(b), provided any such publication does not involve the publication of—
- (a) any disclosure information that the major participant did not make readily available to the public by reason of clauses 13.2A(2)(ba) to 13.2A(2)(d), 13.2A(2)(f) to 13.2A(2)(g), or 13.2A(2)(i); or
- (b) information from which the nature of any disclosure information that the major participant did not make readily available to the public by reason of clauses 13.2A(2)(ba) to 13.2A(2)(d), or 13.2A(2)(f) to 13.2A(2)(i) can reasonably be identified by another participant or member of the public; or
- (c) the grounds relied on under clauses 13.2A(2)(ba) to 13.2A(2)(d), or 13.2A(2)(f) to 13.2A(i) by the major participant to not make disclosure information readily available to the public, where the disclosure of those grounds would enable another participant or a member of the public to reasonably identify the disclosure information.
(2) The limitations in subclause (1)(a) to (1)(c) do not apply if the grounds under clauses 13.2A(2)(ba) to 13.2A(2)(d), or 13.2A(2)(f) to 13.2A(2)(i) no longer apply to the disclosure information.
(3) If a major participant identifies to the Authority that the major participant is bound by a legal obligation to keep confidential any disclosure information provided to the Authority in a quarterly disclosure report or that disclosure of the disclosure information by the major participant would be a breach of law, the Authority is required to keep that disclosure information confidential, except that this subclause does not prevent the use of the disclosure information for the purposes of clause 13.2F(1)(b).
(4) The Authority is not required to keep disclosure information to which subclause (3) applies confidential if it does not consider on reasonable grounds that the major participant is bound by a legal obligation to keep the disclosure information confidential or that disclosure of the disclosure information by the major participant would be a breach of law.

Clause 13.2E: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2F

Use of information in quarterly disclosure reports by the Authority

(1) The Authority may use the disclosure information set out in a quarterly disclosure report—
- (a) as provided in clause 13.2E(1); or
- (b) for the purposes set out in section 16(1)(b), (c), (d), (f), and (g) of the Act.
(2) The Authority may not use any information subject to legal professional privilege for the purposes in subclause (1)(b) above other than for the purpose of monitoring and enforcing compliance with clause 13.2A.
(3) The Authority must comply with section 48(2) and 48(3) of the Act in respect of information that is subject to privilege against self-incrimination.

Clause 13.2F: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2G

Authority may require review of disclosure requirements or certification by independent person

(1) The Authority may, in its discretion, require a review by an independent person of whether a major participant may not have complied with any or all of clauses 13.2B to 13.2D.

Clause 13.2G: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2H

Nomination of independent person to undertake review

(1) If the Authority requires a review under clause 13.2G—
- (a) the Authority must require the major participant to nominate an appropriate independent person to undertake the review; and
- (b) the major participant must provide that nomination within a reasonable timeframe.
(2) The Authority may direct the major participant to appoint the person nominated under subclause (1) or to nominate another person for approval.
(3) If the major participant fails to nominate an appropriate person under subclause (1) within 5 business days, the Authority may direct the major participant to appoint a person of the Authority's choice.
(4) The major participant must appoint a person to undertake the review in accordance with a direction made under subclause (2) or subclause (3).

Clause 13.2H: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2I

Factors relevant to a direction under clause 13.2H

(1) In making the direction required by clause 13.2H(2) or clause 13.2H(3), the Authority may have regard to any factors it considers relevant in the circumstances, including the following:
- (a) the degree of independence between the major participant and the person nominated under clause 13.2H(1);
- (b) the expected quality of the review; and
- (c) the expected costs of the review.
(2) For the purposes of subclause (1)(a), the Authority may have regard to the special definition of independent under clause 1.4 but is not bound by that definition.

Clause 13.2I: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2J

Carrying out of review by independent person

(1) A major participant subject to a review under clause 13.2G must, on request from the person undertaking the review, provide that person with such information as the person reasonably requires in order to carry out the review.
(2) The major participant must provide the information no later than 10 business days after receiving a request from the person for the information.
(3) The major participant must ensure that the person undertaking the review—
- (a) produces a report on whether, in the opinion of that person, the major participant may not have complied with clauses 13.2B to 13.2D (as specified by the Authority) under clause 13.2G; and
- (b) submits the report to the Authority within the timeframe specified by the Authority.
(4) The report produced under subclause (3)(a) must include any other information that the Authority may reasonably require.
(5) Before the report is submitted to the Authority, any identified failure of the major participant to comply with clauses 13.2B to 13.2D must be referred back to the major participant for comment.
(6) The comments of the major participant must be included in the report.
(7) The major participant may require that the person does not provide the Authority with a copy of any information that the major participant has provided to the person in accordance with subclause (2).

Clause 13.2J: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2K

Payment of review costs

(1) If a report received under clause 13.2J(3)(a) establishes, to the Authority's reasonable satisfaction, that the major participant may not have complied with clauses 13.2B to 13.2D (whether or not the Authority appoints an investigator to investigate the alleged breach), the major participant must pay the costs of the person who undertook the review.
(2) Despite subclause (1), if a report establishes, to the Authority's reasonable satisfaction that any non-compliance of the major participant is minor, the Authority may, in its discretion, determine the proportion of the person’s costs that the major participant must pay, and the major participant must pay those costs.
(3) If a report establishes to the Authority's reasonable satisfaction that the major participant has complied with clauses 13.2B to 13.2D, the Authority must pay the person’s costs.

Clause 13.2K: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.2L

Requirement to provide complete and accurate information

(1) In addition to the requirements of clause 13.2, the major participant must take all practicable steps to ensure that the information that the major participant is required to provide to any person under clauses 13.2B to 13.2D is complete and correct.
(2) If a major participant becomes aware that any information the major participant provided under clauses 13.2B to 13.2D does not comply with subclause (1) or clause 13.2, even if the major participant has taken all practicable steps to ensure that the information complies, the major participant must, as soon as practicable, provide such further information as is necessary to ensure that the information provided complies with clauses 13.2B to 13.2D and clause 13.2.

Clause 13.2L: inserted, on 1 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Reporting on Wholesale Market Information Disclosure) 2020.

13.3 Approval process for industrial co-generating stations

A generator may apply to the Authority to have 1 or more generating units approved as—
- (a) a type A industrial co-generating station under clause 8(1)(a)(i) of Schedule 13.4; or
- (b) a type B industrial co-generating station under clause 8(1)(a)(ii) of Schedule 13.4.

Compare: Electricity Governance Rules 2003 rule 3 section I part G

Clause 13.3: substituted, on 27 May 2015, by clause 6 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

13.3A

Approval process for dispatch-capable load stations

(1) A purchaser at a GXP may apply to the system operator for approval for a device or a group of devices at the GXP to be a dispatch-capable load station under Schedule 13.8.
(1A) In addition to subclause (1), a purchaser who intends to operate devices or a group of devices as a dispatch notification purchaser may apply to the system operator for approval for devices or a group of devices located at more than one GXP to be a dispatch-capable load station under Schedule 13.8.
(2) The system operator must consider an application under subclause (1) or (1A) in accordance with Schedule 13.8.
(3) If the system operator approves a device or a group of devices as a dispatch-capable load station following an application by a purchaser under subclause (1) or (1A)—
- (a) the approval is valid until the date the approval is revoked under clause 10 of Schedule 13.8; but
- (b) a device or group of devices in respect of which the approval is granted is not a dispatch-capable load station while its approval is suspended under clause 10 of Schedule 13.8.
(4) The system operator must suspend or revoke an approval for devices or a group of devices located at more than one GXP to be a dispatch-capable load station in accordance with clause 10 of Schedule 13.8 if the purchaser is not, will not in the future or states that it no longer intends to operate as, a dispatch notification purchaser in respect of the relevant dispatch-capable load station.
(5) Where the system operator suspends such an approval under subclause (4), the system operator must continue such suspension until—
- (a) the purchaser re-commences operating as a dispatch notification purchaser in respect of the relevant dispatch capable load station; or
- (b) the system operator revokes the approval for devices or a group of devices located at more than one GXP to be a dispatch-capable load station in accordance with clause 10 of Schedule 13.8.

Clause 13.3A: inserted, on 15 May 2014, by clause 7 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.3A(1A): inserted, on 1 March 2024, by clause 5(1) of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

Clause 13.3A(2): amended, on 1 March 2024, by clause 5(2) of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

Clause 13.3A(3): amended, on 1 March 2024, by clause 5(3) of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

Clause 13.3A(4) and (5): inserted, on 1 March 2024, by clause 5(4) of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

13.3B

Purchasers to advise system operator of changes to dispatch-capable load station

(1) A purchaser to which a dispatch-capable load station approval is granted must advise the system operator of any change to the factors the system operator considered in granting approval, including an intended change of the dispatchable load purchaser.
(2) A purchaser must advise the system operator of the change no later than 10 business days before the change takes effect.
(3) The system operator must consider the change advised and decide whether—
- (a) to amend the approval under clause 10 of Schedule 13.8; or
- (b) to revoke the approval under clause 10 of Schedule 13.8; or
- (c) to suspend the approval under clause 10 of Schedule 13.8.

Clause 13.3B Heading: replaced, on 5 October 2017, by clause 334 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.3B: inserted, on 15 May 2014, by clause 7 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.3C

System operator to publish dispatch-capable load station approval process guidelines

(1) The system operator must publish guidelines for the purpose of assisting purchasers to obtain approval under clause 13.3A.
(2) Before publishing the guidelines under subclause (1), the system operator must consult with participants on the guidelines.
(3) To avoid doubt, consultation undertaken before the commencement of this clause is to be treated as the consultation required for the purpose of subclause (2).

Clause 13.3C: inserted, on 15 May 2014, by clause 7 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.3D

Access to WITS

(1) A participant that requires access to WITS must apply to the Authority to have access to WITS.
(2) The Authority must specify and publish the terms and conditions that apply to participants that are granted access to WITS.
(3) For the avoidance of doubt, the terms and conditions specified and published under subclause (2) apply to a participant that has access to WITS as at 18 April 2019.
(4) If the Authority grants a participant's application—
- (a) the WITS manager must provide the participant with access to WITS in accordance with the terms and conditions specified and published by the Authority under subclause (2):
- (b) the participant must comply with the terms and conditions specified and published by the Authority under subclause (2), including any amendments under subclause (5):
- (c) the Authority may restrict or suspend a participant's access to WITS if the participant does not comply with those terms and conditions, even though such a restriction or suspension may affect a participant's ability to meet its obligations under this Code.
(5) The Authority may, from time to time, specify and publish amendments to the terms and conditions under which the Authority grants access to WITS. Such amendments will apply—
- (a) to those participants the Authority has already granted access to WITS; and
- (b) to future applications for access to WITS.
(6) The Authority must consult with the participants referred to in subclause (5)(a) on any proposed amendments to the terms and conditions specified and published by the Authority under subclause (2).
(7) The terms and conditions specified and published by the Authority under subclause (2), including any amendments specified under subclause (5), replace any agreements to access WITS, which the participant and the WITS manager had agreed prior to 18 April 2019.

Clause 13.3D: inserted, on 18 April 2019, by clause 5 of the Electricity Industry Participation Code Amendment (Terms and Conditions for Access to Registry and WITS) 2019.

Clause 13.3D(6): amended, on 1 March 2024, by clause 68 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.3E

Approval process for dispatch notification purchasers

(1) A purchaser may apply to become a dispatch notification purchaser by applying to the system operator for approval of the relevant device or group of devices as a dispatch-capable load station under Schedule 13.8.
(2) If the system operator receives an application under subclause (1), the system operator must consider the application in accordance with Schedule 13.8.
(2A) The system operator may only approve an application if the Authority has confirmed to the system operator that the applicant will be able to comply with clause 13.82B.
(3) If the system operator approves a purchaser's application to become a dispatch notification purchaser,—
- (a) the purchaser is a dispatch notification purchaser in relation to the dispatch-capable load station to which the application relates; and
- (b) the approval is valid until the date on which the approval is revoked under clause 10 of Schedule 13.8; but
- (c) the purchaser in respect of which approval is granted is not a dispatch notification purchaser while approval for the relevant dispatch-capable load station is suspended under clause 10 of Schedule 13.8.
(4) The system operator may suspend or revoke an approval for a dispatch notification purchaser in accordance with clause 10 of Schedule 13.8 if the purchaser has repeatedly submitted revised bids under clause 13.19C(1) such that it is no longer appropriate for the purchaser to remain a dispatch notification purchaser, taking into account any criteria set out in the policy statement.

Clause 13.3E: inserted, on 1 November 2022, by clause 12 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.3E(2A): inserted, on 1 March 2024, by clause 6 of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

13.3F

Approval process for dispatch notification generators

(1) A generator may, by notice in writing to the system operator, apply to become a dispatch notification generator in respect of a generating station that exports less than 30 MW to the grid or a local network.
(2) The notice must specify the generating station in respect of which the generator wishes to be a dispatch notification generator.
(3) The system operator must approve an application received under subclause (1) if the application—
- (a) relates to a generating station that exports less than 30 MW to the grid or a local network; and
- (b) meets any criteria for approval set out in the policy statement.
(3A) Notwithstanding subclause (3), the system operator may only approve an application received under subclause (1) if the Authority has confirmed to the system operator that the applicant will be able to comply with clause 13.82B.
(4) The system operator may revoke an approval for a dispatch notification generator if—
- (a) the generator no longer meets the approval requirements; or
- (b) the generator has repeatedly submitted revised offers under clause 13.19C(2) such that it is no longer appropriate for the generator to remain a dispatch notification generator, taking into account any criteria set out in the policy statement.

Clause 13.3F: inserted, on 1 November 2022, by clause 12 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.3F(3A): inserted, on 1 March 2024, by clause 7 of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

Subpart 1—Bids and offers

13.4 Contents of this subpart

This subpart provides for processes to facilitate trading by which―
- (a) bids and offers for electricity are submitted and revised by generators and purchasers; and
- (b) information from the grid owners is submitted and revised; and
- (c) reserve offers are submitted and revised by ancillary service agents; and
- (d) the system operator collects the information referred to in this subpart; and
- (e) information about bids and offers is to be made available.

Compare: Electricity Governance Rules 2003 rule 1 section II part G

13.5 Bids and offers must be lawful

A purchaser, generator or ancillary service agent must not make or maintain a bid, offer or reserve offer if the purchaser or generator or ancillary service agent knows or ought reasonably to know that acting in accordance with the bid, offer or reserve offer would contravene any law.

Compare: Electricity Governance Rules 2003 rule 2 section II part G

Clause 13.5: amended, on 28 June 2012, by clause 6 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.5A

Conduct in relation to generators' offers and ancillary service agents' reserve offers

(1) In the spot market –
- (a) it is expected that offers and reserve offers will generally be subject to competitive disciplines such that no party has significant market power;
- (b) however, there may be locations where, or periods when, one or more generators, or ancillary service agents, as the case may be, has significant market power.
(2) Accordingly –
- (a) where a generator submits or revises an offer, that offer must be consistent with the offer that the generator, acting rationally, would have made if no generator could exercise significant market power at the point of connection to the grid and in the trading period to which the offer relates;
- (b) where an ancillary service agent submits or revises a reserve offer, that offer must be consistent with the reserve offer that the ancillary service agent, acting rationally, would have made if no ancillary service agent could exercise significant market power at the point of connection to the grid and in the trading period to which the reserve offer relates.
(3) For the purposes of this clause –
- (a) market power becomes significant when its exercise would have a net adverse impact on economic efficiency, which includes productive, allocative and dynamic efficiency;
- (b) “spot market” has the same meaning as wholesale market except that it excludes the hedge market for electricity (including the market for FTRs).

Clause 13.5A: inserted, on 17 July 2014, by clause 5 of the Electricity Industry Participation Code Amendment (Pivotal Supply) 2014.

Clause 13.5A(2): amended, on 29 June 2017, by clause 5 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.5A: replaced, on 30 June 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Trading Conduct Provisions) 2021.

13.5B

[Revoked]

Clause 13.5B: inserted, on 17 July 2014, by clause 5 of the Electricity Industry Participation Code Amendment (Pivotal Supply) 2014.

Clause 13.5B(1)(b) and (3)(b): amended, on 29 June 2017, by clause 6 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.5B: revoked, on 30 June 2021, by clause 6 of the Electricity Industry Participation Code Amendment (Trading Conduct Provisions) 2021.

Bids and offer preparation

13.6 Requirements for generators when submitting offers

(1) Each generator with a point of connection to the grid, and each embedded generator required by the system operator to submit an offer under clause 8.25(5), must—
- (a) submit to the system operator an offer for each trading period in the schedule period, under which the generator is prepared to sell electricity to the clearing manager; and
- (b) ensure that the system operator receives an offer at least 71 trading periods before the beginning of the trading period to which the offer relates.
(2) Despite subclause (1), a generator must give at least 5 business days' notice in writing to the system operator and the clearing manager before the generator makes an offer for the 1st time in respect of the generating plant that is the subject of the offer.
(3) The notice must state—
- (a) the point of connection to the grid at which electricity generated by the generator is sold to the clearing manager under clause 14.3 or 14.4; and
- (b) whether the generating plant is an intermittent generating station.
(4) A generator must comply with any request from the system operator for information concerning generating plant that is the subject of a notice under subclause (2) if the system operator requires the information for the purposes of scheduling and dispatch in accordance with this Code.
(5) Despite subclause (1), if a generator intends to permanently cease to submit offers to the system operator in respect of any generating plant, the generator must give at least 5 business days' notice in writing to the system operator and the clearing manager.

Compare: Electricity Governance Rules 2003 rules 3.1 and 3.2 section II part G

Clause 13.6(1)-(3): substituted, on 28 June 2012, by clause 7 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.6(4): amended, on 23 February 2015, by clause 75 of the Electricity Industry Participation Code Amendment (Distributed Generation) 2014.

Clause 13.6: substituted, on 29 June 2017, by clause 7 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.6(2): amended, on 1 March 2024, by clause 69(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.6(5): amended, on 1 March 2024, by clause 69(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.7 Purchaser to submit bids for dispatch-capable load station

(1) This clause applies to each dispatchable load purchaser.
(2) Unless the dispatchable load purchaser relies on clause 13.8A, the dispatchable load purchaser must submit to the system operator for each of its dispatch-capable load stations for each trading period in the schedule period—
- (a) a nominated non-dispatch bid; or
- (b) a nominated dispatch bid.
(3) A nominated bid submitted under subclause (2) must represent a reasonable estimate of the total quantity of electricity the dispatchable load purchaser will purchase—
- (a) for the dispatch-capable load station; and
- (b) for the trading period; and
- (c) at the prices specified in the nominated bid.
(4) A dispatch notification purchaser operating a dispatch-capable load station consisting of devices or a group of devices located at more than one GXP must submit nominated bids at—
- (a) the primary GXP assigned by the system operator under clause 6(1A)(a) of Schedule 13.8; or
- (b) if the system operator gives reasonable notice requiring the dispatch notification purchaser to submit nominated bids at an alternative GXP specified by the system operator under clause 6(1A)(b) of Schedule 13, that alternative GXP for the period specified in the notice.

Compare: Electricity Governance Rules 2003 rules 3.3 and 3.4 section II part G

Clause 13.7 Heading and (1): substituted, on 28 June 2012, by clause 8(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.7(1A) and (1B): inserted, on 28 June 2012, by clause 8(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.7(2): amended, on 28 June 2012, by clause 8(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.7: substituted, on 15 May 2014, by clause 8 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.7(4): inserted, on 1 March 2024, by clause 8 of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

13.7AA

Purchaser to submit bids for non-dispatch-capable load

(1) This clause applies to each purchaser that—
- (a) purchases non-dispatch-capable load; and
- (b) in relation to a nominated bid, does not rely on clause 13.8A.
(2) The purchaser—
- (a) must, if it purchases non-dispatch-capable load at a non-conforming GXP, submit to the system operator for each trading period in the schedule period a nominated non-dispatch bid that represents a reasonable estimate of the total non-dispatch-capable load that the purchaser will purchase—
  - (i) at the GXP; and
  - (ii) for the trading period; and
  - (iii) at the prices specified in the nominated non-dispatch bid; and
- (b) may, if it purchases non-dispatch-capable load at a conforming GXP, submit to the system operator for a trading period a difference bid that represents a reasonable estimate of an increase or decrease in the purchaser's usual non-dispatch-capable load purchased—
  - (i) at the GXP; and
  - (ii) for the trading period; and
  - (iii) at the prices specified in the difference bid.

Clause 13.7AA: inserted, on 15 May 2014, by clause 8 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.7AB

Timeframe for submitting bids to system operator

(1) Each purchaser that submits a nominated bid to the system operator must submit the nominated bid at least 71 trading periods before the beginning of the trading period to which the nominated bid applies.
(2) Each purchaser that submits a difference bid to the system operator must submit the difference bid at least 4 trading periods before the beginning of the trading period to which the difference bid applies.

Clause 13.7AB: inserted, on 15 May 2014, by clause 8 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.7AC

Submitting bid for first time

(1) Despite anything in this Code, a purchaser must give at least 5 business days’ notice in writing to the system operator and the clearing manager before the purchaser submits a bid for the first time.
(2) The system operator may request from a purchaser information—
- (a) about the purchaser; and
- (b) that the system operator requires for the purposes of scheduling and dispatch in accordance with this Code.
(3) A purchaser must comply with a request made under subclause (2).

Clause 13.7AC: inserted, on 15 May 2014, by clause 8 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.7AD

Submitting bid for last time

Despite anything in this Code, if a purchaser intends to permanently cease to provide bids to the system operator, the purchaser must give at least 5 business days' notice in writing to the system operator and the clearing manager.

Clause 13.7AD: inserted, on 29 June 2017, by clause 8 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.7AD: amended, on 1 November 2022, by clause 13 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.7A

System operator to prepare forecast of non-dispatch-capable load at conforming GXPs

(1) The system operator must prepare a forecast of non-dispatch-capable load for each conforming GXP for each trading period in a schedule period.
(2) The system operator must—
- (a) disclose to the Authority a description of the processes and methodology it uses to prepare the forecast under subclause (1); and
- (b) publish and keep published, either—
  - (i) the description it disclosed to the Authority under paragraph (a); or
  - (ii) a summary of the processes and methodology it uses to prepare the forecast under subclause (1).
(3) Despite subclause (2), the system operator is required to disclose or publish information under subclause (2) only if the information—
- (a) is available to the system operator; and
- (b) is not confidential or commercially sensitive.

Clause 13.7A: inserted, on 28 June 2012, by clause 9 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.7A Heading: amended, on 15 May 2014, by clause 9(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.7A: amended, on 15 May 2014, by clause 9 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.7A(2)(b): amended, on 5 October 2017, by clause 335(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.7A(3): amended, on 5 October 2017, by clause 335(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.7B

Authority may request system operator to report on accuracy of forecasts of non-dispatch-capable load at conforming GXPs

(1) The Authority may, from time to time, request the system operator to report to the Authority on the accuracy of the forecast that it prepares under clause 13.7A(1).
(2) A request—
- (a) must specify the period that must be covered by the report; and
- (b) must specify a reasonable date by which the system operator must provide the report; and
- (c) must be made no more frequently than once per calendar month, unless the system operator agrees otherwise.
(3) The system operator must comply with a request made under this clause.

Clause 13.7B: inserted, on 28 June 2012, by clause 9 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.7B Heading: amended, on 15 May 2014, by clause 10(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.7B(1): amended, on 15 May 2014, by clause 10(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.8 Deemed offers

(1) This clause applies if, on any trading day ("the current trading day"), a generator has not submitted an offer for a trading period in the trading day following the next trading day.
(2) A generator is deemed to have submitted, for that trading period, an offer that is the same as the offer the generator made for the corresponding trading period on the current trading day, and clause 13.9A applies accordingly.
(3) A deemed offer under subclause (2) applies until the generator revises the offer in accordance with clauses 13.17 to 13.19.

Compare: Electricity Governance Rules 2003 rule 3.5 section II part G

Clause 13.8: substituted, on 28 June 2012, by clause 10 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.8(3): amended, on 15 May 2014, by clause 11 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.8(2): amended, on 29 June 2017, by clause 9(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.8(3): amended, on 29 June 2017, by clause 9(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.8A

Deemed nominated bids

(1) This clause applies if, on any trading day (“the current trading day”), a purchaser has not submitted a nominated bid for a trading period in the trading day following the next trading day.
(2) A purchaser is deemed to have submitted, for that trading period, a nominated bid that is the same as the nominated bid the purchaser made for the corresponding trading period on the current trading day.
(3) A deemed nominated bid under subclause (2) applies until the purchaser revises the nominated bid in accordance with clause 13.19A.
(4) A purchaser must ensure that each of its deemed nominated bids under this clause,—
- (a) if it is a nominated bid for a dispatch-capable load station, represents a reasonable estimate of the total quantity of electricity that the purchaser will purchase for the dispatch-capable load station at the specified prices for the trading period; or
- (b) if it is a nominated bid for non-dispatch-capable load, represents a reasonable estimate of the non-dispatch-capable load that the purchaser will purchase at the GXP at the specified prices for the trading period.

Clause 13.8A: inserted, on 28 June 2012, by clause 10 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.8A(2) & (3): amended, on 15 May 2014, by clause 12(a) & (b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.8A(4): inserted, on 15 May 2014, by clause 12(c) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.8A(3): amended, on 29 June 2017, by clause 10 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.8B

Deemed reserve offers

(1) This clause applies if, on a trading day ("the current trading day"), an ancillary service agent who provides instantaneous reserves has not submitted a reserve offer for a trading period in the trading day following the next trading day.
(2) An ancillary service agent is deemed to have submitted, for that trading period, a reserve offer that is the same as the reserve offer the ancillary service agent made for the corresponding trading period on the current trading day, and clause 13.38(2)(c) applies accordingly.
(3) A deemed reserve offer under subclause (2) applies until the ancillary service agent revises the reserve offer in accordance with clauses 13.46 to 13.49.

Clause 13.8B: inserted, on 1 November 2012, by clause 4 of the Electricity Industry Participation (Part 13 Minor Amendments) Code Amendment 2012.

Clause 13.8B(3): amended, on 29 June 2017, by clause 11 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.9 Information that offers must contain

Each offer submitted by a generator must―
- (a) other than for intermittent generators, type A co-generators, and type B co-generators, contain all information required by Form 1 in Schedule 13.1; and
- (b) [Revoked]
- (c) if the offer is submitted by an intermittent generator for an intermittent generating station,―
  - (i) contain the information required by Form 2 in Schedule 13.1; and
  - (ii) [Revoked]
  - (iii) [Revoked]
- (d) if the offer is submitted by a type A co-generator for a type A industrial co-generating station or by a type B co-generator for a type B industrial co-generating station,―
  - (i) contain the information required by Form 3 in Schedule 13.1; and
  - (ii) have a maximum of 2 price bands for each trading period; and
  - (iii) specify a price of either $0.00 (in accordance with clause 13.116) or $0.01 for the price band.

Compare: Electricity Governance Rules 2003 rule 3.6 section II part G

Clause 13.9(a): amended, on 27 May 2015, by clause 7(1) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.9(b): revoked, on 29 June 2017, by clause 12 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.9(c)(ii) and (iii): revoked, at 12.00 pm on 19 September 2019, by clause 5 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.9(d): amended, on 27 May 2015, by clause 7(2) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

13.9A

Offer not to exceed capability

(1) The total MW specified in each offer submitted by a generator must, in relation to the generating plant that is the subject of the offer, not exceed the total MW that the generator expects to be capable of generating at the relevant point of connection to the grid for the relevant trading period.
(2) Subclause (1) does not apply to an intermittent generator.

Clause 13.9A: inserted, on 29 June 2017, by clause 13 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.9A(2): inserted, at 12.00 pm on 19 September 2019, by clause 6 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.9B

Offer requirements for intermittent generators

Each offer submitted by an intermittent generator must, in relation to the generating plant that is the subject of the offer,—
- (a) not exceed the nameplate capacity of the generating plant; and
- (b) include a forecast of generation potential for the trading period to which the offer relates.

Clause 13.9B: inserted, at 12.00 pm on 19 September 2019, by clause 7 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.10 Generators must specify units in offers

Each offer submitted by a generator must―
- (a) be specific to individual generating units for generating plant in respect of which electricity is offered by that generator that cannot synchronise and come up to minimum load within the duration of a trading period; or
- (b) be specific to individual generating stations for other generating plant in respect of which electricity is offered by that generator.

Compare: Electricity Governance Rules 2003 rule 3.7 section II part G

13.11 Offers may be made by unit or plant

(1) Despite clause 13.10, a generator, other than an intermittent generator, may offer electricity in respect of any generating plant on a unit basis. A generator may exercise this option by giving the system operator at least 5 business days’ notice in writing of the exercise of the option. The system operator must, during the 5 business day period, make any necessary changes to the scheduling software.
(2) If a generator has offered electricity in respect of any generating plant on a unit basis in accordance with subclause (1), it may change to submitting offers in accordance with clause 13.10. Such a change may be effected by giving the system operator at least 5 business days’ notice in writing of the change. The system operator must, during the 5 business day period, make any necessary changes to the scheduling software.

Compare: Electricity Governance Rules 2003 rule 3.8 section II part G

13.12 Offers may contain up to 5 price bands

Subject to clause 13.9(d), an offer submitted by a generator may have a maximum of 5 price bands for each trading period, with the 1st price band containing the lowest price offered, and each subsequent band having a higher price than the band preceding it.

Compare: Electricity Governance Rules 2003 rule 3.9 section II part G

Clause 13.12: amended, at 12.00 pm on 19 September 2019, by clause 8 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.13 Information to be contained in bids

(1) A purchaser must ensure that each of its nominated bids—
- (a) contains all information required by Form 4 in Schedule 13.1; and
- (aa) if it is a nominated bid for a dispatch-capable load station, specifies whether it is—
  - (i) a nominated dispatch bid; or
  - (ii) a nominated non-dispatch bid.
- (b) [Revoked]
- (c) [Revoked]
(1A) [Revoked]
(2) A purchaser must ensure that each of its difference bids contains all information required by Form 4A in Schedule 13.1.

Compare: Electricity Governance Rules 2003 rule 3.10 section II part G

Clause 13.13: substituted, on 28 June 2012, by clause 11 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.13(1)(aa): inserted, on 15 May 2014, by clause 13(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.13(1)(b): revoked, on 15 May 2014, by clause 13(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.13(1)(c): inserted, on 3 November 2016, by clause 4(1) of the Electricity Industry Participation Code Amendment (Dispatchable Demand During Tight Market Conditions) 2016.

Clause 13.13(1)(c): revoked, on 1 November 2022, by clause 14(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.13(1A): inserted, on 3 November 2016, by clause 4(2) of the Electricity Industry Participation Code Amendment (Dispatchable Demand During Tight Market Conditions) 2016.

Clause 13.13(1A): revoked, on 1 November 2022, by clause 14(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.13(2): substituted, on 15 May 2014, by clause 13(c) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.14 Nominated bids may contain up to 10 price bands

(1) A nominated bid submitted by a purchaser may have a maximum of 10 price bands for each trading period.
(2) The price in each band must decrease progressively from band to band as the aggregate quantity increases.
(3) The highest price band in each nominated bid is deemed to start at a quantity of 0.

Compare: Electricity Governance Rules 2003 rule 3.11 section II part G

Clause 13.14: substituted, on 28 June 2012, by clause 12 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.14A

Difference bids may contain up to 10 price bands

A difference bid submitted by a purchaser may have a maximum of—
- (a) 5 price bands for each trading period representing the purchaser’s progressive increase in its usual quantity of electricity demanded for the trading period. The price in bands 2 to 5 must, in each case, be lower than the price in the preceding band; and
- (b) 5 price bands for each trading period representing the purchaser’s progressive decrease in its usual quantity of electricity demanded for the trading period. The price in bands 2 to 5 must, in each case, be higher than the price in the preceding band.

Clause 13.14A: inserted, on 28 June 2012, by clause 13 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.15 How price is to be specified in bids or offers

Prices in bids or offers must be expressed in dollars and whole cents per MWh excluding any GST. There is no upper limit on the prices that may be specified and the lower limit is $0.00/MWh, subject to clauses 13.9(d), 13.24, 13.26, and 13.116.

Compare: Electricity Governance Rules 2003 rule 3.12 section II part G

Clause 13.15: amended, at 12.00 pm on 19 September 2019, by clause 9 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.16 How quantity is to be specified in bids or offers

For each price band, a bid or offer must specify a quantity expressed in MW to not more than 3 decimal places. The minimum quantity that may be bid or offered in a price band for a trading period is 0.000 MW.

Compare: Electricity Governance Rules 2003 rule 3.13 section II part G

Clause 13.16: amended, on 21 September 2012, by clause 18 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

13.17 Offers may be revised

(1) Subject to subclauses (2) to (4), a generator may revise an offer at any time before the end of the trading period to which the offer relates by submitting a new offer to the system operator.
(2) A generator must not revise any of its offer prices during a gate closure period.
(3) A generator must not revise the MW specified in any price band in an offer during a gate closure period, unless clause 13.18(1), 13.18(1A), 13.19 or 13.19C applies.
(4) A generator must not revise any of the following offer parameters during a gate closure period, unless clause 13.19 applies:
- (a) ramp rates:
- (b) maximum output (including overload).

Compare: Electricity Governance Rules 2003 rule 3.14 section II part G

Clause 13.17 Heading: amended, on 28 June 2012, by clause 14(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.17(1): amended, on 28 June 2012, by clause 14(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.17(1): amended, on 1 November 2022, by clause 15(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.17: substituted, on 29 June 2017, by clause 14 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.17(3): amended, at 12.00 pm on 19 September 2019, by clause 10 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.17(3): amended, on 1 November 2022, by clause 15(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.18 When revised offer to be submitted

(1) A generator, other than an intermittent generator, must immediately submit a revised offer to the system operator if the total MW specified in an offer exceeds, by more than 5 MW, the total MW that the generator expects to be capable of generating at the relevant point of connection to the grid for the relevant trading period.
(1A) A generator, other than an intermittent generator, may submit a revised offer to the system operator if the total MW specified in an offer exceeds, by 5 MW or less, the total MW that the generator expects to be capable of generating at the relevant point of connection to the grid for the relevant trading period.
(1B) The submission of a revised offer under subclause (1) or subclause (1A) does not relieve the generator of liability for breach of any other provision of this Code.
(2) [Revoked]
(3) [Revoked]

Compare: Electricity Governance Rules 2003 rules 3.15 and 3.16 section II part G

Clause 13.18 Heading: amended, on 28 June 2012, by clause 15(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.18 Heading: amended, on 29 June 2017, by clause 15(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.18(1): amended, on 28 June 2012, by clause 15(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.18(1): replaced, on 29 June 2017, by clause 15(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.18(1): amended, at 12.00 pm on 19 September 2019, by clause 11(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.18(1): amended, on 1 November 2022, by clause 16(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.18(1A): inserted, on 28 June 2012, by clause 15(3) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.18(1A): replaced, on 29 June 2017, by clause 15(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.18(1A): amended, at 12.00 pm on 19 September 2019, by clause 11(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.18(1B): inserted, on 29 June 2017, by clause 15(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.18(2): amended, on 28 June 2012, by clause 15(4) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.18(2): revoked, on 29 June 2017, by clause 15(4) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.18(3): inserted, on 29 June 2017, by clause 15(5) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.18(3): replaced, at 12.00 pm on 19 September 2019, by clause 11(3) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.18(3): revoked, on 1 November 2022, by clause 16(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.18A

Intermittent generators to submit revised forecast of generation potential every trading period in last 2 hours

(1) During the 2 hours immediately preceding the trading period to which an offer relates, each intermittent generator must submit to the system operator a revised forecast of generation potential for the relevant intermittent generating station for the trading period at a frequency of at least 1 revised forecast per trading period.
(2) A revised forecast of generation potential submitted under subclause (1) must be based on a resource persistence model, unless otherwise agreed with the Authority.
(3) For the purposes of this clause, a resource persistence model means a method for producing a forecast of the intermittent generator's generation for a trading period, in MW, that is derived from the expected availability and capability of generating plant forming all or part of the relevant intermittent generating station, on the assumption that the variable resource conditions at the time at which the forecast is prepared will persist throughout the trading period to which the forecast relates.

Clause 13.18A: inserted, on 29 June 2017, by clause 16 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.18A: replaced, at 12.00 pm on 19 September 2019, by clause 12 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.18A(3): amended, on 20 March 2020, by clause 5 of the Electricity Industry Participation Code Amendment (Broadening Definitions of Generating Unit and Intermittent Generating Station) 2020.

13.19 When revised offers may be submitted during gate closure period

(1) A generator, other than an intermittent generator, may submit a revised offer to the system operator during a gate closure period if—
- (a) the revision is necessary due to a bona fide physical reason; or
- (b) the system operator issues a formal notice under clause 5 of Technical Code B of Schedule 8.3; or
- (c) a bona fide physical reason that made a revision necessary under paragraph (a) ceases to exist sooner than was expected at the time it arose, and—
  - (i) the 1st trading period after the original bona fide physical reason ceases to exist is within 24 hours after the circumstances that constituted the original bona fide physical reason arose; and
  - (ii) the total change in MW specified in the offer that is revised as a result of the bona fide physical reason ceasing to exist is the same or less than the total change in MW specified in the offer that was made as a result of the original bona fide physical reason.
(2) A generator that submits a revised offer under subclause (1)(c) must do so as soon as possible after the relevant bona fide physical reason ceases to exist.

Compare: Electricity Governance Rules 2003 rule 3.17 section II part G

Clause 13.19 Heading: amended, on 28 June 2012, by clause 16(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.19: amended, on 28 June 2012, by clause 16(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.19: substituted, on 29 June 2017, by clause 17 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19(1): amended, at 12.00 pm on 19 September 2019, by clause 13 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.19AA

Limitations on revised offers

A generator that submits a revised offer under clauses 13.18(1), 13.18(1A), or 13.19(1) during a gate closure period must ensure that—
- (a) the revised offer only differs from the original offer to the extent necessary to ensure that the MW specified in the revised offer is the MW that the generator expects to be capable of generating at the relevant point of connection to the grid for the relevant trading period; and
- (b) the revised offer complies with the following:
  - (i) the reduction in MW specified in the revised offer must be first deducted from the MW offered in the highest price band:
  - (ii) if the reduction in MW exceeds the MW in the highest price band, the remainder must be deducted from the price bands below the highest, in descending order as the MW in each price band is reduced to zero, until all of the reduction is reflected in the revised offer.

Clause 13.19AA: inserted, on 29 June 2017, by clause 17 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.19A

Bids may be revised

(1) Each purchaser may, at any time before the end of a trading period in respect of which a bid is made,—
- (a) revise any of its bid prices or the MW specified in any price band in a bid for any trading period by submitting a new bid to the system operator; or
- (aa) revise a nominated bid—
  - (i) from being a nominated dispatch bid to being a nominated non-dispatch bid; or
  - (ii) from being a nominated non-dispatch bid to being a nominated dispatch bid.
- (b) [Revoked]
(1A) Despite subclause (1), a dispatchable load purchaser must not do any of the following during a gate closure period:
- (a) revise the price of a nominated dispatch bid:
- (b) revise the MW specified in any price band in a nominated dispatch bid, unless subclause (1B) or clause 13.19B applies.
- (c) revise a nominated non-dispatch bid to being a nominated dispatch bid, unless the system operator declares a grid emergency in accordance with Technical Code B of Schedule 8.3.
(1B) A dispatchable load purchaser may revise the MW specified in any price band in a nominated dispatch bid during a gate closure period if—
- (a) the revision is necessary due to a bona fide physical reason; or
- (b) the system operator has declared a grid emergency; or
- (c) a bona fide physical reason that made a revision necessary under paragraph (a) ceases to exist sooner than was expected at the time it arose, and—
  - (i) the 1st trading period after the original bona fide physical reason ceases to exist is within 24 hours after the circumstances that constituted the original bona fide physical reason arose; and
  - (ii) the total change in MW specified in the nominated dispatch bid that is revised as a result of the bona fide physical reason ceasing to exist is the same or less than the total change in MW specified in the nominated dispatch bid that was made as a result of the original bona fide physical reason.
(2) [Revoked]
(3) [Revoked]
(3A) [Revoked]
(3B) [Revoked]
(4) [Revoked]
(5) [Revoked]
(6) [Revoked].

Clause 13.19A Heading: amended, on 29 June 2017, by clause 18(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19A: inserted, on 28 June 2012, by clause 17 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.19A(1): amended, on 29 June 2017, by clause 18(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19A(1): amended, on 1 November 2022, by clause 17(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.19A(1)(a): amended, on 29 June 2017, by clause 18(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19A(1)(aa): inserted, on 15 May 2014, by clause 14(1) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.19A(1)(aa)(ii): amended, on 29 June 2017, by clause 18(4) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19A(1)(b): revoked, on 29 June 2017, by clause 18(5) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19A(1A) and (1B): inserted, on 29 June 2017, by clause 18(6) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19A(1A)(c): inserted, on 1 November 2022, by clause 17(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.19A(1B)(b): amended, on 1 November 2022, by clause 17(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.19A(2)(ba): inserted, on 15 May 2014, by clause 14(2) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.19A(3)(a)(ia): inserted, on 15 May 2014, by clause 14(3) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.19A(3)(b): substituted, on 15 May 2014, by clause 14(4) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.19A(3)(c): amended, on 15 May 2014, by clause 14(5) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.19A(2), (3), (4) and (5): revoked, on 29 June 2017, by clause 18(7) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19A(3A): inserted, on 1 December 2015, by clause 4 of the Electricity Industry Participation Code Amendment (Dispatchable Demand: Late Bid Revisions) 2015.

Clause 13.19A(3B): inserted, on 29 June 2017, by clause 18(8) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19A(6): inserted, on 29 June 2017, by clause 18(9) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clauses 13.19A(3A), (3B) and (6): revoked, on 1 November 2022, by clause 17(4) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.19B

Bids must be revised

(1) Before the end of the trading period to which a nominated bid relates, the purchaser that submitted the nominated bid must immediately submit a revised nominated bid in respect of MW to the system operator if the purchaser expects, or ought reasonably to expect, that the MW it is likely to purchase at the prices indicated in the nominated bid will,—
- (a) if the nominated bid is a nominated non-dispatch bid, differ from the MW specified in the nominated bid by more than the lesser of—
  - (i) 20 MW; and
  - (ii) 20% of the nominated bid MW; or
- (b) if the nominated bid is a nominated dispatch bid, differ from the MW specified in the nominated bid by more than the lesser of—
  - (i) 10 MW; and
  - (ii) 10% of the nominated bid MW.
(2) Despite subclause (1), a purchaser is not required to submit a revised nominated bid in respect of MW if the expected change in MW is less than 5 MW.

Clause 13.19B: inserted, on 29 June 2017, by clause 19 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.19B(1): amended, on 1 November 2022, by clause 18 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.19C

Dispatch notification purchasers and dispatch notification generators to submit revised bids and offers in certain circumstances

(1) If a dispatch notification purchaser does not intend to comply with a nominated dispatch bid that is the subject of a dispatch notification, the dispatch notification purchaser must immediately revise the nominated dispatch bid to be a nominated non-dispatch bid.
(2) If a dispatch notification generator does not intend to comply with an offer that is the subject of a dispatch notification, the dispatch notification generator must immediately revise the MW specified in the offer to 0.
(3) A dispatch notification purchaser that submits a revised bid under this clause—
- (a) is deemed to have submitted a nominated non-dispatch bid for the trading period following the trading period to which the revised bid relates; and
- (b) despite clauses 13.19A and 13.19B, must not submit a revised bid for the trading period to which the revised bid relates or the next trading period.
(4) A dispatch notification generator that submits a revised offer under this clause—
- (a) is deemed to have submitted an offer in which the MW specified in the offer is 0 for the trading period following the trading period to which the revised offer relates; and
- (b) despite clauses 13.17 and 13.19, must not submit a revised offer for the trading period to which the revised offer relates or the next trading period.

Clause 13.19C: inserted, on 1 November 2022, by clause 19 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.20 System operator advised of revised nominated bids or offers in certain circumstances

(1) This clause applies to each purchaser or generator that submits a revised nominated bid or offer in the period commencing 15 minutes before the trading period to which the revised nominated bid or offer relates and ending at the end of that trading period.
(2) Subject to subclause (4), a purchaser or generator that submits a revised nominated bid or offer in the time frame described in subclause (1) must immediately advise the system operator of the revision.
(3) Subclause (2) does not apply to an intermittent generator submitting a revised forecast of generation potential under clause 13.18A.
(4) Despite subclause (2), if the system operator and a purchaser or generator have entered into a written agreement relating to the notification of revised nominated bids or offers, the purchaser or generator—
- (a) must submit a revised nominated bid or offer in accordance with that agreement; but
- (b) if the agreement provides that the purchaser or generator is not required to advise the system operator of revised nominated bids or offers, the purchaser or generator is not required to do so.

Compare: Electricity Governance Rules 2003 rule 3.18 section II part G

Clause 13.20 Heading: amended, on 5 October 2017, by clause 336(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.20: substituted, on 28 June 2012, by clause 18 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.20: substituted, on 29 June 2017, by clause 20 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.20: amended, on 1 November 2022, by clause 20 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.20(1): amended, on 15 May 2014, by clause 15 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.20(2): amended, on 5 October 2017, by clause 336(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.20(3): amended, at 12.00 pm on 19 September 2019, by clause 14 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.21 Authority informed of revised nominated dispatch bid or offer during gate closure period

(1) A dispatchable load purchaser or generator that submits a revised nominated dispatch bid or a revised offer to the system operator during a gate closure period must report each revision to the Authority in writing together with an explanation of the reasons for the revision.
(1A) The dispatchable load purchaser or generator must report the revision to the Authority no later than 1700 hours on the 1st business day following the trading day on which the revision was made.
(1B) Subclauses (1) and (1A) do not apply to an intermittent generator submitting a revised forecast of generation potential under clause 13.18A.
(2) [Revoked]

Compare: Electricity Governance Rules 2003 rules 3.19 and 3.20 section II part G

Clause 13.21 Heading: amended, on 28 June 2012, by clause 19(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.21 Heading: replaced, on 29 June 2017, by clause 21(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.21 Heading: amended, on 5 October 2017, by clause 337 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.21(1): amended, on 28 June 2012, by clause 19(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.21(1): replaced, on 29 June 2017, by clause 21(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.21(2): amended, on 28 June 2012, by clause 19(3) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.21(1A) and (1B): inserted, on 29 June 2017, by clause 21(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.21(1B): amended, at 12.00 pm on 19 September 2019, by clause 15 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.21(2): revoked, on 29 June 2017, by clause 21(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.22 Transmission of information

(1) Except where specified otherwise in clauses 13.6 to 13.27, all information that a purchaser or generator must submit under clauses 13.6 to 13.27 must be submitted to the system operator using WITS.
(2) The system operator must immediately confirm receipt of any information that the system operator receives from a purchaser or generator under clauses 13.6 to 13.27. Each confirmation must contain a copy of the information received by the system operator together with the time of receipt.
(3) If a purchaser or generator has not received the confirmation within 10 minutes of submitting the information under clauses 13.6 to 13.27 to the system operator, the purchaser or generator must—
- (a) check whether the system operator has received the information; and
- (b) if the system operator has not received the information, resend the information; and
- (c) repeat the process set out in this clause until the system operator has confirmed receipt of the information from the purchaser or generator.

Compare: Electricity Governance Rules 2003 rules 3.21 to 3.23 section II part G

Clause 13.22(3): amended, on 28 June 2012, by clause 20 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.22: replaced, on 5 October 2017, by clause 338 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.23 Backup procedures if WITS is unavailable

(1) If WITS is unavailable to receive bids or offers or to confirm the receipt of bids or offers, each purchaser and generator or the system operator, as the case may be, must follow the backup procedures agreed between the WITS manager and the Authority and published by the Authority.
(2) [Revoked]

Compare: Electricity Governance Rules 2003 rules 3.24 and 3.25 section II part G

Clause 13.23 Heading: amended, on 5 October 2017, by clause 339(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.23: amended, on 5 October 2017, by clause 339(2), (3) and (4) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.23(1): amended, on 1 March 2024, by clause 70(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.23(2): revoked, on 1 March 2024, by clause 70(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.24 Plant with special circumstances

Despite clause 13.18(1), a generator is not required to submit a revised offer in respect of an automatic control plant if—
- (a) the offer submitted in respect of the automatic control plant is based on a profile of the pre-programmed levels of the automatic control plant; and
- (b) the offer is made at a 0 price and clause 13.116(2) applies to the generator; and
- (c) the offer is otherwise made in accordance with clauses 13.6 to 13.27; and
- (d) the system operator has confirmed in writing to the generator that it is satisfied that the offer meets the requirements of the dispatch objective; and
- (e) the generator expects that the ability of the automatic control plant to generate the quantity scheduled for a trading period at a grid injection point will not change by more than 10 MW of the scheduled quantity.

Compare: Electricity Governance Rules 2003 rule 3.26 section II part G

Clause 13.24: amended, on 20 December 2021, by clause 54 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

13.25 Exception for small generation

(1) Despite clause 13.6(1), a generator is not required to submit an offer for a generating station that is 10 MW or smaller and any electricity sold to the clearing manager from the generating station is regarded as unoffered generation for the purpose of this Code.
(2) The system operator may require the relevant generator to provide information in a form reasonably determined by the system operator on the expected generation output for any unoffered generation from a generating station with a point of connection to the grid.

Compare: Electricity Governance Rules 2003 rule 3.27 section II part G

Clause 13.25(1): amended, on 29 June 2017, by clause 22 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.26 Exception for embedded generation

An embedded generator required to submit an offer in accordance with clause 8.25(5) may make an offer at a 0 price and clause 13.116(2) applies to the embedded generator.

Compare: Electricity Governance Rules 2003 rule 3.28 section II part G

13.27 System operator to retain bids and offers

The system operator must retain, in a form that it considers appropriate, all bids and offers for electricity submitted by participants under this subpart, including all revised bids and offers.

Compare: Electricity Governance Rules 2003 rule 3.29 section II part G

Clause 13.27: amended, on 29 June 2017, by clause 23 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Process for determining conforming and non-conforming grid exit points

Heading: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.27A

Authority determines conforming and non-conforming GXPs on own initiative

The Authority may, on its own initiative,—
- (a) determine whether a GXP, which is deemed to be a conforming GXP under clause 13.27F, is a conforming GXP or a non-conforming GXP:
- (b) reconsider a previous determination, and as a result may decide to replace the previous determination with a new determination.

Clause 13.27A: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.27B

Authority to determine conforming and non-conforming GXPs if requested

(1) Subclause (4) applies if—
- (a) a purchaser or the system operator makes a request under clause 13.27H; and
- (b) the Authority decides there are valid grounds to consider the request.
(2) The Authority must decide whether to proceed with the request within a reasonable time after receiving the request.
(3) If the Authority decides there are no valid grounds to consider the request, the Authority must give written notice to the requester of—
- (a) the Authority’s decision; and
- (b) the grounds for the Authority’s decision.
(4) If subclause (1) applies, the Authority must—
- (a) determine whether a GXP, which is deemed to be a conforming GXP under clause 13.27F, is a conforming GXP or a non-conforming GXP:
- (b) reconsider a previous determination, and as a result may decide to replace the previous determination with a new determination.

Clause 13.27B: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.27B(3): amended, on 5 October 2017, by clause 340 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.27C

Process for making determination

(1) In making a determination, the Authority must—
- (a) apply the methodology set out in Schedule 13.7; and
- (b) request and take into account advice from the system operator; and
- (c) take into account any information submitted by a purchaser who purchases electricity at the GXP.
(2) The Authority must make a determination in accordance with the methodology in Schedule 13.7, unless—
- (a) the Authority has applied the methodology; and
- (b) according to the methodology, the GXP is a conforming GXP; and
- (c) the Authority considers that the GXP should be treated as a non-conforming GXP; and
- (d) the Authority has published criteria under clause 13.27E; and
- (e) making a determination that the GXP is a non-conforming GXP is in accordance with the criteria.
(3) If paragraphs (a) to (e) in subclause (2) apply, the Authority may make a determination in accordance with the criteria published under clause 13.27E.
(4) As soon as practicable after making a determination, the Authority must—
- (a) advise the WITS manager, all purchasers, and the system operator—
  - (i) of its determination; and
  - (ii) whether, in making the determination, the Authority has followed—
    - (A) the methodology set out in Schedule 13.7; or
    - (B) the criteria published under clause 13.27E; and
- (b) advise all purchasers and the system operator of the right to request, under clause 13.27H, a reconsideration of the determination; and
- (c) if the determination was requested under clause 13.27H, provide reasons for its decision to the requester.

Clause 13.27C Heading: amended, on 5 October 2017, by clause 341(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.27C: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.27C(2)(d), (3) and (4)(a)(ii)(B): amended, on 5 October 2017, by clause 341(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.27C(4): amended, on 27 June 2012, by clause 7 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011, Amendment 2012.

Clause 13.27(4)(a): amended, on 5 October 2017, by clause 341(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.27D

System operator to provide advice within reasonable time

The system operator must provide the advice requested under clause 13.27C(1)(b) within a reasonable time specified by the Authority.

Clause 13.27D: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.27E

Authority may publish criteria for determining GXP to be non-conforming

(1) The Authority may publish criteria that set out the circumstances in which the Authority may make a determination that does not follow the methodology set out in Schedule 13.7.
(2) The Authority must consult with participants before—
- (a) publishing the criteria under subclause (1):
- (b) amending the criteria published under subclause (1).

Clause 13.27E Heading: amended, on 5 October 2017, by clause 342(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.27E: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.27E: amended, on 5 October 2017, by clause 342(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.27F

GXP deemed to be conforming GXP before determination is made

If the Authority has not made a determination for a GXP, the GXP is deemed to be a conforming GXP until the Authority determines otherwise.

Clause 13.27F: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.27G

Authority must publish and maintain list of non-conforming and conforming GXPs

The Authority must publish and maintain a list of all non-conforming GXPs and all conforming GXPs, including—
- (a) the mean demand (in MW) for each GXP calculated in accordance with clause 1(b) of Schedule 13.7; and
- (b) if the mean demand for a GXP is 10 MW or more, the unpredictability measure for the GXP calculated in accordance with clause 1(c) of Schedule 13.7.

Clause 13.27G Heading: amended, on 5 October 2017, by clause 343(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.27G: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.27G: amended, on 5 October 2017, by clause 343(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.27H

Right to request determination or reconsideration of determination

(1) A purchaser may request that the Authority—
- (a) determine whether a GXP is a conforming GXP or a non-conforming GXP, in respect of a GXP—
  - (i) at which the purchaser purchases electricity; and
  - (ii) which is deemed to be a conforming GXP under clause 13.27F:
- (b) reconsider a determination made under clause 13.27A or clause 13.27B(4) for a GXP at which the purchaser purchases electricity.
(2) The system operator may request that the Authority—
- (a) determine whether a GXP, which is deemed to be a conforming GXP under clause 13.27F, is a conforming GXP or a non-conforming GXP:
- (b) reconsider a determination made under clause 13.27A or clause 13.27B(4).
(3) The person making the request may provide the Authority with information that the person considers relevant to its request.

Clause 13.27H: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.27I

Effect of determination

(1) When making a determination, the Authority must specify a date and a trading period from which the determination takes effect.
(2) The Authority must not specify a date that is earlier than 5 business days after the date on which the Authority makes the determination.

Clause 13.27I: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.27J

New GXPs

At least 1 month before a grid owner connects a GXP to the grid for the first time, the grid owner must advise the Authority in writing of its intention to connect the GXP.

Clause 13.27J: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.27J: amended, on 23 February 2015, by clause 75 of the Electricity Industry Participation Code Amendment (Distributed Generation) 2014.

Clause 13.27J: amended, on 5 October 2017, by clause 344 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.27K

Authority to provide information at purchaser’s request

(1) After the Authority has made a determination under clause 13.27A or clause 13.27B(4) for a GXP, a purchaser who purchases electricity at the GXP may request from the Authority the following information in relation to the GXP:
- (a) reconciled half hour demand data (in MW), as described in clause 2(1)(a) of Schedule 13.7:
- (b) information about the way in which demand switching information (described in clause 2(1)(b) of Schedule 13.7) has been used to prepare the adjusted reconciled half hour demand data described in clause 1(a) of Schedule 13.7:
- (c) information about the one-off events described in clause 2(1)(c) and clause 2(3) of Schedule 13.7 and the way in which those one-off events have been used to prepare the adjusted reconciled half hour demand data described in clause 1(a) of Schedule 13.7:
- (d) the adjusted reconciled half hour demand data (in MW), as described in clause 1(a) of Schedule 13.7:
- (e) the estimates of the adjusted reconciled half hour demand produced by the statistical predictive model under clause 3(1)(a) of Schedule 13.7, and the residuals calculated under clause 3(1)(b) of Schedule 13.7.
(2) If a purchaser requests information under subclause (1), the Authority must provide the information if the information—
- (a) is available to the Authority; and
- (b) is not confidential; and
- (c) is not commercially sensitive.

Clause 13.27K: inserted, on 28 March 2012, by clause 21 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Special treatment of some grid exit points

Heading: inserted, on 28 June 2012, by clause 22 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.28 Special treatment of some grid exit points

(1) For the purpose of this subpart and subparts 2 and 4, a purchaser, generator or market operation service provider may apply to the Authority to have 2 or more grid exit points treated as 1 grid exit point for the purposes of determining the status of a GXP under clause 13.27A or clause 13.27B(4), submitting bids, scheduling, switching, dispatch, pricing, clearing and settlement where there are 2 or more local networks supplied from the grid at the same physical location.
(2) In determining an application under subclause (1), the Authority must consider the following factors:
- (a) the efficiency or otherwise, of creating a separate price for grid exit points that are at the same, or at a geographically similar location:
- (b) the geographical similarity of the grid exit points that are the subject of the application:
- (c) the effect on a market operation service provider in terms of added processing time and complexity in treating as separate 2 or more grid exit points that are in the same or in a geographically similar location:
- (d) any submissions received from participants under subclause (3):
- (e) any other matter the Authority thinks fit.
(3) The Authority must give written notice to participants of an application under subclause (1) within 2 business days of the application being received by the Authority. Each participant has 5 business days to make submissions to the Authority on the application. The Authority must not consider an application until after the period for making submissions on the application has expired.
(4) If an application under subclause (1) has been approved, the Authority must consult with each market operation service provider about the time it may take to implement changes that are required to accommodate the decision. The Authority must then give written notice to each participant of the date from which its decision takes effect.

Compare: Electricity Governance Rules 2003 rule 4 section II part G

Clause 13.28(1): amended, on 28 June 2012, by clause 23 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.28(3) and (4): amended, on 5 October 2017, by clause 345 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Information from grid owners

13.29 Standing data on grid capability to be provided to system operator

In addition to the asset owner obligations to provide information under clauses 2(5) and (6) and 3(1) of Technical Code A of Schedule 8.3, each grid owner must provide standing data on the capability of the transmission system to the system operator that is consistent with the configuration of the transmission system in the algorithms described in Schedule 13.3. The transmission data must include—
- (a) AC system configuration, including the transmission lines; and
- (b) AC system capacity including the limits of each transmission line of the transmission system; and
- (c) AC system loss characteristics including transmission loss functions for each transmission line of the transmission system.

Compare: Electricity Governance Rules 2003 rule 5.1 section II part G

Clause 13.29(a): amended, on 1 February 2016, by clause 77 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

13.30 Standing data on HVDC capability to be provided to system operator

(1) In addition to the asset owner obligations to provide information under clauses 2(5) and (6), and 3(1) of Technical Code A of Schedule 8.3, the HVDC owner must provide standing data on the capability of the HVDC link to the system operator consistent with the HVDC link configuration.
(2) The data provided under subclause (1) must include—
- (a) the HVDC transmission lines and system capacity, including reserve capacity; and
- (b) HVDC link capacity, including limits of each HVDC transmission line of the HVDC transmission system; and
- (c) HVDC system loss characteristics including transmission loss functions for each transmission line of the HVDC transmission system; and
- (d) in relation to Pole 2, or Pole 3, or Pole 2 and Pole 3, of the HVDC link—
  - (i) if the HVDC owner imposes a limit on transfer direction, the direction of that transfer limit (northward or southward); and
  - (ii) if the HVDC owner imposes a minimum transfer limit, that minimum transfer limit (in MW); and
  - (iii) if the HVDC owner imposes a maximum transfer limit, that maximum transfer limit (in MW).
(3) Subclause (2)(d) applies only if—
- (a) the HVDC owner is operating the HVDC link in accordance with—
  - (i) a commissioning plan agreed with the system operator under clause 2(6) to (9) of Technical Code A of Schedule 8.3; or
  - (ii) a test plan provided to the system operator under clause 2(6) to (9) of Technical Code A of Schedule 8.3; and
- (b) the HVDC link configuration is—
  - (i) Pole 3 and Pole 2 bipole round power; or
  - (ii) Pole 3 and Pole 2 bipole not round power.

Compare: Electricity Governance Rules 2003 rule 5.2 section II part G

Clause 13.30: substituted, on 1 November 2012, by clause 4 of the Electricity Industry Participation (HVDC Link Pole 3 Standing Data) Code Amendment 2012.

Clause 13.30(2)(a): amended, on 1 February 2016, by clause 78 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.30(2)(d): amended, on 26 September 2013, by clause 5 of the Electricity Industry Participation (HVDC Link Bipole Control System Testing) Code Amendment 2013.

Clause 13.30(3)(a)(i): amended, on 5 October 2017, by clause 346 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.30(1): amended, on 1 March 2024, by clause 71(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.30(3)(b): amended, on 1 March 2024, by clause 71(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.31 Standing data on transformer capability to be provided to system operator

In addition to the asset owner obligations to provide information under clauses 2(5) and (6), and 3(1) of Technical Code A of Schedule 8.3 each grid owner must provide standing data on the capability of transformers to the system operator consistent with the configuration of those transformers. The data must include—
- (a) the transformer capacity of each transformer; and
- (b) the transformer loss characteristics, including transformer loss functions, for each transformer.

Compare: Electricity Governance Rules 2003 rule 5.3 section II part G

13.32 Transmission grid capability information to be updated

In addition to the asset owner obligations to provide information under clauses 2(5) and (6) of Technical Code A of Schedule 8.3, and subject to any timetable agreed with the system operator under clause 3(1) of Technical Code A of Schedule 8.3, each grid owner must submit to the system operator for each trading period of a schedule period, or for such longer period of time as agreed between the system operator and each grid owner, any updates to the information described in clauses 13.29 to 13.31 and 13.33(d).

Compare: Electricity Governance Rules 2003 rule 5.4 section II part G

Clause 13.32: amended, on 28 June 2012, by clause 24 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.33 Grid owners must submit revised information to system operator

Up to 1 hour before the beginning of the relevant trading period, but subject to any timetable agreed with the system operator under clause 3(1) of Technical Code A of Schedule 8.3, each grid owner must immediately submit revised information to the system operator if there has been or is likely to be—
- (a) a change to the information described in clauses 13.29 or 13.30; or
- (b) a change of 5% or more in the capacity limit of any transmission line of the transmission system, of the HVDC link, or of any transformer, represented in the algorithms described in Schedule 13.3; or
- (c) a change to loss characteristics, including loss functions, for any transmission line of the transmission system or of the HVDC link, or for any transformer, represented in the algorithms described in Schedule 13.3 that causes any losses or marginal losses to change by 5% or more; or
- (d) a change in the availability of assets forming part of the grid.

Compare: Electricity Governance Rules 2003 rule 5.5 section II part G

Clause 13.33: amended, on 29 June 2017, by clause 24 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.33: amended, on 20 December 2021, by clause 55 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

13.34 Changes may be made later than 1 hour before trading period

(1) A grid owner may update the information submitted under clause 13.33 during the period commencing 1 hour before the relevant trading period and ending at the end of the relevant trading period only if—
- (a) a bona fide physical reason necessitates the change; or
- (b) the system operator issues a formal notice; or
- (c) an unforeseeable change occurs in the availability of a grid owner’s assets, which were the subject of a planned or unplanned outage in relation to which the grid owner gave written notice to the system operator.
(2) If a grid owner has sent revised information to the system operator under subclause (1) later than 15 minutes before the relevant trading period, the grid owner must also immediately advise the system operator of the revised information by telephone or by such other mechanism as may be agreed from time to time in writing between grid owners and the system operator.
(3) [Revoked]
(4) [Revoked]

Compare: Electricity Governance Rules 2003 rules 5.6 to 5.9 section II part G

Clause 13.34 Heading: amended, on 29 June 2017, by clause 25(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.34 Heading: amended, on 1 November 2022, by clause 21(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.34(1): amended, on 29 June 2017, by clause 25(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.34(1): amended, on 1 November 2022, by clause 21(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.34(1)(c): amended, on 5 October 2017, by clause 347 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.34(2): amended, on 1 November 2018, by clause 83 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.34(3) and (4): revoked, on 29 June 2017, by clause 25(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.35 System operator to confirm receipt of grid owner information

(1) [Revoked]
(2) The system operator must immediately confirm to each grid owner receipt of all information received from that grid owner under clauses 13.29 to 13.35. The confirmation must also contain a record of the time of receipt.
(3) If a grid owner has not received a confirmation that its information has been received by the system operator within 10 minutes after that information has been sent, the grid owner must telephone the system operator to check whether the information has been received. If it has not, the grid owner must resend the information. The process set out in this clause must be repeated until the system operator confirms receipt of the information.

Compare: Electricity Governance Rules 2003 rules 5.10 to 5.12 section II part G

Clause 13.35 Heading: amended, on 5 October 2017, by clause 348(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.35(1): revoked, on 5 October 2017, by clause 348(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.35(2): amended, on 5 October 2017, by clause 348(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.35(2): amended, on 1 November 2018, by clause 84 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

13.36 [Revoked]

Compare: Electricity Governance Rules 2003 rules 5.13 and 5.14 section II part G

Clause 13.36: revoked, on 5 October 2017, by clause 349 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Offering instantaneous reserve

13.37 System operator to approve ancillary service agents wishing to make reserve offers

Before an ancillary service agent makes a reserve offer under clauses 13.38 to 13.54, the ancillary service agent must have a valid and enforceable contract with the system operator to provide reserve offers in accordance with this Code.

Compare: Electricity Governance Rules 2003 rule 6.1 section II part G

13.38 Ancillary service agents to submit reserve offers to system operator

(1) Each ancillary service agent who has a contract described in clause 13.37 may submit reserve offers to the system operator.
(1A) An ancillary service agent who submits a reserve offer must ensure that the system operator receives the reserve offer at least 71 trading periods before the beginning of the trading period to which the reserve offer applies.
(2) Each reserve offer submitted by an ancillary service agent under subclause (1) may be for fast instantaneous reserve, sustained instantaneous reserve or both and must—
- (a) contain all the information required by Form 5(1) in Schedule 13.1 for partly loaded spinning reserve or Form 5(2) in Schedule 13.1 for all other categories of generation reserve; and
- (b) contain all the information required by Form 6 in Schedule 13.1 for interruptible load; and
- (c) be a reasonable estimate of the quantity of instantaneous reserve available from the ancillary service agent at that grid injection point, grid exit point or interruptible load group GXP.
(3) Each reserve offer submitted under subclause (1), by an ancillary service agent that is a generator, must be made by reference to the same generating unit or generating station that is the subject of an offer under clauses 13.10 or 13.11.

Compare: Electricity Governance Rules 2003 rules 6.2 to 6.4 section II part G

Clause 13.38(1): substituted, on 28 June 2012, by clause 25 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.38(1A): inserted, on 28 June 2012, by clause 25 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.38(1A): amended, on 1 November 2012, by clause 5 of the Electricity Industry Participation (Part 13 Minor Amendments) Code Amendment 2012.

Clause 13.38(2)(a): amended, on 3 May 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Enabling Energy Storage Systems to Offer Instantaneous Reserve) 2022.

Clause 13.38(3): amended, on 15 May 2014, by clause 38 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

13.39 Inter-relationship between reserve and energy offers

Reserve offers and offers made under clauses 13.38(1) and 13.6(1) to (3) respectively, if they are in respect of the same individual generating unit or individual generating station (as required under clauses 13.10 and 13.11), are inter-related in that the greater the energy dispatched the lower the instantaneous reserve may be and vice versa. Accordingly, an ancillary service agent that is a generator does not breach clause 13.38(2)(c) if the offer quantity under clauses 13.6 to 13.27 and quantity of instantaneous reserve offered under clauses 13.37 to 13.54 are duplicated, and the ancillary service agent must not be scheduled by the system operator and a dispatch instruction from the system operator must not be given the effect of which is that the combined dispatch quantity and instantaneous reserve exceeds the capacity of the individual generating unit or individual generating station, as the case may be.

Compare: Electricity Governance Rules 2003 rule 6.5 section II part G

Clause 13.39: amended, on 15 May 2014, by clause 39 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.39: amended, on 20 December 2021, by clause 56 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

13.40 Inter-relationship between reserve offers of interruptible load and bids

Bids and reserve offers of interruptible load are inter-related in that demand electrically disconnected in response to an under-frequency event and in accordance with a dispatched reserve offer may lower the quantity purchased at that grid exit point. Accordingly, a purchaser does not breach the reasonable estimate requirement in clauses 13.7(3), 13.7AA(2), and 13.8A(4) if the purchaser is acting as an ancillary service agent and reduces corresponding demand in response to an under-frequency event in accordance with a dispatched reserve offer.

Compare: Electricity Governance Rules 2003 rule 6.6 section II part G

Clause 13.40 Heading: amended, on 15 May 2014, by clause 16(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.40: amended, on 28 June 2012, by clause 26 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.40: amended, on 15 May 2014, by clause 16(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.40: amended, on 5 October 2017, by clause 350 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.40: amended, on 20 December 2021, by clause 57 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

Clause 13.40: amended, on 3 May 2022, by clause 6 of the Electricity Industry Participation Code Amendment (Enabling Energy Storage Systems to Offer Instantaneous Reserve) 2022.

13.40A

Inter-relationship between reserve offers and nominated dispatch bids

Reserve offers and nominated dispatch bids made under clauses 13.38(1) and 13.7(1) to (3) respectively, if they are in respect of the same plant, are inter-related in that the lower the demand dispatched or scheduled the lower the instantaneous reserve may be. The ancillary service agent must not be scheduled by the system operator and a dispatch instruction from the system operator must not be given the effect of which is that the instantaneous reserve exceeds the scheduled or dispatched demand quantity of the dispatch-capable load station, as the case may be.

Clause 13.40A: inserted, on 1 November 2022, by clause 22 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.41 Reserve offers may contain up to 3 price bands

Each reserve offer submitted by an ancillary service agent may, for each type of instantaneous reserve, have a maximum of 3 price bands for each trading period. The price offered in each band must increase progressively from band to band as the aggregate quantity increases.

Compare: Electricity Governance Rules 2003 rule 6.7 section II part G

13.42 How price to be specified in reserve offers

When submitting a reserve offer under clause 13.38, an ancillary service agent—
- (a) must express the price in each band in dollars and whole cents per MW excluding GST; and
- (b) must specify a price that is equal to or greater than $0.00/MW.

Compare: Electricity Governance Rules 2003 rule 6.8 section II part G

Clause 13.42: substituted, on 1 November 2012, by clause 6 of the Electricity Industry Participation (Part 13 Minor Amendments) Code Amendment 2012.

13.43 [Revoked]

Compare: Electricity Governance Rules 2003 rule 6.9 section II part G

Clause 13.43: revoked, on 1 November 2012, by clause 7 of the Electricity Industry Participation (Part 13 Minor Amendments) Code Amendment 2012.

13.44 How quantity is to be specified in reserve offers

(1) For each price band, a reserve offer must specify the quantity of instantaneous reserve offered to respond as fast instantaneous reserve and/or sustained instantaneous reserve—
- (a) as the generation available to be injected as a proportion of electricity output up to a specified maximum quantity for partly loaded spinning reserve; or
- (b) as the generation available to be injected for all other categories of generation reserve; or
- (c) as the demand available to be reduced for interruptible load.
(2) The quantity that may be offered in a price band for a trading period must be expressed in MW to not more than 3 decimal places and must not be less that 0.000 MW.

Compare: Electricity Governance Rules 2003 rule 6.10 section II part G

Clause 13.44: amended, on 15 May 2014, by clause 40 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.44: amended, on 29 June 2017, by clause 26 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.44: amended, on 3 May 2022, by clause 7 of the Electricity Industry Participation Code Amendment (Enabling Energy Storage Systems to Offer Instantaneous Reserve) 2022.

13.45 Reserve offers revised if energy offers revised

An ancillary service agent that has made a reserve offer must revise the reserve offer if it has, in accordance with clauses 13.6 to 13.27, revised the offer made in respect of the equivalent item of generating plant.

Compare: Electricity Governance Rules 2003 rule 6.11 section II part G

Clause 13.45: amended, on 29 June 2017, by clause 27 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.46 Reserve offer may be revised

(1) Subject to subclauses (1A) and (1B), an ancillary service agent may revise a reserve offer at any time before the end of the trading period in respect of which the reserve offer is made by submitting a new reserve offer to the system operator.
(1A) An ancillary service agent must not revise its reserve offer prices during a gate closure period.
(1B) An ancillary service agent must not revise the MW specified in any price band in a reserve offer during a gate closure period unless subclause (3) or clause 13.47 applies.
(2) An ancillary service agent that revises a reserve offer for an embedded generating station must use reasonable endeavours to submit the reserve offer at least 1 hour before the beginning of the trading period in respect of which the reserve offer is made.
(3) Before the end of the trading period to which the reserve offer applies, and despite clauses 13.97 to 13.101, an ancillary service agent must immediately submit a revised reserve offer in respect of MW offered to the system operator if—
- (a) the MW specified in any price band in the reserve offer no longer represents a reasonable estimate of the instantaneous reserve available from the ancillary service agent at the grid injection point, grid exit point or interruptible load group GXP
- (b) [Revoked]
(4) [Revoked]

Compare: Electricity Governance Rules 2003 rules 6.12 and 6.13 section II part G

Clause 13.46 Heading: amended, on 29 June 2017, by clause 28(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.46 Heading: amended, by clause 23(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.46(1): replaced, on 29 June 2017, by clause 28(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.46(1) and (3): amended, by clause 23(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.46(1A) and (1B): inserted, on 29 June 2017, by clause 28(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.46(2): replaced, on 29 June 2017, by clause 28(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.46(3): amended, on 29 June 2017, by clause 28(4)(a) and (b) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.46(3)(a): amended, on 29 June 2017, by clause 28(4)(c) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.46(3)(a): amended, by clause 23(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.46(3)(b): amended, on 28 June 2012, by clause 27 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.46(3)(b): amended, on 29 June 2017, by clause 28(4)(d)(i) and (ii) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.46(3)(b): revoked, by clause 23(4) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.46(4): revoked, on 29 June 2017, by clause 28(5) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.47 MW change during gate closure period

(1) An ancillary service agent may revise a reserve offer during a gate closure period if—
- (a) the revision is necessary due to a bona fide physical reason; or
- (b) the system operator issues a formal notice under clause 5 of Technical Code B of Schedule 8.3; or
- (c) a bona fide physical reason that made a revision necessary under paragraph (a) ceases to exist sooner than was expected at the time it arose, and—
  - (i) the 1st trading period after the original bona fide physical reason ceases to exist is within 24 hours after the circumstances that constituted the original bona fide physical reason arose; and
  - (ii) the total change in MW specified in the reserve offer that is revised as a result of the bona fide physical reason ceasing to exist is the same or less than the total change in MW specified in the reserve offer that was made as a result of the original bona fide physical reason.
(2) [Revoked]

Compare: Electricity Governance Rules 2003 rule 6.14 section II part G

Clause 13.47 Heading: replaced, on 29 June 2017, by clause 29(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.47(1): replaced, on 29 June 2017, by clause 29(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.47(2): amended, on 15 May 2014, by clause 41 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.47(2): revoked, on 29 June 2017, by clause 29(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.48 System operator advised of revised reserve offers in certain circumstances

(1) This clause applies to each ancillary service agent that submits a revised reserve offer in the period beginning 15 minutes before the trading period to which the revised reserve offer relates and ending at the end of the relevant trading period.
(2) The ancillary service agent must immediately advise the system operator of the revision.

Compare: Electricity Governance Rules 2003 rule 6.15 section II part G

Clause 13.48 Heading: amended, on 5 October 2017, by clause 351(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.48: substituted, on 29 June 2017, by clause 30 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.48(1): amended, by clause 24 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.48(2): amended, on 5 October 2017, by clause 351(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.49 Authority advised of revised reserve offer during gate closure period

(1) An ancillary service agent that submits a revised reserve offer to the system operator during a gate closure period must report each revision to the Authority in writing together with an explanation of the reason for the revision.
(2) The ancillary service agent must report a revision to the Authority no later than 1700 hours on the 1st business day following the trading day on which it made the revision.

Compare: Electricity Governance Rules 2003 rule 6.16 section II part G

Clause 13.49 Heading: amended, on 5 October 2017, by clause 352 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.49: substituted, on 29 June 2017, by clause 31 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.50 System operator to advise Authority of revision of reserve offers

(1) The system operator must advise the Authority of any revision of the availability of reserves that are provided under ancillary services contracts not covered by clauses 13.37 to 13.54.
(1A) The system operator must advise the Authority of a revision no later than 1700 hours on the 1st business day following the trading day on which the revision was made.
(2) [Revoked]

Compare: Electricity Governance Rules 2003 rules 6.17 and 6.18 section II part G

Clause 13.50 Heading: amended, on 29 June 2017, by clause 32(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.50(1): amended, on 29 June 2017, by clause 32(2)(a) and (b) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.50(1A): inserted, on 29 June 2017, by clause 32(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.50(2): revoked, on 29 June 2017, by clause 32(4) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.51 Transmission of reserve offers

(1) All reserve offers or cancellations of reserve offers submitted by an ancillary service agent under clauses 13.37 to 13.54 must be transmitted to the system operator through WITS.
(2) The system operator must immediately confirm receipt to the ancillary service agent of all reserve offers or cancellations of reserve offers received from the ancillary service agent through WITS. Such confirmation must also contain a copy of the reserve offer or cancellation of reserve offer received by the system operator, together with the time of receipt.
(3) If an ancillary service agent has not received confirmation that the system operator has received its reserve offer or cancellation of a reserve offer within 10 minutes after the ancillary service agent submitted the reserve offer or cancellation of a reserve offer, the ancillary service agent must check whether the system operator has received the reserve offer or cancellation of a reserve offer. If the system operator has not received the reserve offer or cancellation of a reserve offer, the ancillary service agent must resend the reserve offer or cancellation of a reserve offer. The processes set out in this clause must then be repeated until the system operator confirms receipt of the reserve offer or cancellation of a reserve offer from the ancillary service agent.

Compare: Electricity Governance Rules 2003 rules 6.19 to 6.21 section II part G

Clause 13.51 Heading: amended, on 5 October 2017, by clause 353(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.51(1) and (2): amended, on 5 October 2017, by clause 353(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.51(3): replaced, on 5 October 2017, by clause 351(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.52 Backup procedures if WITS is unavailable

(1) If WITS is unavailable to receive reserve offers or cancellations of reserve offers or to confirm the receipt of such reserve offers or cancellations, an ancillary service agent or the system operator, as the case may be, must follow the backup procedures specified by the WITS manager.
(2) The backup procedures referred to in subclause (1) must be specified by the WITS manager following consultation with the Authority, ancillary service agents and the system operator.

Compare: Electricity Governance Rules 2003 rules 6.22 and 6.23 section II part G

Clause 13.52 Heading: amended, on 5 October 2017, by clause 354(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.52: amended, on 5 October 2017, by clause 354(2), (3) and (4) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.53 Additional information to be provided by participants

Despite clauses 13.22, 13.23, 13.51, and 13.52, if an ancillary service agent submits a reserve offer for generation reserve in accordance with clauses 13.37 to 13.54, the ancillary service agent must also provide the maximum quantity of fast response generation reserve expressed in MW and/or the maximum quantity of sustained response generation reserve expressed in MW to the system operator in a manner and at such times as are approved by the system operator (such approval not to be unreasonably withheld).

Compare: Electricity Governance Rules 2003 rule 6.24 section II part G

Clause 13.53: amended, on 15 May 2014, by clause 42 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.53: amended, on 3 May 2022, by clause 8 of the Electricity Industry Participation Code Amendment (Enabling Energy Storage Systems to Offer Instantaneous Reserve) 2022.

13.54 System operator to retain reserve offers

The system operator must retain, in a form that it considers appropriate, all reserve offers submitted by all ancillary service agents in accordance with this subpart, including all revised reserve offers.

Compare: Electricity Governance Rules 2003 rule 6.25 section II part G

Clause 13.54: amended, on 29 June 2017, by clause 33 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.55 Availability of bids, offers, and reserve offers

(1) The WITS manager must, within 24 hours of the end of each day, make available on WITS and at no cost on a publicly accessible approved system, all final bids, final offers and final reserve offers received for the trading periods of the previous trading day.
(2) All information made available on WITS and on the publicly accessible approved system must remain available for inspection for a period of at least 4 weeks—
- (a) on WITS; and
- (b) at no cost on the publicly accessible approved system.
(3) If WITS is unavailable for the purposes of subclause (2)(a), the WITS manager must follow the backup procedures specified by the WITS manager from time to time.
(4) The backup procedures referred to in subclause (3) must be put in place by the WITS manager in consultation with the Authority, purchasers, generators and ancillary service agents.
(5) If the publicly accessible approved system is not available for the purposes of subclause (2)(b), the WITS manager is not obliged to follow any backup procedures, but the WITS manager must make the information available at no cost as soon as practicable once the publicly accessible approved system becomes available.
(6) [Revoked]
(7) [Revoked]

Compare: Electricity Governance Rules 2003 rule 7 section II part G

Clause 13.55 Heading: amended, on 28 June 2012, by clause 28(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.55(1): amended, on 5 October 2017, by clause 355(1) and (2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.55(2): replaced, on 5 October 2017, by clause 355(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.55(3): amended, on 5 October 2017, by clause 355(1) and (4) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.55(4): amended, on 5 October 2017, by clause 355(1) and (5) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.55(5): replaced, on 5 October 2017, by clause 355(6) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.55(6) and (7): revoked, on 28 June 2012, by clause 28(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.55A

System operator to make information available

(1) The system operator must retain, for at least 2 years,—
- (a) information about all bids, cancelled bids, offers, cancelled offers, reserve offers, and cancelled reserve offers submitted by a purchaser, generator, or ancillary service agent for a trading period; and
- (b) each forecast prepared under clause 13.7A(1).
(2) Any person may request that the system operator make available any of the information described in subclause (1) for any trading period that occurred at least 1 day before the date of the request.
(3) The system operator must make the requested information available in a manner, and for a fee, that is reasonable having regard to the size and nature of the request.

Clause 13.55A: inserted, on 28 June 2012, by clause 29 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.55A(1)(b): amended, on 15 May 2014, by clause 17 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Subpart 2—Scheduling and dispatch

13.56 Contents of this subpart

This subpart specifies—
(a) the system operator’s dispatch objective; and
(b) the process for preparing a price-responsive schedule and non-response schedule, including the contents of and inputs for those schedules; and
(c) the process by which the system operator prepares a dispatch schedule; and
(d) the process by which the system operator prepares and issues dispatch instructions and dispatch notifications; and
(e) the requirement for generators, ancillary service agents, and dispatched purchasers to comply with dispatch instructions; and
(f) [Revoked]
(g) the implications of a grid emergency for bids, offers and reserve offers; and
(h) the system operator’s reporting obligations; and
(i) the requirement for the system operator to publish scheduling information.

Compare: Electricity Governance Rules 2003 rule 1 section III part G

Clause 13.56: substituted, on 28 June 2012, by clause 30 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.56(d): amended, by clause 25(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.56(e): amended, on 15 May 2014, by clause 18 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.56(f): revoked, by clause 25(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.57 The dispatch objective

The system operator’s dispatch objective is to maximise for each half hour the gross economic benefits to all purchasers of electricity at the grid exit points, less the cost of supplying the electricity at the grid injection points and the costs of ancillary services purchased by the system operator under subpart 3 of Part 8, in accordance with the methodology set out in Schedule 13.3, subject to—
- (a) the capability of generation, dispatch-capable load stations for which a nominated dispatch bid was submitted, and ancillary services and the configuration and capacity of the grid and information made available by asset owners; and
- (b) achieving the principal performance obligations and any arrangements of the type described in clause 8.6; and
- (c) meeting the requirements of clause 8.5 in relation to restoration of the power system—
provided that in the case of any conflict between paragraphs (b) and (c), paragraph (c) takes priority.

Compare: Electricity Governance Rules 2003 rule 2 section III part G

Clause 13.57(a): amended, on 15 May 2014, by clause 19 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.58 Process for preparing price-responsive schedule and non-response schedule

(1) The system operator must prepare—
- (a) a price-responsive schedule; and
- (b) a non-response schedule.
(1A) The system operator must prepare the schedules listed in subclause (1) in accordance with the timing required under clause 13.62.
(2) [Revoked]
(3) [Revoked]
(3A) In preparing each price-responsive schedule, the system operator must—
- (a) use the most recent information received under subpart 1; and
- (b) use all other information described in clause 13.58A(1); and
- (c) act in accordance with Schedule 13.3.
(3B) In preparing each non-response schedule, the system operator must—
- (a) use the most recent information received under subpart 1; and
- (b) use all other information described in clause 13.58A(2); and
- (c) act in accordance with Schedule 13.3.
(4) As soon as practicable after the system operator has completed preparing a price-responsive schedule and a non-response schedule, the system operator must make the schedules available to the clearing manager using WITS.

Compare: Electricity Governance Rules 2003 rules 3.1 to 3.4 section III part G

Clause 13.58(1): substituted, on 28 June 2012, by clause 31 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.58(1A): inserted, on 28 June 2012, by clause 31 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.58(2) and (3): revoked, on 28 June 2012, by clause 31 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.58(3A) and (3B): inserted, on 28 June 2012, by clause 31 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.58(4): substituted, on 28 June 2012, by clause 31 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.58(4): amended, on 5 October 2017, by clause 356 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.58AA

System operator to assign price and quantity values

(1) In preparing each price-responsive schedule and each non-response schedule, the system operator must assign the price and quantity values set out in subclause (2) to the following demand:
- (a) in relation to a price-responsive schedule, forecast demand at a conforming GXP that is not the subject of a bid:
- (b) in relation to a non-response schedule,—
  - (i) forecast demand at a conforming GXP that is not the subject of a nominated bid; and
    (ii) demand at a GXP that is the subject of a nominated non-dispatch bid.
(2) The price and quantity values are as follows:
- (a) $21,000 per MWh for the first 5% of the relevant demand:
- (b) $31,000 per MWh for the next 15% of the relevant demand:
- (c) $50,000 per MWh for the remaining 80% of the relevant demand.
(3) In preparing each price-responsive schedule and each non-response schedule, the system operator must assign the price and quantity values set out in the following table to the constraints specified in clause 12(5) of Schedule 13.3:

Tranche	Fast instantaneous reserve contingent risk violation ($/MWh)	Sustained instantaneous reserve contingent risk violation ($/MWh)	Quantity (MWh)
1	7,000	6,500	No limit

(4) In preparing each price-responsive schedule and each non-response schedule, the system operator must assign the price values set out in the following table to the model parameters specified in clause 1 of Schedule 13.2:

Tranche	Fast instantaneous reserve contingent risk violation ($/MWh)	Sustained instantaneous reserve contingent risk violation ($/MWh)	Quantity (MWh)
1	7,000	6,500	No limit

Clause 13.58(AA): inserted, by clause 26 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.58AA(2): amended, by clause 5(1) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2025.

Clause 13.58AA(3) table: replaced, by clause 5(2) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2025.

Clause 13.58AA(4): table replaced, by clause 5(3) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2025.

13.58AB

Authority to review price and quantity values

The Authority may review the price and quantity values specified in clause 13.58AA(2) and (3) at any time, and must do so no later than 5 years after the commencement of this clause, and at intervals of no more than 5 years after that.

Clause 13.58(AB): inserted, by clause 26 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.58A

Inputs for price-responsive schedule and non-response schedule

(1) The system operator must prepare a price-responsive schedule using the following inputs:
- (a) offers and reserve offers; and
- (aa) the potential output of all intermittent generating stations, determined using the most recent forecast of generation potential for each intermittent generating station submitted under clause 13.18A; and
- (b) nominated bids; and
- (c) the forecast prepared by the system operator under clause 13.7A(1); and
- (d) difference bids; and
- (e) information provided to the system operator by a grid owner under clauses 13.29 to 13.34 about—
  - (i) the AC transmission system configuration, capacity, and losses; and
  - (ii) the capability of the HVDC link including the HVDC link configuration, the capacity of the HVDC link, the losses in the HVDC link, the direction of any transfer limit on the HVDC link, and any minimum or maximum transfer limits on the HVDC link; and
  - (iii) transformer configuration, capacity, and losses; and
- (f) the adjustments specified in subclause (2)(e), subject to any exceptions specified in the policy statement; and
- (g) information about voltage support from contracts held by the system operator under the procurement plan; and
- (h) information from ancillary service agents about instantaneous reserves procured under the procurement plan; and
- (i) any price and quantity values assigned by the system operator under clause 13.58AA(1)(a).
(2) The system operator must prepare a non-response schedule using the following inputs:
- (a) offers, nominated dispatch bids, and reserve offers; and
- (aa) the potential output of all intermittent generating stations, determined using the most recent forecast of generation potential for each intermittent generating station submitted under clause 13.18A; and
- (b) nominated non-dispatch bid quantities (where, in the case of a nominated non-dispatch bid submitted by a dispatch notification purchaser, the relevant quantity is 0 MW); and
- (c) the forecast prepared by the system operator under clause 13.7A(1); and
- (d) information provided to the system operator by a grid owner under clauses 13.29 to 13.34 referring to—
  - (i) the AC transmission system configuration, capacity, and losses; and
  - (ii) the capability of the HVDC link including the HVDC link configuration, the capacity of the HVDC link, the losses in the HVDC link, the direction of any transfer limit on the HVDC link, and any minimum or maximum transfer limits on the HVDC link; and
  - (iii) transformer configuration, capacity, and losses; and
- (e) adjustments made by the system operator under clause 13(1) of Schedule 13.3, in order to meet the dispatch objective; and
- (f) information about voltage support from contracts held by the system operator under the procurement plan; and
- (g) information from ancillary service agents about instantaneous reserves procured under the procurement plan; and
- (h) any price and quantity values assigned by the system operator under clause 13.58AA(1)(b).

Clause 13.58A: inserted, on 28 June 2012, by clause 32 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.58A(1)(aa): inserted, at 12.00 pm on 19 September 2019, by clause 16(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.58A(1)(c): amended, on 15 May 2014, by clause 20 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.58A(1)(e)(ii): substituted, on 1 November 2012, by clause 5(1) of the Electricity Industry Participation (HVDC Link Pole 3 Standing Data) Code Amendment 2012.

Clause 13.58A(1)(h): amended, by clause 27(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.58A(1)(i): inserted, by clause 27(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.58A(2)(a) – (c): amended, on 15 May 2014, by clause 20 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.58A(2)(aa): inserted, at 12.00 pm on 19 September 2019, by clause 16(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.58A(2)(b): amended, by clause 27(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.58A(2)(d)(ii): substituted, on 1 November 2012, by clause 5(2) of the Electricity Industry Participation (HVDC Link Pole 3 Standing Data) Code Amendment 2012.

Clause 13.58A(2)(g): amended, by clause 27(4) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.58A(2)(h): inserted, by clause 27(5) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.58A(1)(e)(ii): replaced, on 1 March 2024, by clause 72(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.58A(2)(d)(ii): replaced, on 1 March 2024, by clause 72(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.59 Contents of each price-responsive schedule and non-response schedule

For each trading period in the schedule length period, each price-responsive schedule and each non-response schedule prepared by the system operator must contain the information specified in the table in Schedule 13.3B, as indicated by a X—
- (a) in the case of the price-responsive schedule, in column 1 of the table; and
- (b) in the case of the non-response schedule, in column 2 of the table.

Compare: Electricity Governance Rules 2003 rule 3.5 section III part G

Clause 13.59: substituted, on 28 June 2012, by clause 33 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.59(a)(iv): amended, on 3 October 2013, by clause 5 of the Electricity Industry Participation (Technology Neutral Language in Frequency Keeping) Code Amendment 2013.

Clause 13.59(a)(xviii) and (xix): inserted, on 1 June 2013, by clause 6 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.59(c): substituted, on 15 May 2014, by clause 21 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.59: replaced, by clause 28 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.60 Block dispatch may occur

(1) A generator and the system operator may agree to treat a group of generating stations as a block dispatch group.
(2) If an agreement for block dispatch has been reached, the following procedures apply:
- (a) the generator must give written notice to the clearing manager of the agreement, at least 5 business days before the agreement takes effect, specifying—
  - (i) the trading day and the trading period in which the agreement will take effect; and
  - (ii) the generating stations that are the subject of the agreement; and
  - (iii) the terms of the agreement; and
- (b) the system operator must identify in each non-response schedule the generating stations or generating units that are part of a block dispatch group.
(3) The generator must give written notice to the clearing manager of any change to an agreement for block dispatch made under this clause or clause 13.61 at least 5 business days before the change takes effect.

Compare: Electricity Governance Rules 2003 rules 3.6 to 3.6.2 section III part G

Clause 13.60(2)(a) and (3): amended, on 5 October 2017, by clause 357 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.60(2)(a): amended, on 1 November 2018, by clause 85(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.60(2)(b): amended, on 28 June 2012, by clause 34 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.60(3): inserted, on 15 May 2014, by clause 43 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.60(3): amended, on 1 November 2018, by clause 85(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

13.61 System operator to give notice of block security constraints

(1) The system operator must give notice on WITS to generators of the implication of any block security constraints that apply within the block dispatch group. The notice must include—
- (a) the trading periods for which the block security constraint applies; and
- (b) how the block security constraint divides the generating stations or generating units of a block dispatch group into sub-block dispatch groups.
(2) If a notice has been sent in accordance with subclause (1), the notice remains valid until the earliest of—
- (a) completion of the trading periods set out in the notice; or
- (b) receipt of another notice from the system operator in accordance with subclause (1) for the same block dispatch group for the same trading period or trading periods; or
- (c) receipt of a notice from the system operator that the block security constraint no longer exists; or
- (d) receipt of an instruction from the system operator in accordance with clause 13.75(1)(f) for the same block dispatch group for the applicable trading period, and such instruction remains valid for the trading periods specified in that instruction.
(3) [Revoked]

Compare: Electricity Governance Rules 2003 rules 3.6.3 to 3.6.5 section III part G

Clause 13.61 Heading: amended, on 5 October 2017, by clause 358(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.61(1): amended, on 5 October 2017, by clause 358(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.61(1)(a) and (b): amended, on 1 February 2016, by clause 79(1) and (2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.61(2)(c): amended, on 1 February 2016, by clause 79(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.61(2)(c): amended, on 5 October 2017, by clause 358(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.61(2)(d): amended, on 1 November 2018, by clause 86 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.61(3): revoked, on 15 May 2014, by clause 44 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

13.62 Frequency of price-responsive schedules and non-response schedules

(1) The system operator must use reasonable endeavours to commence preparing a price-responsive schedule and a non-response schedule—
- (a) once in every 4th trading period throughout the trading day, for a period covering—
  - (i) the trading period in which the system operator commences preparing the relevant schedule; and
  - (ii) the following 71 trading periods; and
- (b) once in each trading period for a period covering—
  - (i) the trading period in which the system operator commences preparing the relevant schedule; and
  - (ii) the following 7 trading periods.
(2) The system operator must use reasonable endeavours to ensure that—
- (a) each time it prepares a price-responsive schedule, it prepares a non-response schedule at the same time; and
- (b) each time it prepares a non-response schedule, it prepares a price-responsive schedule at the same time.
(3) The system operator must complete a schedule—
- (a) if it commenced preparing the schedule under subclause (1)(a), by the end of the trading period after the trading period in which the system operator commenced preparing the schedule; and
- (b) if it commenced preparing the schedule under subclause (1)(b), by the end of the trading period in which the system operator commenced preparing the schedule.

Compare: Electricity Governance Rules 2003 rule 3.7 section III part G

Clause 13.62: substituted, on 28 June 2012, by clause 35 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.63 Trading period information to be made available to clearing manager

The system operator must, by 0730 hours of each trading day, make the final information provided to the system operator under subpart 1 in relation to each trading period of the previous trading day available to the clearing manager on WITS or through an approved system.

Compare: Electricity Governance Rules 2003 rule 3.8 section III part G

Clause 13.63 Heading: amended, on 5 October 2017, by clause 359(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.63 Heading: amended, by clause 29(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.63: amended, on 5 October 2017, by clause 359(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.63: amended, by clause 29(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.64 Station dispatch may occur

(1) A generator may elect to have its generating plant dispatched as a station dispatch group by giving the system operator at least 15 business days’ notice in writing in the form set out in Form 8 of Schedule 13.1. The system operator must use best endeavours to implement the election within 15 business days after receiving the notice.
(2) The system operator must give written notice to the generator and the clearing manager of the effective date of the election at least 5 business days before the date. On and from the effective date, the procedures set out in clauses 13.65 and 13.66 must be followed by the system operator and the generator.

Compare: Electricity Governance Rules 2003 rule 3.9 section III part G

Clause 13.64(2): amended, on 5 October 2017, by clause 360 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.65 System operator to give notice of station security constraints

(1) The system operator must give notice on WITS to the generator of the implication of any station security constraints that apply within a station dispatch group. The notice must include—
- (a) the trading periods for which the station security constraint applies; and
- (b) how the station security constraint divides the generating units or generating stations of a station dispatch group into a sub-station dispatch group or limits the generation of a station dispatch group.
(2) If a notice has been sent in accordance with subclause (1), the notice remains valid until the earliest of—
- (a) completion of the trading periods set out in the notice; or
- (b) receipt of another notice from the system operator in accordance with subclause (1) for the same station dispatch group for the same trading period or trading periods; or
- (c) receipt of a notice from the system operator that the station security constraint no longer exists; or
- (d) receipt of an instruction from the system operator in accordance with clause 13.75(1)(g) for the same station dispatch group for the applicable trading period, and the instruction remains valid for the trading periods specified in the instruction.

Compare: Electricity Governance Rules 2003 rules 3.9.1 and 3.9.2 section III part G

Clause 13.65 Heading: amended, on 5 October 2017, by clause 361(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.65(1): amended, on 5 October 2017, by clause 361(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.65(2)(c): amended, on 5 October 2017, by clause 361(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.65(2)(d): amended, on 1 November 2018, by clause 87 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

13.66 Generator gives written notice of change from station to unit dispatch

If a generator changes the dispatch of its generating plant from a station dispatch group basis to a generating unit basis, it must give the system operator at least 15 business days’ notice in writing. The system operator must use best endeavours to implement the change within 15 business days of receiving a notice. The system operator must give written notice to the generator and the clearing manager of the effective date of the change at least 5 business days before the date.

Compare: Electricity Governance Rules 2003 rule 3.9.3 section III part G

Clause 13.66 Heading: amended, on 5 October 2017, by clause 362(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.66: amended, on 5 October 2017, by clause 362(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.67 Transmission of information

(1) [Revoked]
(2) If WITS or the publicly accessible approved system is unavailable for the purposes of making information available under clauses 13.58 to 13.66, the system operator must follow the backup procedures specified by the WITS manager.
(3) The WITS manager must specify the backup procedures referred to in subclause (2) following consultation with the Authority, the system operator and the clearing manager.

Compare: Electricity Governance Rules 2003 rules 3.10 to 3.12 section III part G

Clause 13.67 Heading: amended, on 5 October 2017, by clause 363(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.67(1): revoked, on 5 October 2017, by clause 363(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.67(2) and (3): replaced, on 5 October 2017, by clause 363(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.67(3): amended, by clauses 30(a) and (b) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

The dispatch process

13.68 [Revoked]

Compare: Electricity Governance Rules 2003 rule 4.1 section III part G

Clause 13.68 Heading: amended, on 28 June 2012, by clause 36(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.68(1): amended, on 28 June 2012, by clause 36(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.68: revoked, on 15 May 2014, by clause 22 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.69 [Revoked]

Compare: Electricity Governance Rules 2003 rule 4.2 section III part G

Clause 13.69: revoked, on 15 May 2014, by clause 22 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.69A

System operator to prepare dispatch schedule

(1) Except as provided in clause 13.72A, before each trading period, or as soon as practicable after the start of a trading period, the system operator must prepare a dispatch schedule for the trading period—
- (a) using the information described in clause 13.69B; and
- (b) in accordance with the methodology set out in Schedule 13.3.
(2) The system operator must prepare a new dispatch schedule for a trading period as frequently as the system operator considers is necessary during a trading period to meet the dispatch objective.

Clause 13.69A: inserted, on 15 May 2014, by clause 23 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.69A: replaced, by clause 31 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.69AA

System operator to assign price and quantity values

(1) In preparing each dispatch schedule, the system operator must assign the price and quantity values—
- (a) set out in clause 13.58AA(2) for the expected profile of demand under clause 13.69B(1)(d) for the demand at each GXP that is not the subject of a nominated dispatch bid; and
- (b) set out in clause 13.58AA(3) to the constraints specified in clause 12(5) of Schedule 13.3; and
- (c) set out in clause 13.58AA(4) to the model parameters specified in clause 1 of Schedule 13.2.
(2) The prices and quantities assigned in subclause (1) must be used in the dispatch schedule in accordance with the processes set out in Schedule 13.3AA.

Clause 13.69AA: inserted, by clause 32 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.69AAA

Grid owner to provide real time demand values to system operator

(1) Each grid owner must provide to the system operator real time net demand values (in MW) for each of its GXPs that are required by the system operator to calculate the expected profile of demand under clause 13.69B.
(2) A grid owner must, to the extent practicable, source the information required under subclause (1) from its grid revenue meters.

Clause 13.69AAA: inserted, by clause 32 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.69B

Inputs for dispatch schedule

(1) The system operator must use the following inputs to prepare a dispatch schedule:
- (a) offers and reserve offers, excluding the following:
  - (i) offers submitted by an intermittent generator under clause 13.6:
  - (ii) revised offers submitted by an intermittent generator under clause 13.18A:
  - (iii) offers submitted by a type B co-generator under clause 13.6:
  - (iv) revised offers submitted by a type B co-generator under clause 13.17; and
- (b) the quantities and prices specified in nominated dispatch bids (clause 13.7) and the quantities and prices specified in revised nominated dispatch bids (clauses 13.19A and 13.19B):
- (c) any price and quantity values assigned by the system operator under clause 13.69AA:
- (d) the expected profile of demand until the next dispatch schedule is produced by the system operator, where in an unsupplied demand situation—
  - (i) the expected profile of demand used to calculate dispatch instructions and dispatch notifications must reflect the demand expected to be supplied by the available offers; and
  - (ii) the expected profile of demand used to calculate dispatch price must be adjusted for the demand that was unable to be supplied by the available offers that was assigned a value by the system operator under clause 13.69AA(a), in accordance with the processes set out in Schedule 13.3AA:
- (e) the potential output of all intermittent generating stations, determined in accordance with subclause (4):
- (f) the current output levels of each generator or, if no such data is available, a reasonable estimate of the current output levels of each generator:
- (g) information from the grid owner (clauses 13.29 to 13.34) and revised information from the grid owner (clause 13.33) about—
  - (i) the AC transmission system configuration, capacity and losses; and
  - (ii) the capability of the HVDC link including the HVDC link configuration, the capacity of the HVDC link, the losses in the HVDC link, the direction of any transfer limit on the HVDC link, and any minimum or maximum transfer limits on the HVDC link; and
  - (iii) transformer configuration, capacity and losses:
- (h) information about voltage support:
- (i) the price order in the current dispatch schedule:
- (j) in relation to intermittent generators, any ramp rates agreed between the intermittent generator and the system operator.
(2) The system operator must incorporate, in each schedule prepared, any adjustments to the inputs described in subclause (1) that may be required to meet the dispatch objective.
(3) The system operator must use the information provided under clause 13.69AAA as part of its calculation of the expected profile of demand.
(4) The system operator must, in determining the potential output of an intermittent generating station for the purposes of subclause (1)(e), use the following information:
- (a) if the most recent dispatch instruction to the relevant intermittent generator for the intermittent generating station was not flagged, the actual output in MW of the intermittent generating station:
- (b) if the most recent dispatch instruction to the relevant intermittent generator for the intermittent generating station was flagged, the greater of—
  - (i) the forecast of generation potential specified in the intermittent generator's final offer for the relevant intermittent generating station submitted under clause 13.18A; and
  - (ii) the actual output in MW of the intermittent generating station:
- (c) if the intermittent generator and the system operator have agreed in writing that an alternative estimate may be provided, the alternative estimate of the potential output of the intermittent generating station provided by the relevant intermittent generator.

Clause 13.69B: inserted, by clause 32 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.69B(1)(g)(i): amended, on 1 March 2024, by clause 73(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.69B(1)(g)(ii): replaced, on 1 March 2024, by clause 73(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.69B(1)(g)(iii): amended, on 1 March 2024, by clause 73(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.69C

Contents of each dispatch schedule

Each dispatch schedule prepared by the system operator must contain the information specified in the table in Schedule 13.3B, as indicated by a X in column 3 of the table.

Clause 13.69C: inserted, by clause 32 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.69D

System operator to verify accuracy of dispatch prices and dispatch reserve prices

The system operator must verify the accuracy of dispatch prices and dispatch reserve prices in each dispatch schedule using the method specified in the policy statement.

Clause 13.69D: inserted, by clause 32 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.70 System operator may depart from dispatch schedule

The system operator may exercise discretion in departing from the dispatch schedule only if it is necessary to meet—
- (a) the dispatch objective; or
- (b) the requirements of clause 8.5 in relation to restoration of the power system.

Compare: Electricity Governance Rules 2003 rule 4.3 section III part G

13.71 [Revoked]

Compare: Electricity Governance Rules 2003 rule 4.4 section III part G

Clause 13.71(d): amended, on 28 June 2012, by clause 37 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.71: substituted, on 15 May 2014, by clause 24 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.71(1): amended, on 8 August 2019, by clause 4 of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.71(1)(b), (d) and (i): amended, on 5 October 2017, by clause 364 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.71(1)(b): amended, at 12.00 pm on 19 September 2019, by clause 17(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.71(1)(c): replaced, at 12.00 pm on 19 September 2019, by clause 17(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.71(1)(e): replaced, at 12.00 pm on 19 September 2019, by clause 17(3) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.71(3): inserted, at 12.00 pm on 19 September 2019, by clause 17(4) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.71: revoked, by clause 33 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.72 System operator to issue dispatch instructions and dispatch notifications

(1) The system operator must implement each dispatch schedule, and any departure from a dispatch schedule under clause 13.70 by—
- (a) issuing dispatch instructions to,—
  - (i) generators; and
  - (ii) ancillary service agents; and
  - (iii) dispatchable load purchasers (other than dispatch notification purchasers) that have submitted nominated dispatch bids;
- (b) issuing dispatch notifications to dispatch notification purchasers and dispatch notification generators.
(2) The system operator must issue each dispatch instruction and each dispatch notification in a reasonable and timely manner to enable the participant to which the dispatch instruction or dispatch notification is issued to comply with the dispatch instruction or dispatch notification.
(3) Despite subclause (1), the system operator is not required to issue a dispatch instruction to a participant if—
- (a) the dispatch instruction is—
  - (i) to provide a quantity of active power under clause 13.73(1)(a); or
  - (ii) to provide a quantity of instantaneous reserve under clause 13.73(1)(b); and
- (c) the dispatch instruction would differ from the most recent dispatch instruction issued to the participant by 1 MW or less.

Compare: Electricity Governance Rules 2003 rule 4.5 section III part G

Clause 13.72: substituted, on 15 May 2014, by clause 25 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.72: replaced, by clause 34 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.72A

Dispatch schedule primary modelling system unavailable

(1) Where the system operator’s primary modelling system for preparing and implementing a dispatch schedule is unavailable, the system operator—
- (a) must issue dispatch instructions and dispatch notifications using the backup procedure specified by it from time to time and using the inputs available to it at the relevant time; and
- (b) is not required to prepare a dispatch schedule that complies with the requirements set out in clause 13.69A(1)(a) and clause 13.69A(1)(b).
(2) When the system operator issues dispatch instructions in accordance with clause 13.72A(1), such dispatch instructions will be deemed to comprise a dispatch schedule for the purposes of clause 13.72(1).

Clause 13.72A: inserted, by clause 35 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.73 Content of dispatch instructions and dispatch notifications

(1) The system operator must ensure that each dispatch instruction and dispatch notification it issues under clause 13.72(1) instructs the generator, ancillary service agent, or dispatchable load purchaser to carry out 1 of the following:
- (a) provide a quantity of active power:
- (b) provide a quantity of instantaneous reserve:
- (c) provide a quantity and quality of reserve power or alternative to regulate frequency continuously:
- (d) provide a quantity of reactive power:
- (e) adjust transformer tap positions to maintain voltage levels:
- (f) provide a level of voltage:
- (g) synchronise or de-synchronise generating plant within the current trading period or the next trading period either directly or in accordance with any process that may be agreed with the generator:
- (h) switch on or switch off schemes for over frequency tripping where such capability exists in generating plant that a generator has offered to provide to the system operator:
- (i) manage the generating plant within a block dispatch group or station dispatch group so as to ensure the largest single reserve risk within that block dispatch group or station dispatch group does not exceed the relevant maximum reserve risk advised by the system operator for the North Island or the South Island for each trading period:
- (j) manage the total aggregate generation for each sub-block dispatch group or sub-station dispatch group for that generator so as not to exceed the total sum of the dispatched quantities for each generating plant or generating unit comprising that sub-block dispatch group or sub-station dispatch group for the duration of the notice received under clauses 13.60, 13.61, or 13.64 to 13.66:
- (k) manage the total aggregate generation for each block dispatch group or station dispatch group for that generator so as to meet the total sum of the dispatched quantities for each generating station or generating unit comprising that block dispatch group or station dispatch group:
- (l) use a specified quantity of electricity.
(1A) The system operator must include an indication (flag) in each dispatch instruction it issues to an intermittent generator under clause 13.72(1)(a) if the intermittent generator is dispatched for a trading period at a quantity less than the potential output of the relevant intermittent generating station.
(1B) For the purposes of subclause (1A), the potential output of an intermittent generating station is the potential output for the relevant intermittent generating station determined by the system operator under clause 13.69B(4).
(2) [Revoked]

Compare: Electricity Governance Rules 2003 rule 4.6 section III part G

Clause 13.73 Heading: amended, on 3 October 2013, by clause 6(a) of the Electricity Industry Participation (Technology Neutral Language in Frequency Keeping) Code Amendment 2013.

Clause 13.73: amended, on 3 October 2013, by clause 6(b) and (c) of the Electricity Industry Participation (Technology Neutral Language in Frequency Keeping) Code Amendment 2013.

Clause 13.73: substituted, on 15 May 2014, by clause 26 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.73(1): amended, on 8 August 2019, by clause 5 of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.73(1): amended, on 1 November 2022, by clause 36(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.73(1)(c): amended, on 3 October 2013, by clause 6(d) of the Electricity Industry Participation (Technology Neutral Language in Frequency Keeping) Code Amendment 2013.

Clause 13.73(1)(i): amended, on 5 October 2017, by clause 365 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.73(1)(l): inserted, on 1 November 2022, by clause 36(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.73(1A) and (1B): inserted, at 12.00 pm on 19 September 2019, by clause 18 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.73(1B): amended, on 1 November 2022, by clause 36(4) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.73(2): revoked, on 1 November 2022, by clause 36(5) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.74 [Revoked]

Compare: Electricity Governance Rules 2003 rule 4.7 section III part G

Clause 13.74: substituted, on 3 October 2013, by clause 7 of the Electricity Industry Participation (Technology Neutral Language in Frequency Keeping) Code Amendment 2013.

Clause 13.74: revoked, on 15 May 2014, by clause 27 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.75 Form of dispatch instruction and dispatch notification

(1) When issuing a dispatch instruction or dispatch notification under clause 13.72(1), the system operator must specify—
- (a) the generating plant, generating unit, block dispatch group, station dispatch group, interruptible load, dispatch-capable load station, or frequency keeping units to which the dispatch instruction or dispatch notification applies; and
- (b) the desired outcome of the dispatch instruction or dispatch notification; and
- (c) if the start time for the dispatch instruction or dispatch notification differs from the issue time, the start time within the current trading period or the next trading period; and
- (d) if specific ramp rates are concerned, a specific target time to reach the desired outcome; and
- (e) the time at which the dispatch instruction or dispatch notification was issued; and
- (f) any block security constraint that occurs within a block dispatch group and how the block security constraint divides the generating stations or generating units of a block dispatch group into sub-block dispatch groups as part of such a dispatch instruction or dispatch notification; and
- (g) any station security constraint that occurs within a station dispatch group and how the station security constraint divides the generating stations or generating units of a station dispatch group into sub-station dispatch groups; and
- (h) if it is a dispatch instruction or dispatch notification specified in clause 13.73(1)(i), the maximum reserve risk for the relevant island; and
- (i) when issuing a dispatch instruction or dispatch notification to a dispatchable load purchaser, the trading period for which the dispatch instruction or dispatch notification is issued.

Compare: Electricity Governance Rules 2003 rule 4.8 section III part G

Clause 13.75(a): amended, on 3 October 2013, by clause 8 of the Electricity Industry Participation (Technology Neutral Language in Frequency Keeping) Code Amendment 2013.

Clause 13.75(1): amended, on 15 May 2014, by clause 28(a) & (b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.75(1)(f): amended, on 1 February 2016, by clause 80(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.75(1)(g): amended, on 1 February 2016, by clause 80(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.75(1)(h): inserted, on 15 May 2014, by clause 28(c) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.75(2): inserted, on 15 May 2014, by clause 28(d) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.75: replaced, on 1 November 2022, by clause 37 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.76 System operator to issue and log dispatch instructions and dispatch notifications

(1) The system operator must issue dispatch instructions and dispatch notifications—
- (a) to each generator (other than a generator receiving dispatch instructions in its capacity as an ancillary service agent) and each dispatchable load purchaser, using an approved system; and
- (b) to each ancillary service agent, using an approved system or as otherwise agreed in the relevant ancillary service arrangement.
(2) The system operator must log and record each dispatch instruction and each dispatch notification.
(3) Each generator and each ancillary service agent must log each dispatch instruction received from the system operator.
(4) The system operator must provide a copy of each dispatch instruction and each dispatch notification—
- (a) to the clearing manager, by 1600 hours on the 7th business day of the billing period after the billing period in which the system operator issues and logs the dispatch instruction or dispatch notification; and
- (b) to the Authority, by 1600 hours on the first business day after the day on which the system operator issues and logs the dispatch instruction or dispatch notification.

Compare: Electricity Governance Rules 2003 rule 4.9 section III part G

Clause 13.76 Heading: replaced, on 5 October 2017, by clause 366(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.76: substituted, on 15 May 2014, by clause 29 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.76(1): replaced, on 5 October 2017, by clause 366(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.76(1)(a): amended, on 8 August 2019, by clause 6(1) of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.76(1)(c): amended, on 8 August 2019, by clause 6(2) of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.76(2): revoked, on 5 October 2017, by clause 366(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.76(5): substituted, on 19 May 2016, by clause 31 of the Electricity Industry Participation Code Amendment (System Operator and Alignment with Statutory Objective) 2016.

Clause 13.76(6): amended, on 15 May 2014, by clause 45 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.76: replaced, on 1 November 2022, by clause 38 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.77 [Revoked]

Compare: Electricity Governance Rules 2003 rule 4.9.1 section III part G

Clause 13.77: revoked, on 15 May 2014, by clause 30 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.78 [Revoked]

Compare: Electricity Governance Rules 2003 rule 4.9.2 section III part G

Clause 13.78: revoked, on 15 May 2014, by clause 30 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.79 Acknowledgement of dispatch instructions

If the system operator has issued a dispatch instruction or dispatch notification to a participant under clause 13.72(1), the participant must acknowledge to the system operator receipt of that dispatch instruction or dispatch notification—
- (a) within 4 minutes of receiving that dispatch instruction or dispatch notification; or
- (b) if the system operator and that person have entered into a written agreement relating to the person’s acknowledgement of receipt of dispatch instructions or dispatch notifications that conflicts with paragraph (a), in accordance with that agreement, which may include an agreement that the person need not acknowledge receipt of some or all dispatch instructions or dispatch notifications.

Compare: Electricity Governance Rules 2003 rule 4.9.3 section III part G

Clause 13.79: amended, on 21 September 2012, by clause 19 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.79: replaced, on 8 August 2019, by clause 7 of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.79: replaced, on 1 November 2022, by clause 39 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.80 [Revoked]

Compare: Electricity Governance Rules 2003 rule 4.9.4 section III part G

Clause 13.80(1): amended, on 21 September 2012, by clause 20 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.80(1): amended, on 15 May 2014, by clause 31 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.80(1): amended, on 15 May 2014, by clause 46 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.80(1): amended, on 23 February 2015, by clause 75 of the Electricity Industry Participation Code Amendment (Distributed Generation) 2014.

Clause 13.80(1): amended, on 5 October 2017, by clause 367 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.80: revoked, on 1 November 2022, by clause 40 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.81 Backup procedures if communication not possible

The system operator must follow the back-up procedures specified by it from time to time for issuing dispatch instructions and dispatch notifications if—
- (a) the relevant mechanism described in clause 13.76(1)(a) or 13.76(1)(b) is not available to issue dispatch instructions or dispatch notifications under clause 13.72(1); or
- (b) subject to any agreement referred to in clause 13.79(b), the system operator does not receive an acknowledgement from a participant of receipt of a dispatch instruction or dispatch notification within 10 minutes after issuing the dispatch instruction or dispatch notification.

Compare: Electricity Governance Rules 2003 rule 4.10 section III part G

Clause 13.81(1)(a): substituted, on 15 May 2014, by clause 32(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.81(1)(b): amended, on 15 May 2014, by clause 47 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.81(1): amended, on 8 August 2019, by clause 8(1), (2) and (3) of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.81(2): inserted, on 15 May 2014, by clause 32(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.81(2): amended, on 5 October 2017, by clause 368 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.81(2): amended, on 8 August 2019, by clause 8(4) of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.81: replaced, on 1 November 2022, by clause 41 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.82 Dispatch instructions to be complied with

(1) This clause applies to—
- (a) a generator; and
- (b) an ancillary service agent; and
- (c) a dispatched purchaser.
(2) Each participant to which this clause applies must comply with a dispatch instruction properly issued by the system operator under clause 13.72(1)(a) unless,—
- (a) in the participant's reasonable opinion,—
  - (i) personnel or plant safety is at risk; or
  - (ii) following the dispatch instruction will contravene a law; or
- (b) the generating plant or dispatch-capable load station is already responding to an automated signal to activate—
  - (i) capacity reserve; or
  - (ii) instantaneous reserve; or
  - (iii) automatic under-frequency load shedding; or
  - (iv) over frequency reserve; or
- (c) the participant is a generator or ancillary service agent acting in accordance with clause 13.86; or
- (d) the participant is an intermittent generator and the system operator has not flagged the dispatch instruction in accordance with clause 13.73(1A); or
- (e) the participant—
  - (i) is a generator; and
  - (ii) deviates from a dispatch instruction for active power to comply with clause 8.17; or
- (f) the participant—
  - (i) is a dispatched purchaser; and
  - (ii) deviates from the dispatch instruction—
    - (A) to comply with a request issued by the system operator under clause 5(4) of Technical Code B of Schedule 8.3; or
    - (B) to comply with clause 8.18; or
- (g) the participant—
  - (i) is a dispatched purchaser; and
  - (ii) cannot comply with the dispatch instruction because demand has been electrically disconnected under clause 7(20) of Technical Code B of Schedule 8.3; or
- (ga) the participant—
  - (i) is a dispatched purchaser; and
  - (ii) the dispatch instruction is issued for a trading period for which the latest nominated bid for the relevant dispatch-capable load station is a nominated non-dispatch bid; or
- (h) the participant—
  - (i) is a generator or an ancillary service agent; and
  - (ii) deviates from a dispatch instruction to comply with clause 9 of Technical Code B of Schedule 8.3; or
- (i) the participant—
  - (i) is a generator or an ancillary service agent; and
  - (ii) is acting in accordance with a commissioning plan or test plan that—
    - (A) is required under clause 2(6) of Technical Code A of Schedule 8.3; and
    - (B) expressly allows the generator or ancillary service agent to depart from the dispatch instruction for the purpose of the commissioning plan or test plan; and
  - (iii) has no reasonable means of complying with the dispatch instruction while acting in accordance with the commissioning plan or test plan; or
- (j) the participant is a type B co-generator and the system operator has not advised that there is—
  - (i) a grid emergency; or
  - (ii) a system constraint that directly affects the type B co-generator.
(3) A participant to which the exception in subclause (2)(a) applies must immediately advise the system operator of the circumstance in which the exception arises.
(4) If a dispatched purchaser is issued with more than 1 dispatch instruction for the same dispatch-capable load station for the same trading period, the dispatched purchaser must comply with the latest dispatch instruction.
(5) To avoid doubt, a dispatch instruction listed in clause 13.73(1)(b) to 13.73(1)(f) or 13.73(1)(h) is properly issued only if—
- (a) the generator or ancillary service agent to which the dispatch instruction is given has an enforceable contract with the system operator for the provision of services relating to the dispatch instruction; or
- (b) the dispatch instruction is consistent with an enforceable contract between the system operator and the generator or ancillary service agent for the provision of services relating to the dispatch instruction; or
- (c) the dispatch instruction is given for the purposes of clause 8.5 or 13.70; or
- (d) the dispatch instruction is consistent with—
  - (i) the asset owner performance obligations under clauses 8.22 to 8.24; or
  - (ii) the technical codes concerning voltage; or
  - (iii) a dispensation.
(6) A dispatched purchaser issued with a dispatch instruction for a dispatch-capable load station must not make changes to its other load at the same GXP with the intention of offsetting the dispatch instruction for the dispatch-capable load station.

Compare: Electricity Governance Rules 2003 rule 4.11 section III part G

Clause 13.82: substituted, on 15 May 2014, by clause 33 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.82: amended, on 1 November 2022, by clause 42 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.82(2)(d): amended, on 29 June 2017, by clause 34 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.82(2)(d)(ii): amended, on 27 May 2015, by clause 8(1) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.82(2)(d): replaced, at 12:00 pm on 19 September 2019, by clause 19 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.82(2)(g)(ii): amended, on 7 August 2014, by clause 23 of the Electricity Industry Participation Code Amendment (Extended Reserve) 2014.

Clause 13.82(2)(ga): inserted, on 1 December 2015, by clause 5 of the Electricity Industry Participation Code Amendment (Dispatchable Demand: Late Bid Revisions) 2015.

Clause 13.82(2)(h): inserted, on 18 April 2013, by clause 4 of the Electricity Industry Participation (Dispatch Compliance Minor Amendment) Code Amendment 2013.

Clause 13.82(2)(i)(iii): amended, on 27 May 2015, by clause 8(2) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.82(2)(j): inserted, on 27 May 2015, by clause 8(3) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.82(2)(g)(ii) and (2)(i): amended, on 5 October 2017, by clause 369 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.82(2)(g)(ii): amended, on 21 December 2012, by clause 31 of the Electricity Industry Participation Code Amendment (Automatic Under-Frequency Load Shedding Systems) 2021.

13.82A

Compliance with dispatch notifications

(1) Each dispatch notification purchaser and dispatch notification generator that receives a dispatch notification issued by the system operator under clause 13.72(1)(b) must either—
- (a) comply with the dispatch notification; or
- (b) comply with clause 13.19C.
(2) To avoid doubt, a dispatch notification generator is not prohibited from generating in a trading period for which it has submitted an offer of 0 MW.

Clause 13.82A: inserted, on 1 November 2022, by clause 43 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.82B

Dispatch notification purchasers and dispatch notification generators to provide information

(1) Each dispatch notification purchaser, in respect of each dispatch-capable load station for which it submits nominated bids, and each dispatch notification generator, in respect of each generating unit or generating station for which it submits offers, must provide information about the usage or provision of electricity, and any other information the Authority may reasonably require, for the purpose of monitoring compliance with Part 13.
(2) Each dispatch notification purchaser and each dispatch notification generator must agree with the Authority the format, time periods to be captured, method of delivery and frequency of delivery for information provided under subclause (1).

Clause 13.82B: inserted, on 1 March 2024, by clause 9 of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

13.83 Generators to make staff or facilities available to meet dispatch instructions and dispatch notifications

(1) Each generator must ensure, with respect to its generating plant that is the subject of an offer, that appropriate personnel or facilities are available to receive, acknowledge (subject to any agreement referred to in clause 13.79(b)), and comply with any dispatch instruction or dispatch notification given by the system operator to the generator.
(2) Nothing in this clause limits the ability of a generator to have a control centre that operates 1 or more items of generating plant by remote control.

Compare: Electricity Governance Rules 2003 rule 4.12 section III part G

Clause 13.83 Heading: amended, on 1 November 2022, by clause 44(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.83(1): amended, on 8 August 2019, by clause 9 of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.83: amended, on 1 November 2022, by clause 44(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.83A

Dispatchable load purchasers to make staff or facilities available to meet dispatch instructions and dispatch notifications

(1) Each dispatchable load purchaser that has submitted a nominated dispatch bid must ensure that appropriate personnel or facilities are available to receive and comply with each dispatch instruction or dispatch notification issued to the dispatchable load purchaser.
(2) Nothing in this clause limits the ability of a dispatchable load purchaser to have a control centre that operates 1 or more dispatch-capable load stations by remote control.

Clause 13.83A Heading: amended, on 1 November 2022, by clause 45(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.83A: inserted, on 15 May 2014, by clause 34 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.83A(1): amended, on 1 November 2022, by clause 45(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.84 Ancillary service agents to make staff or facilities available to meet dispatch instructions

Each ancillary service agent must ensure that appropriate personnel or facilities are available to receive, acknowledge (subject to any agreement referred to in clause 13.79(b)), and comply with any dispatch instruction given by the system operator to that ancillary service agent.

Compare: Electricity Governance Rules 2003 rule 4.13 section III part G

Clause 13.84: amended, on 8 August 2019, by clause 10 of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

13.85 Generators have flexibility within block dispatch group or station dispatch group

Each generator may synchronise, de-synchronise, or alter the output of any generating plant within a block dispatch group or station dispatch group if it first consults with the system operator with regard to such action.

Compare: Electricity Governance Rules 2003 rule 4.15 section III part G

13.86 Generators and ancillary service agents not obliged to comply with dispatch instructions below threshold

A generator, or ancillary service agent providing instantaneous reserve or frequency keeping, is not required to comply with 1 or more dispatch instructions given by the system operator in accordance with clause 13.72(1)(a) if implementing the dispatch instruction or those dispatch instructions together would change by less than or equal to—
(a) for ancillary service agents, 1 MW from the last dispatch instruction that the ancillary service agent complied with; or
(b) for generators other than type A co-generators, 1 MW from the last dispatch instruction that the generator complied with; or
(c) for type A co-generators, 5 MW from the last dispatch instruction that the type A co-generator complied with.

Compare: Electricity Governance Rules 2003 rule 4.16 section III part G

Cross-heading: revoked, on 28 June 2012, by clause 38(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.86: amended, on 15 May 2014, by clause 35 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.86: amended, on 8 August 2019, by clause 11 of the Electricity Industry Participation Code Amendment (Dispatch Service Enhancement) 2019.

Clause 13.86(b): amended, on 27 May 2015, by clause 9(1) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.86(c): amended, on 27 May 2015, by clause 9(2)(i) and (ii) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

13.86A

Intermittent generators must not substantially reduce generation

(1) An intermittent generator must not generate electricity during a trading period at a rate that is more than 30MW below the forecast of generation potential specified in the intermittent generator’s final offer for the trading period submitted under clause 13.18A, unless—
- (a) the intermittent generator reduces the output of the relevant intermittent generating station in order to comply with a flagged dispatch instruction under clause 13.73(1A), or any other instruction issued by the system operator; or
- (b) the intermittent generator has a bona fide physical reason.
(2) If an intermittent generator generates electricity during a trading period at a rate that is below the rate specified in subclause (1) for 1 or more trading periods in a calendar month, other than for one of the reasons specified in subclause (1)(a), the intermittent generator must provide a report to the Authority no later than the end of the next calendar month.
(3) A report provided to the Authority under subclause (2) must specify—
- (a) the trading periods in relation to which the intermittent generator generated electricity at a rate that was below the rate specified in subclause (1); and
- (b) in relation to each such trading period, an explanation of the reason for the intermittent generator generating electricity at a rate that was below the rate specified in subclause (1); and
- (c) if the intermittent generator considers that one of the reasons in subclause (1) applies in respect of any of the trading periods specified in the report, the intermittent generator's reasons for that view.

Clause 13.86A: inserted, at 12.00 pm on 19 September 2019, by clause 20 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.87 [Revoked]

Clause 13.87: revoked, on 28 June 2012, by clause 38(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.88 [Revoked]

Compare: Electricity Governance Rules 2003 rule 6 section III part G

Clause 13.88 Heading: amended, on 28 June 2012, by clause 39(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.88 (1)-(4): amended, on 28 June 2012, by clause 39(2)-(4) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.88: revoked, on 1 November 2022, by clause 47 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.89 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.1 section III part G

Clause 13.89 Heading: amended, on 28 June 2012, by clause 40(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.89: amended, on 28 June 2012, by clause 40(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.89: revoked, on 1 November 2022, by clause 48 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.90 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.2 section III part G

Clause 13.90 Heading: replaced, on 5 October 2017, by clause 370(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.90(1): amended, on 5 October 2017, by clause 370(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.90(1): amended, on 28 June 2012, by clause 41 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.90(1)(b)(i) and (ii): amended, on 1 February 2016, by clause 81 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.90(1)(b)(ii): substituted, on 15 May 2014, by clause 48 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.90(1)(b)(iii): amended, on 15 May 2014, by clause 36 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.90(1)(b)(iii)(A): amended, on 21 September 2012, by clause 21 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.90(2): replaced, on 5 October 2017, by clause 370(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.90: revoked, on 1 November 2022, by clause 49 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.91 [Revoked]

Compare: Electricity Governance Rules 2003 rules 7.3 to 7.5 section III part G

Clause 13.91 Heading: replaced, on 5 October 2017, by clause 371(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.91(1): revoked, on 5 October 2017, by clause 371(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.91(2) and (3): replaced, on 5 October 2017, by clause 371(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.91: revoked, on 1 November 2022, by clause 50 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.92 [Revoked]

Compare: Electricity Governance Rules 2003 rules 7.6 and 7.7 section III part G

Clause 13.92: replaced, on 5 October 2017, by clause 372 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.92: revoked, on 1 November 2022, by clause 51 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.93 [Revoked]

Compare: Electricity Governance Rules 2003 rules 7.8 and 7.9 section III part G

Clause 13.93 Heading: amended, on 5 October 2017, by clause 373(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.93(1): replaced, on 5 October 2017, by clause 373(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.93(2): amended, on 5 October 2017, by clause 373(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.93: revoked, on 1 November 2022, by clause 52 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.94 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.10 section III part G

Clause 13.94: revoked, on 1 November 2022, by clause 53 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.95 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.11 section III part G

Clause 13.95: revoked, on 1 November 2022, by clause 54 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.96 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.12 section III part G

Clause 13.96: substituted, on 15 May 2014, by clause 37 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.96: revoked, on 1 November 2022, by clause 55 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Grid emergencies

13.97 Grid emergency situations

(1) The system operator may, at any time, declare a grid emergency in accordance with Technical Code B of Schedule 8.3.
(2) Despite clauses 13.6 to 13.27 and clauses 13.37 to 13.54, if the system operator has declared a grid emergency,—
- (a) a generator may not reduce the MW specified in any of the offers made by the generator for the trading periods and grid injection points affected by the grid emergency, unless the generator has a bona fide physical reason that makes the reduction necessary; and
- (b) an ancillary service agent may not reduce the instantaneous reserve specified in any of the reserve offers made by the ancillary service agent for the trading periods and points of connection with the grid affected by the grid emergency, unless the ancillary service agent has a bona fide physical reason that makes the reduction necessary; and
- (c) the system operator must accept any reduction made under paragraphs (a) or (b).
(3) Subclause (2)(a) does not apply in relation to the MW specified in the forecast of generation potential specified in any of the offers made by an intermittent generator.

Compare: Electricity Governance Rules 2003 rules 8.1 and 8.2 section III part G

Clause 13.97(2): amended, on 29 June 2017, by clause 35(1) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.97(2)(a): amended, on 29 June 2017, by clause 35(2)(a) and (b) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.97(2)(a): amended, at 12.00 pm on 19 September 2019, by clause 21(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.97(2)(b): amended, on 29 June 2017, by clause 35(3)(a) and (b) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.97(3): inserted, at 12.00 pm on 19 September 2019, by clause 21(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.98 Generators and ancillary service agents may change other parameters

Despite clause 13.97(2), during a grid emergency,—
- (a) a generator may reduce the MW specified in any price band offered in respect of certain generating plant, if equivalent increased MW is, in substitution, offered for other items of generating plant owned or operated by that generator at grid injection points in the electrical or geographical region affected as specified in the system operator’s notice issued under clause 5(1) of Technical Code B of Schedule 8.3; and
- (b) an ancillary service agent may reduce the instantaneous reserves offered, if equivalent increased instantaneous reserves are, in substitution, offered by that ancillary service agent at points of connection with the grid in the electrical or geographical region affected as specified in the system operator’s notice issued under clause 5(1) of Technical Code B of Schedule 8.3; and
- (c) despite clauses 13.6 to 13.27, a generator may—
  - (i) submit revised offers in respect of generating plant already subject to an offer before the grid emergency, so that the total MW offered by the generator from the generating plant for that trading period is increased; and
  - (ii) submit new offers in respect of a generating plant not subject to an offer before the grid emergency; and
- (d) despite clause 13.17(2), a generator may submit a new price band or bands for new offers or revised offers in respect of the increased MW made under paragraph (c), but may not revise the price band or bands in respect of the MW offered before the notice of the grid emergency; and
- (e) despite clauses 13.37 to 13.54, an ancillary service agent may—
  - (i) submit revised reserve offers in respect of any instantaneous reserve already subject to a reserve offer before the grid emergency so that the total instantaneous reserve offered by the ancillary service agent for that trading period is increased; and
  - (ii) submit new reserve offers in respect of any instantaneous reserve not subject to a reserve offer before the grid emergency; and
- (f) despite clause 13.46(1A), an ancillary service agent may submit a new price band or bands for new reserve offers or revised reserve offers in respect of the increased instantaneous reserve made under paragraph (e), but may not revise the type of instantaneous reserve or the price band or bands in respect of the instantaneous reserve offered before the notice of the grid emergency.

Compare: Electricity Governance Rules 2003 rule 8.3 section III part G

Clause 13.98(a): amended, on 29 June 2017, by clause 36(1)(a), (b) and (c) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.98(a) and (b): amended, on 5 October 2017, by clause 374 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.98(b): amended, on 29 June 2017, by clause 36(2)(a) and (b) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.98(c)(i): amended, on 29 June 2017, by clause 36(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.98(d): amended, on 29 June 2017, by clause 36(4)(a), (b) and (c) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.98(e): amended, on 29 June 2017, by clause 36(5) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.98(f): amended, on 29 June 2017, by clause 36(6)(a), (b) and (c) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.99 Effect of grid emergency on total quantities bid

Despite clauses 13.19A to 13.27, if the system operator has declared a grid emergency—
(a) a purchaser may not increase the aggregate quantity of electricity specified in all of the nominated bids made by the purchaser for the trading periods and GXPs affected by the grid emergency unless the purchaser has a bona fide physical reason that necessitates the increase; and
(b) the system operator must accept any revision made under paragraph (a).

Compare: Electricity Governance Rules 2003 rule 8.4 section III part G

Clause 13.99: amended, on 29 June 2017, by clause 37 of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.99(a): amended, on 28 June 2012, by clause 42 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.99(a): amended, on 15 May 2014, by clause 38 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.99A

[Revoked]

Clause 13.99A: revoked, on 1 November 2022, by clause 56 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.100 Purchasers may change other parameters

Despite clause 13.99, during a grid emergency, a purchaser may—
(a) increase a nominated bid’s quantities, or submit nominated bids at GXPs that were not subject to nominated bids before the grid emergency, if equivalent decreased quantities are, in substitution, bid for GXPs in the affected electrical or geographical region, as specified in the formal notice issued by the system operator, which were the subject of nominated bids made by the purchaser; and
(b) decrease a nominated bid’s quantities.

Compare: Electricity Governance Rules 2003 rule 8.5 section III part G

Clause 13.100(a): substituted, on 28 June 2012, by clause 43(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.100(b): amended, on 28 June 2012, by clause 43(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.100(a): amended, on 15 May 2014, by clause 40(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.100(b): substituted, on 15 May 2014, by clause 40(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.101 Reporting requirements in respect of grid emergencies

(1) If the system operator declares a grid emergency,—
- (a) the system operator must, within 12 hours of the conclusion of the grid emergency, publish a written report that describes the basis on which the system operator decided to declare the grid emergency; and
- (b) a generator that reduced the MW specified in any price band in any offer, and an ancillary service agent that reduced the instantaneous reserve specified in any reserve offer, made by that person in respect of the point of connection with the grid and trading periods affected by the grid emergency must report the reduction to the Authority in writing together with details of the bona fide physical reason for the reduction claimed by the generator or ancillary service agent. A reduction must be reported to the Authority by 1700 hours on the 1^st business day after the trading day on which the reduction was made.
- (c) [Revoked]
(2) [Revoked]

Compare: Electricity Governance Rules 2003 rules 8.6 and 8.7 section III part G

Clause 13.101(1)(a): substituted, on 1 February 2016, by clause 82 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.101(1)(b): amended, on 28 June 2012, by clause 44(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.101(1)(b): amended, on 29 June 2017, by clause 38(1)(a), (b) and (c) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.101(1)(c): substituted, on 28 June 2012, by clause 44(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.101(1)(c): revoked, on 29 June 2017, by clause 38(2) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

Clause 13.101(2): revoked, on 29 June 2017, by clause 38(3) of the Electricity Industry Participation Code Amendment (Shortened Gate Closure and Revised Bid and Offer Provisions) 2017.

13.102 Reporting obligations of system operator

By the 10^th business day of each calendar month, the system operator must inform the Authority in writing of any discretionary action the system operator has taken under clause 13.70, in the previous calendar month, that required departure from the dispatch schedule.

Compare: Electricity Governance Rules 2003 rule 9 section III part G

Clause 13.102(1)(b): amended, on 28 June 2012, by clause 45 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.102(1)(d): amended, on 1 February 2016, by clause 83 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.102: substituted, on 19 May 2016, by clause 32 of the Electricity Industry Participation Code Amendment (System Operator and Alignment with Statutory Objective) 2016.

System operator to provide and make information available

Cross Heading: amended, on 1 November 2022, by clause 57 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.103 [Revoked]

Clause 13.103: revoked, on 28 June 2012, by clause 46 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.104 System operator to make information available

(1) As soon as practicable after the system operator has completed preparing a price-responsive schedule and a non-response schedule, the system operator must make available on WITS, for each trading period in the schedule length period, the information specified in the table in Schedule 13.3B, as indicated by a X—
- (a) in the case of the price-responsive schedule, in column 4 of the table; and
- (b) in the case of the non-response schedule, in column 5 of the table.
(2) Subclause (3) applies to—
- (a) each price-responsive schedule prepared under clause 13.62(1)(a):
- (b) each non-response schedule prepared under clause 13.62(1)(a).
(3) Despite subclause (1), for each schedule to which this subclause applies, the system operator is not required to make available on WITS the information referred to in subclause (1) for the trading periods covered by—
- (a) the price-responsive schedule prepared under clause 13.62(1)(b):
- (b) the non-response schedule prepared under clause 13.62(1)(b).

Compare: Electricity Governance Rules 2003 rule 10.2 section III part G

Clause 13.104 Heading: replaced, on 5 October 2017, by clause 375(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.104: substituted, on 28 June 2012, by clause 47 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.104(1): replaced, on 1 November 2022, by clause 58(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.104(1)(a)(iii): amended, at 12:00 pm on 19 September 2019, by clause 22 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.104(1) and (1)(a)(iv): amended, on 5 October 2017, by clause 375(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.104(1)(a)(x): revoked, on 1 November 2012, by clause 8(1) of the Electricity Industry Participation (Part 13 Minor Amendments) Code Amendment 2012.

Clause 13.104(1)(a)(xvi) and (xvii): inserted, on 1 June 2013, by clause 7 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.104(1)(a) & (b): amended, on 15 May 2014, by clause 41 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.104(1)(c): inserted, on 1 November 2012, by clause 8(2) of the Electricity Industry Participation (Part 13 Minor Amendments) Code Amendment 2012.

Clause 13.104(1)(c): amended, on 3 October 2013, by clause 9 of the Electricity Industry Participation (Technology Neutral Language in Frequency Keeping) Code Amendment 2013.

Clause 13.104(3): amended, on 5 October 2017, by clause 375(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.104(3): amended, on 1 November 2022, by clause 58(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.104A

System operator to make information available in respect of dispatch schedule

The system operator must, each time the system operator implements a dispatch schedule, make available on WITS the information specified in the table in Schedule 13.3B, as indicated by a X in column 6 of the table.

Clause 13.104A: inserted, on 1 November 2022, by clause 59 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.105 [Revoked]

Clause 13.105: revoked, on 28 June 2012, by clause 48 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

13.105A

Information to be made available to purchasers, generators, and ancillary service agents

(1) At the same time as the system operator is required to make information available in accordance with clause 13.104(1), the system operator must make available on WITS—
- (aa) for each dispatchable load purchaser that has submitted a nominated dispatch bid, information from the current non-response schedule relating to the scheduling of the dispatchable load purchaser’s nominated dispatch bids for the trading periods covered in the schedule length period; and
- (a) for each purchaser, information from the current price-responsive schedule relating to the scheduling of the purchaser’s bids for the trading periods covered in the schedule length period; and
- (b) for each generator, information from the current price-responsive schedule and non-response schedule relating to the scheduling of the generator’s offers for the trading periods covered in the schedule length period; and
- (c) for each ancillary service agent who has submitted a reserve offer for the scheduling period, information from the current price-responsive schedule and non-response schedule relating to the scheduling of the ancillary service agent’s reserve offers for the trading periods covered in the schedule length period.
(2) Subclause (3) applies to—
- (a) each price-responsive schedule prepared under clause 13.62(1)(a):
- (b) each non-response schedule prepared under clause 13.62(1)(a).
(3) Despite subclause (1), for each schedule to which this subclause applies, the system operator is not required to make available on WITS the information set out in subclause (1) for the trading periods covered by—
- (a) the price-responsive schedule prepared under clause 13.62(1)(b):
- (b) the non-response schedule prepared under clause 13.62(1)(b).

Clause 13.105A Heading: amended, on 5 October 2017, by clause 376(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.105A: inserted, on 28 June 2012, by clause 49 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.105A(1): amended, on 5 October 2017, by clause 376(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.105A(1): amended, on 1 November 2022, by clause 60 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.105A(1)(aa): inserted, on 15 May 2014, by clause 42 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.105A(3): amended, on 5 October 2017, by clause 376(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.106 Transmission of information

(1) [Revoked]
(2) If WITS is unavailable for the purposes of making information available under clauses 13.104 to 13.105A, the system operator must follow the backup procedures specified by the WITS manager.
(3) The WITS manager must specify the backup procedures referred to in subclause (2) following consultation with the Authority, the system operator, the clearing manager, purchasers, generators, and ancillary service agents.

Compare: Electricity Governance Rules 2003 rules 10.5 to 10.7 section III part G

Clause 13.106 Heading: amended, on 5 October 2017, by clause 377(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.106(1): amended, on 28 June 2012, by clause 50 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13.106(1): revoked, on 5 October 2017, by clause 377(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.106(2) and (3): replaced, on 5 October 2017, by clause 377(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.106(3): amended, on 1 November 2022, by clause 61 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Subpart 3—Must-run dispatch auction

13.107 Contents of this subpart

This subpart provides for must-run dispatch auctions.

Compare: Electricity Governance Rules 2003 rule 1 section IV part G

13.108 Clearing manager to hold must-run dispatch auctions

Each day the clearing manager must hold an auction as set out in clauses 13.117 to 13.130, at which generators may bid for auction rights in time blocks.

Compare: Electricity Governance Rules 2003 rule 2 section IV part G

13.109 Clearing manager authorises generators

(1) If a generator’s bid at an auction is successful the clearing manager must authorise the generator to offer electricity at 0 price for the relevant time block and trading period.
(2) The clearing manager must specify in each authorisation—
- (a) the quantity of electricity that the generator may offer under the authorisation; and
- (b) the trading periods for which the authorisation is valid; and
- (c) how much the generator must pay the clearing manager for the auction rights.

Compare: Electricity Governance Rules 2003 rules 2.1 and 2.2 section IV part G

13.110 Clearing manager must calculate amounts owing

(1) The clearing manager must calculate the amount owing by each generator for the auction rights the generator has acquired in the previous billing period.
(2) Any auction revenue owing by a generator in relation to a billing period must be advised to the generator by the clearing manager under subpart 4 of Part 14.

Compare: Electricity Governance Rules 2003 rules 2.3 and 2.4 section IV part G

Clause 13.110 heading: amended, on 24 March 2015, by clause 9(1) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.110: amended, on 24 March 2015, by clause 9(2) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

13.111 Purchasers must receive auction revenue

Each purchaser who purchases electricity at a grid exit point must receive auction revenue from generators in accordance with clause 13.112(1).

Compare: Electricity Governance Rules 2003 rule 2.5 section IV part G

13.112 Clearing manager must calculate amounts receivable

(1) The clearing manager must calculate and credit purchasers for auction revenue for each trading period in accordance with the following formula:

AR_p = (TAR_g/APB)*(P_q/TP_q)

where

AR_p

is the auction revenue receivable by a purchaser

TAR_g

is the total auction revenue for a time block owing by generators as calculated by the clearing manager in accordance with clause 13.110(1)

APB

is the number of trading periods in that time block

P_q

is the total electricity purchased by that purchaser from the clearing manager during the trading period as shown by the reconciliation information calculated by the reconciliation manager under clause 15.21 to 15.26

TP_q

is the total electricity purchased by all purchasers from the clearing manager during the trading period as shown by reconciliation information calculated by the reconciliation manager under clause 15.21 to 15.26.

(2) Any auction revenue owing to a purchaser in relation to a billing period must be advised to the purchaser by the clearing manager under subpart 4 of Part 14.

Compare: Electricity Governance Rules 2003 rules 2.6 and 2.7 section IV part G

Clause 13.112: amended, on 24 March 2015, by clause 10 of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

13.113 Generators choose grid injection points at which they will exercise rights conferred

A generator who acquires auction rights may exercise them in respect of any generating plant it owns and at a grid injection point during the relevant time block.

Compare: Electricity Governance Rules 2003 rule 2.8 section IV part G

13.114 Transmission of auction information

(1) Except where specified otherwise in this Part, all information in relation to auctions must be transmitted using WITS.
(2) If WITS is not available to transmit information under this clause, the clearing manager must follow the backup procedures specified by the WITS manager.
(3) The WITS manager must specify the backup procedures referred to in subclause (2) following consultation with the Authority, generators, and the clearing manager.

Compare: Electricity Governance Rules 2003 rules 2.9 to 2.11 section IV part G

Clause 13.114 Heading: amended, on 1 February 2016, by clause 84(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.114(1): substituted, on 1 February 2016, by clause 84(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.114: replaced, on 5 October 2017, by clause 378 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.115 Trading in auction rights permitted

(1) A generator who has acquired auction rights at an auction (the "transferring generator") may transfer all or some of those rights to another generator.
(2) The generator who acquires the rights by transfer takes them on the same terms that apply to the transferring generator.
(3) A generator may transfer its rights by transferring, selling, assigning, or otherwise disposing of its ownership interest.

Compare: Electricity Governance Rules 2003 rule 2.12 section IV part G

Clause 13.115(1): amended, on 20 December 2021, by clause 58(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

Clause 13.115(2): amended, on 20 December 2021, by clause 58(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

Clause 13.115(3): inserted, on 20 December 2021, by clause 58(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

13.116 Offers at 0

(1) Subject to subclause (2), a generator may offer electricity to the clearing manager at a 0 price only if the generator has an authorisation from an auction in accordance with clauses 13.108 to 13.115.
(2) A generator may offer electricity to the clearing manager at a 0 price without an authorisation from an auction only in relation to—
- (a) generating plant that comes within the scope of clauses 13.24 or 13.26; or
- (b) offers submitted before publication of auction results, but, if authorisation from an auction is not granted, such offers are cancelled or revised so that they no longer contain a 0 price before 1300 hours on the day before the trading day for which the offers apply.

Compare: Electricity Governance Rules 2003 rules 2.13 and 2.14 section IV part G

Must-run auction process

13.117 Clearing manager must conduct auctions

(1) The clearing manager must conduct an auction every day.
(2) Each generator is eligible to take part in each auction.
(3) The clearing manager must specify the format for bidding and must accept auction bids only if they are made in that format. Each auction bid must be made in positive numbers.

Compare: Electricity Governance Rules 2003 rules 3.1 to 3.3 section IV part G

13.118 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.4 section IV part G

Clause 13.118: revoked, on 1 February 2016, by clause 85 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

13.119 Historic load data

(1) Subject to subclause (3), by 1100 hours on a day that is 2 days before an auction, a grid owner must advise the clearing manager of the information described in subclause (2) by—
- (a) giving written notice to the clearing manager; or
- (b) using WITS.
(2) The information is the total load that was on the grid that is owned or operated by the grid owner, on the day that is 363 days before the date of the auction.
(3) If the trading day following the auction is—
- (a) a national holiday, the day referred to in subclause (2) is deemed to be the Sunday before the day preceding the date of the auction by 363 days; or
- (b) a business day, but the 363^rd day before the date of the auction is a national holiday, the day referred to in subclause (2) is deemed to be the next business day after the national holiday.

Compare: Electricity Governance Rules 2003 rule 3.5 section IV part G

Clause 13.119: replaced, on 5 October 2017, by clause 379 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.120 Quantity available for auction

The clearing manager must calculate the quantity of auction rights available in each time block at each auction as follows:

quantity of auction rights available in each time block = 0.8. * ldf_tb

where

ldf_tb

is the lowest demand forecast for a time block, which is the lowest demand in any trading period on the day for which load must be advised under clause 13.119 (in an interval that equates to the time block)

Compare: Electricity Governance Rules 2003 rule 3.6 section IV part G

Clause 13.120: amended, on 5 October 2017, by clause 380 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.121 Notice of auction and deadline for auction bids

(1) For each auction, by any time up to 1100 hours on the day before the auction, the clearing manager must give written notice or use WITS to advise each generator of the quantity of auction rights available in each time block at the auction to be held the following day and must invite auction bids for those auction rights.
(2) A generator who wishes to bid at an auction must submit auction bids by 0900 hours on the day that the auction is to be held.

Compare: Electricity Governance Rules 2003 rule 3.7 section IV part G

Clause 13.121(1): amended, on 5 October 2017, by clause 381 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.122 Revising, cancelling and extending auction bids

(1) A generator may, by giving written notice or using WITS, revise or cancel an auction bid up to 0900 hours on the day of the auction to which the auction bid relates.
(2) Each auction bid is valid for only 1 auction unless the generator expressly states when it makes the auction bid that the auction bid is to remain valid until cancelled.

Compare: Electricity Governance Rules 2003 rule 3.8 section IV part G

Clause 13.122(1): amended, on 5 October 2017, by clause 382 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.123 Contents of auction bids

(1) A generator may make up to 5 auction bids for each time block.
(2) Each auction bid must specify for each time block the quantity of auction rights sought and the price that the generator is prepared to pay if its auction bid succeeds.

Compare: Electricity Governance Rules 2003 rule 3.9 section IV part G

13.124 Ranking of auction bids

(1) When bidding closes at 0900 hours each day the clearing manager must rank the auction bids it has received in descending order by price per MWh.
(2) Beside each auction bid the clearing manager must record the quantity of auction rights sought by the relevant generator.

Compare: Electricity Governance Rules 2003 rule 3.10 section IV part G

13.125 Matching auction bids to rights

(1) The clearing manager must match the ranked auction bids against all the auction rights available in each time block until the auction bids equal the quantity of auction rights available.
(2) The auction bids made by a generator succeed if the bids are matched (in whole or part) against the auction rights available.

Compare: Electricity Governance Rules 2003 rule 3.11 section IV part G

13.126 Similar and identical auction bids

(1) If the clearing manager receives more than 1 auction bid at the same price, and there are not enough auction rights available to satisfy the auction bids, the clearing manager must award auction rights to each relevant bidder in the order in which the clearing manager received the auction bids (as evidenced by the time stamp provided by the clearing manager’s computer system).
(2) If the clearing manager receives more than 1 auction bid at the same price at the same time it will award auction rights to each relevant bidder in proportion to the volume of auction rights the bidders sought in each of their auction bids.

Compare: Electricity Governance Rules 2003 rule 3.12 section IV part G

13.127 Auction payment

The amount owing by a successful bidder in an auction is the quantity of electricity awarded by the clearing manager to that bidder multiplied by the clearing auction price.

Compare: Electricity Governance Rules 2003 rule 3.13 section IV part G

Clause 13.127: amended, on 24 March 2015, by clause 11 of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

13.128 Results

By 1100 hours on the day of each auction the clearing manager must give written notice or use WITS to advise—
- (a) each generator that has bid at an auction of the outcome of the auction; and
- (b) all generators and purchasers of the quantity and price of all successful auction bids made at the auction.

Compare: Electricity Governance Rules 2003 rule 3.14 section IV part G

Clause 13.128: amended, on 5 October 2017, by clause 383 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.129 Authorisation to successful bidders

The clearing manager must give an authorisation, by way of a written notice or using WITS, to each generator that secures auction rights at an auction. The authorisation must set out the auction rights the generators secured at the auction and the price payable for them.

Compare: Electricity Governance Rules 2003 rule 3.15 section IV part G

Clause 13.129: amended, on 5 October 2017, by clause 384 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.130 Records

The clearing manager must maintain a complete record for 3 years of all quantities of auction rights offered, all auction bids received, and the prices achieved in each time block at each auction. A generator may require the clearing manager to provide, in writing or using WITS, information relating to the generator's auction bids and auction results at any time within that period.

Compare: Electricity Governance Rules 2003 rule 3.16 section IV part G

Clause 13.130: amended, on 5 October 2017, by clause 385 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Subpart 4—Pricing

13.131 Contents of this subpart

This subpart provides for the processes by which—
- (a) the clearing manager prepares and makes available on WITS interim prices and interim reserve prices; and
- (b) interim prices and interim reserve prices become final prices and final reserve prices.

Compare: Electricity Governance Rules 2003 rule 1 section V part G

Clause 13.131: replaced, on 1 November 2022, by clause 62 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.132 [Revoked]

Compare: Electricity Governance Rules 2003 rule 2 section V part G

Clause 13.132(a): amended, on 1 June 2013, by clause 8 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.132(b): replaced, on 5 October 2017, by clause 386 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.132: revoked, on 1 November 2022, by clause 63 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.133 [Revoked]

Compare: Electricity Governance Rules 2003 rule 2A section V part G

Clause 13.133: revoked, on 1 November 2022, by clause 64 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.134 [Revoked]

Compare: Electricity Governance Rules 2003 rule 2B section V part G

Clause 13.134(2): substituted, on 23 December 2011, by clause 4 of the Electricity Industry Participation (High Spring Washer Price Situation) Code Amendment 2011.

Clause 13.134(2A) and (2B): inserted, on 23 December 2011, by clause 4 of the Electricity Industry Participation (High Spring Washer Price Situation) Code Amendment 2011.

Clause 13.134(1): amended, on 21 September 2012, by clause 5(1) of the Electricity Industry Participation (High Spring Washer Price Situation) Code Amendment 2012.

Clause 13.134(2): substituted, on 21 September 2012, by clause 5(2) of the Electricity Industry Participation (High Spring Washer Price Situation) Code Amendment 2012.

Clause 13.134(2A), (2B) and (3): revoked, on 21 September 2012, by clause 5(2) of the Electricity Industry Participation (High Spring Washer Price Situation) Code Amendment 2012.

Clause 13.134(4), (5) and (6): inserted, on 21 September 2012, by clause 5(2) of the Electricity Industry Participation (High Spring Washer Price Situation) Code Amendment 2012.

Clause 13.134: revoked, on 1 November 2022, by clause 65 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Rules governing the preparation of interim prices

Cross Heading: amended, on 1 November 2022, by clause 66 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.134A

Methodology for calculating interim prices

The clearing manager must calculate interim prices and interim reserve prices for a trading period in accordance with the following formula:

where

I

is the interim price or interim reserve price

t

is the sequential number of a dispatch price or dispatch reserve price in the set n in the trading period

n

is the total number of dispatch prices or dispatch reserve prices that apply during the trading period

P_t

is the dispatch price or dispatch reserve price as made available on WITS that applies for the trading period at time T_t

T_t

is the start time of the sequential numbered t dispatch price or dispatch reserve price for the trading period, as made available on WITS

but
(a) if there is no dispatch price or dispatch reserve price for t=1 in a trading period, the dispatch price or dispatch reserve price (as the case may be) for the t=1 period is the forecast price or forecast reserve price in the most recent price-responsive schedule received by the clearing manager prior to the start of the trading period; and
(b) if there is also no forecast price or forecast reserve price under paragraph (a), the dispatch price or dispatch reserve price (as the case may be) for the t=1 period is the final price or final reserve price (as the case may be) from the equivalent trading period determined in accordance with clause 13.134B.

Clause 13.134A: inserted, on 1 November 2022, by clause 67 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.134A: amended, on 1 July 2025, by clause 4 of the Electricity Industry Participation Code Amendment (Backup Interim Price Method) 2025.

13.134B

Equivalent trading periods for interim prices where there is no forecast price or forecast reserve price

(1) Subject to subclauses (2) to (4), the equivalent trading period will be the trading period that falls on the same day of the week and starts at the same time of the day as the t=1 period, in the week before the t=1 period, provided that trading period is not a trading period—
- (a) that falls on a national holiday; or
- (b) that has no final price or final reserve price (as the case may be); or
- (c) in respect of which the Authority has decided to investigate, and is yet to resolve, a potential undesirable trading situation; or
- (d) for which the calculation of the interim price or interim reserve price (as the case may be) under clause 13.134A used a dispatch price or forecast price, or dispatch reserve price or forecast reserve price (as the case may be), from a dispatch schedule or price-responsive schedule that the system operator assigned price and quantity values to under clause 13.69AA or 13.58AA, respectively.
(2) If subclause (1)(a) to (1)(d) applies, the equivalent trading period will be the trading period that falls on the same day of the week and starts at the same time of the day as the t=1 period in the week before the week before the t=1 period, and so on, until an equivalent trading period is arrived at that meets the requirements of subclause (1).
(3) If the t=1 period falls on a national holiday—
- (a) the equivalent trading period will be the trading period that starts at the same time of day as the t=1 period on the closest previous Sunday to the national holiday in respect of which subclause (1)(a) to (1)(d) does not apply; and
- (b) if subclause (1)(a) to (1)(d) applies to that Sunday, the equivalent trading period will be the trading period that starts at the same time of the day as the t=1 period on the next closest previous Sunday to the national holiday, and so on, until a Sunday is arrived at in respect of which subclause (1)(a) to (1)(d) does not apply.
(4) Where, due to daylight savings, the same time of the day does not exist or two such times exist,—
- (a) if the same time of the day does not exist, the next most recent week’s trading period must be used instead; and
- (b) if more than one same time of the day exists, the most recent time must be used.

Clause 13.134B: inserted, on 1 July 2025, by clause 5 of the Electricity Industry Participation Code Amendment (Backup Interim Price Method) 2025.

13.135 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.1 section V part G

Clause 13.135: amended, on 1 June 2013, by clause 9 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.135: revoked, on 1 November 2022, by clause 68 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.135A

[Revoked]

Clause 13.135A: inserted, on 1 June 2013, by clause 10 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.135A(1): amended, on 5 October 2017, by clause 387(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.135A(2A): inserted, on 19 January 2017, by clause 5(1) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2016.

Clause 13.135A(5)(a): replaced, on 5 October 2017, by clause 387(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.135A(6): inserted, on 19 January 2017, by clause 5(2) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2016.

Clause 13.135A(6): amended, on 5 October 2017, by clause 387(c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.135A: revoked, on 1 November 2022, by clause 69 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.135B

[Revoked]

Clause 13.135B: inserted, on 1 June 2013, by clause 10 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.135B(b)(ii): amended, on 19 January 2017, by clause 6(1) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2016.

Clause 13.135B(1)(b): replaced, on 5 October 2017, by clause 388(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.135B(2): amended, on 5 October 2017, by clause 388(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.135B(2) and (3): inserted, on 19 January 2017, by clause 6(2) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2016.

Clause 13.135B(3)(b): amended, on 5 October 2017, by clause 388(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.135B: revoked, on 1 November 2022, by clause 70 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.135C

[Revoked]

Clause 13.135C: inserted, on 1 June 2013, by clause 10 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.135C: revoked, on 1 November 2022, by clause 71 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Generators to give grid owner half-hour metering information

Cross heading: amended, on 19 December 2014, by clause 27 of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

13.136 Offered embedded generators to provide half-hour metering information

(1) Using an approved system or by written notice, each generator must give the relevant grid owner half-hour metering information under clause 13.138 in relation to generating plant—
- (a) that injects electricity directly into a local network or an embedded network; or
- (b) if the meter configuration is such that the electricity flows into a local network without first passing through a grid injection point or grid exit point metering installation.
(1A) For the purposes of subclause (1), the relevant grid owner is—
- (a) in relation to a generator (other than an embedded generator), the grid owner of the grid to which the generator's generation is connected; and
- (b) in relation to a generator that is an embedded generator, the grid owner of the grid to which the local network to which the embedded generator is directly or indirectly connected, is connected.
(2) Subclause (1) does not apply in respect of—
- (a) any unoffered generation; or
- (b) [Revoked]
- (c) a dispatch notification generator.

Compare: Electricity Governance Rules 2003 rule 3.2.1 section V part G

Clause 13.136 Heading: amended, at 12.00 pm on 19 September 2019, by clause 23(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.136(1): substituted, on 19 December 2014, by clause 28 of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.136(1): amended, on 5 October 2017, by clause 389(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.136(1): amended, at 12.00 pm on 19 September 2019, by clause 23(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.136(1A): inserted, on 19 December 2014, by clause 28 of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.136(1A): amended, on 23 February 2015, by clause 75 of the Electricity Industry Participation Code Amendment (Distributed Generation) 2014.

Clause 13.136(1A)(a) and (b): amended, on 5 October 2017, by clause 389(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.136(2): substituted, on 27 May 2015, by clause 10 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.136(2): amended, at 12.00 pm on 19 September 2019, by clause 23(3)(a) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.136(2)(b)(i): revoked, at 12.00 pm on 19 September 2019, by clause 23(3)(b) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.136(2)(b): revoked, on 1 November 2022, by clause 72(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.136(2)(c): inserted, on 1 November 2022, by clause 72(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.137 Unoffered grid-connected generators and grid-connected type B industrial co-generation to provide half-hour metering information

(1) Using an approved system or by written notice, each generator must give the relevant grid owner half-hour metering information for—
- (a) unoffered generation from a generating station with a point of connection to the grid; and
- (b) [Revoked]
- (c) electricity supplied from a type B industrial co-generating station with a point of connection to the grid.
(2) [Revoked]
(3) If the half-hour metering information is not available, the generator must give the relevant grid owner a reasonable estimate of such data using an approved system or by written notice.

Compare: Electricity Governance Rules 2003 rule 3.2.2 section V part G

Clause 13.137 Heading: substituted, on 27 May 2015, by clause 11(1) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.137 Heading: amended, on 5 October 2017, by clause 390(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.137 Heading: replaced, at 12.00 pm on 19 September 2019, by clause 24(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.137: amended, on 19 December 2014, by clause 29 of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.137(1)(b): amended, on 27 May 2015, by clause 11(2) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.137(1)(b): revoked, at 12.00 pm on 19 September 2019, by clause 24(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.137(1)(c): inserted, on 27 May 2015, by clause 11(3) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.137(1) and (3): amended, on 5 October 2017, by clause 390(2)(a) and (b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.137(2): revoked, on 1 November 2022, by clause 73 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.137A

Offered grid-connected intermittent generators to provide half-hour metering information

(1) Using an approved system or by written notice, each intermittent generator must, in relation to an intermittent generating station with a point of connection to the grid, give the relevant grid owner half-hour metering information for the intermittent generating station.
(2) This clause does not apply to unoffered generation.
(3) [Revoked]
(4) If the half-hour metering information is not available, the intermittent generator must give the relevant grid owner a reasonable estimate of such data.

Clause 13.137A: inserted, at 12.00 pm on 19 September 2019, by clause 25 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.137A(3): revoked, on 1 November 2022, by clause 74 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.138 Generator’s half-hour metering information to be adjusted for losses

(1) Each generator must provide the information required by clauses 13.136, 13.137, and 13.137A—
- (a) adjusted for losses (if any) relative to the grid injection point or, for embedded generators the grid exit point, at which it offered the electricity; and
- (b) in the manner and form that the relevant grid owner stipulates; and
- (c) by 1000 hours on a trading day for each trading period of the previous trading day.
(2) To avoid doubt, each generator must provide the half-hour metering information required under this clause—
- (a) in accordance with the requirements of Part 15 for the collection of that generator’s volume information; or
- (b) from a source and in a manner agreed between the generator and the grid owner.

Compare: Electricity Governance Rules 2003 rule 3.2.3 section V part G

Clause 13.138 Heading: amended, on 15 May 2014, by clause 43 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.138(1): amended, at 12.00 pm on 19 September 2019, by clause 26 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.138(1)(b): amended, on 19 December 2014, by clause 30 of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.138(1)(c): amended, on 1 November 2022, by clause 75(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.138(2): replaced, on 1 November 2022, by clause 75(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.138A

[Revoked]

Clause 13.138A: inserted, on 15 May 2014, by clause 44 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.138A(1): amended, on 19 December 2014, by clause 31(1) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.138A(1): amended, on 5 October 2017, by clause 391 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.138A(2)(b): amended, on 19 December 2014, by clause 31(2) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.138A: revoked, on 1 November 2022, by clause 76 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.138B

[Revoked]

Clause 13.138B: inserted, on 15 May 2014, by clause 44 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.138B: revoked, on 1 November 2022, by clause 77 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.138C

Generators to arrange for regular audits

Each generator with one or more obligations under clauses 13.136 to 13.138 of this Code must, in respect of these obligations,—
- (a) obtain and maintain certification under Schedule 15.1 to be permitted to perform, or to have performed by an agent or agents, any of these obligations; and
- (b) arrange to be audited regularly under Part 16A.

Clause 13.138C: inserted, on 1 March 2024, by clause 74 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.139 Half-hour metering information part of input information

The adjusted half-hour metering information provided under clauses 13.136 to 13.138 forms part of the input information in the formula in clause 13.141A.

Compare: Electricity Governance Rules 2003 rule 3.2.4 section V part G

Clause 13.139: substituted, on 19 December 2014, by clause 32 of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.139: amended, on 1 November 2022, by clause 78 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.140 Generators to advise grid owner of having provided half-hour metering information

(1) [Revoked]
(2) If a generator provides half-hour metering information to a grid owner under clauses 13.136 to 13.138, the generator must—
- (a) advise the relevant grid owner of this by 1000 hours on the day the generator provided the half-hour metering information to the relevant grid owner; and
- (b) at the same time, advise the relevant grid owner if any of the half-hour metering information provided under clauses 13.136–13.137A is missing information, incorrect and/or estimated.

Compare: Electricity Governance Rules 2003 rule 3.2.5 section V part G

Clause 13.140 Heading: amended, on 5 October 2017, by clause 392 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.140 Heading: amended, on 1 November 2022, by clause 79(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.140: substituted, on 15 May 2014, by clause 45 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.140(1): revoked, on 1 November 2022, by clause 79(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.140(2): substituted, on 19 December 2014, by clause 33 of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.140(2): replaced, on 1 November 2022, by clause 79(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.140A

Generators to resolve issues

If a generator cannot provide half-hour metering information, has provided incorrect half-hour metering information, or has provided estimated half-hour metering information under clauses 13.136–13.137A, the generator must, by 1200 hours on the 6^th business day following the day the generator provided the half-hour metering information to the relevant grid owner,—
- (a) supply the missing information; or
- (b) replace incorrect information; or
- (c) replace estimated information with final information.

Clause 13.140A: inserted, on 1 November 2022, by clause 80 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.141 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.3 section V part G

Clause 13.141(1)(a) & (b): substituted, on 15 May 2014, by clause 46(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.141(1)(b)(i): amended, on 19 December 2014, by clause 34(1) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.141(1)(b)(i): amended, on 27 May 2015, by clause 12(1) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.141(1)(b)(i): replaced, at 12.00 pm on 19 September 2019, by clause 27(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.141(1)(b)(iii): amended, on 5 October 2017, by clause 393(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.141(1)(c): amended, on 27 May 2015, by clause 12(2) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.141(1)(caa): inserted, at 12.00 pm on 19 September 2019, by clause 27(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.141(1)(ca): inserted, on 15 May 2014, by clause 46(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.141(1)(ca): amended, on 1 December 2015, by clause 6 of the Electricity Industry Participation Code Amendment (Dispatchable Demand: Late Bid Revisions) 2015.

Clause 13.141(1)(e): amended, on 15 May 2014, by clause 46(c) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.141(1)(e): amended, on 5 October 2017, by clause 393(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.141(1AA): inserted, on 27 May 2015, by clause 12(3) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.141(1AA)(a): revoked, at 12.00 pm on 19 September 2019, by clause 27(3) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 13.141(1A): inserted, on 15 May 2014, by clause 46(d) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.141(3): amended, on 5 October 2017, by clause 393(c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.141(4): amended, on 19 December 2014, by clause 34(2) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.141(4): amended, on 5 October 2017, by clause 393(d) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.141(5): amended, on 21 September 2012, by clause 22 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.141(5): amended, on 19 December 2014, by clause 34(3) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.141(5): replaced, on 5 October 2017, by clause 393(e) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.141: revoked, on 1 November 2022, by clause 81 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.141A

Grid owner to calculate adjusted load information

(1) A grid owner must calculate the adjusted load for each point of connection to the grid that is advised by the clearing manager under clause 13.141B(1) using the following formula:

AL = SG + (Xgrid – Igrid)

where

AL

is the adjusted load information

SG

is the generation information provided under clauses 13.136–13.138

Xgrid

is the export from the grid at the point of connection

Igrid

is the injection into the grid at the point of connection

(2) If there is no supplied generation then the adjusted load information will be the net flow at the point of connection as measured by the grid owner.
(3) Where any of the inputs specified in subclause (1) are unavailable, the grid owner may estimate that input.

Clause 13.141A: inserted, on 1 November 2022, by clause 82 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.141B

Adjusted load information to be provided to the clearing manager

(1) The clearing manager must advise a grid owner of the points of connection to the grid for which the grid owner must provide it with the adjusted load information.
(2) A grid owner must use reasonable endeavours to provide the clearing manager with adjusted load information for the relevant points of connection to the grid advised by the clearing manager by 1200 hours on a trading day for each trading period on the previous trading day.
(3) A grid owner and the clearing manager must agree the format and method of delivery for the adjusted load information.

Clause 13.141B: inserted, on 1 November 2022, by clause 82 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.142 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.4 section V part G

Clause 13.142 Heading: amended, on 1 June 2013, by clause 11(1) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.142 Heading: replaced, on 5 October 2017, by clause 394(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.142(1): amended, on 1 June 2013, by clause 11(2) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.142(1): amended, on 5 October 2017, by clause 394(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.142(1)(b): amended, on 1 June 2011, by clause 5 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2011.

Clause 13.142(2): amended, on 5 October 2017, by clause 394(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.142: revoked, on 1 November 2022, by clause 83 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.143 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.5 section V part G

Clause 13.143 Heading: amended, on 5 October 2017, by clause 395(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.143(1), (3) and (4): amended, on 5 October 2017, by clause 395(2)(a) to (c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.143(5): inserted, on 5 October 2017, by clause 395(2)(d) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.143: revoked, on 1 November 2022, by clause 84 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.144 [Revoked]

Compare: Electricity Governance Rules 2003 rules 3.6 and 3.6A section V part G

Clause 13.144 Heading: amended, on 1 June 2013, by clause 12(1) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.144 Heading: amended, on 5 October 2017, by clause 396(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.144(1): amended, on 1 June 2013, by clause 12(2)(a) and (b) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.144(1): amended, on 19 January 2017, by clause 7(1) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2016.

Clause 13.144(1)(a): replaced, on 5 October 2017, by clause 396(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.144(1)(a) and (b): amended, on 1 June 2013, by clause 12(2)(c) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.144(1)(c): amended, on 1 June 2013, by clause 12(2)(d) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.144(1)(d): inserted, on 1 June 2013, by clause 12(2)(e) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.144(1A): inserted, on 19 January 2017, by clause 7(2) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2016.

Clause 13.144(2): amended, on 1 June 2013, by clause 12(3) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.144(2), (3), (4) and (5): amended, on 5 October 2017, by clause 396(2)(b) and (c) and (3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.144(3), (4) and (5): inserted, on 19 January 2017, by clause 7(3) of the Electricity Industry Participation Code Amendment (Scarcity Pricing) 2016.

Clause 13.144: revoked, on 1 November 2022, by clause 85 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.145 Grid owner to give written notice that estimated data given

(1) If a grid owner gives the clearing manager estimated adjusted load information or is unable to provide adjusted load information under clause 13.141B, the grid owner must, by the time specified in clause 13.141B(2),—
- (a) give written notice to the clearing manager of any adjusted load information that is estimated or unable to be provided; and
- (b) give details in the notice of the grid exit points and grid injection points to which the estimated information relates or is unable to be provided; and
- (c) specify in the notice the trading periods for which the adjusted load information is estimated or unable to be provided for each relevant grid exit point and grid injection point.
(2) Where a grid owner is unable to deliver the adjusted load information or the adjusted load information contains estimates, the grid owner will deliver or provide replacement information within 7 business days following the day the generator provided the half-hour metering information to the grid owner.

Compare: Electricity Governance Rules 2003 rule 3.7 section V part G

Clause 13.145 Heading: amended, on 5 October 2017, by clause 397(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.145(1)(a): amended, on 5 October 2017, by clause 397(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.145(1)(c): amended, on 19 December 2014, by clause 35(1) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.145(1)(d) and (e): inserted, on 19 December 2014, by clause 35(2) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.145(1)(d): amended, on 27 May 2015, by clause 13 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 13.145(2): inserted, on 5 October 2017, by clause 397(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.145: replaced, on 1 November 2022, by clause 86 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.146 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.8 section V part G

Clause 13.146 Heading: amended, on 1 June 2013, by clause 13(1) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.146(1) and (2): amended, on 5 October 2017, by clause 398(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.146(2A): inserted, on 1 June 2013, by clause 13(2) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.146(4): amended, on 15 May 2014, by clause 47 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.146(4): amended, on 19 December 2014, by clause 36 of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.146(4): amended, on 5 October 2017, by clause 398(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.146: revoked, on 1 November 2022, by clause 87 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.147 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.9 section V part G

Clause 13.147 Heading: amended, on 5 October 2017, by clause 399(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.147: substituted, on 15 May 2014, by clause 48 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.147(1), (2) and (3): amended, on 5 October 2017, by clause 399(2)(a) and (b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.147(1)(b) and (d): revoked, on 19 December 2014, by clause 37(1) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.147(1)(c): amended, on 19 December 2014, by clause 37(2) of the Electricity Industry Participation Code Amendment (Minor Code Amendments) (No 3) 2014.

Clause 13.147(2)(a): replaced, on 5 October 2017, by clause 399(2)(c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.147(4): inserted, on 5 October 2017, by clause 399(2)(d) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.147: revoked, on 1 November 2022, by clause 88 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.148 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.10 section V part G

Clause 13.148: amended, on 15 May 2014, by clause 49 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.148: revoked, on 1 November 2022, by clause 89 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.149 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.11 section V part G

Clause 13.149 Heading: replaced, on 5 October 2017, by clause 400(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.149 Heading: amended, on 1 November 2018, by clause 88(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.149: amended, on 15 May 2014, by clause 50 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.149(2)(a) and (b): amended, on 5 October 2017, by clause 400(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.149(2)(a) and (b): amended, on 1 November 2018, by clause 88(2)(a) and (b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.149(2)(c): revoked, on 1 November 2018, by clause 88(2)(c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.149: revoked, on 1 November 2022, by clause 90 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.150 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.12 section V part G

Clause 13.150 Heading: replaced, on 5 October 2017, by clause 401(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.150: amended, on 15 May 2014, by clause 51 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.150(2)(a) and (b): amended, on 5 October 2017, by clause 401(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.150(2)(a) and (b): amended, on 1 November 2018, by clause 89(a) and (b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.150(2)(c): revoked, on 1 November 2018, by clause 89(c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.150: revoked, on 1 November 2022, by clause 91 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.151 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.13 section V part G

Clause 13.151: revoked, on 1 November 2022, by clause 92 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.152 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.14 section V part G

Clause 13.152 Heading: amended, on 5 October 2017, by clause 402(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.152: substituted, on 15 May 2014, by clause 52 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.152: amended, on 5 October 2017, by clause 402(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.152: revoked, on 1 November 2022, by clause 93 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.153 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.15 section V part G

Clause 13.153: amended, on 5 October 2017, by clause 403 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.153: revoked, on 1 November 2022, by clause 94 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.154 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.16 section V part G

Clause 13.154 Heading: amended, on 15 May 2014, by clause 53(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.154 Heading: amended, on 5 October 2017, by clause 404(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.154(1): substituted, on 15 May 2014, by clause 53(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.154(1): amended, on 5 October 2017, by clause 404(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.154(1A): inserted, on 15 May 2014, by clause 53(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.154(1A): amended, on 5 October 2017, by clause 404(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.154(2): amended, on 15 May 2014, by clause 53(c) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.154(2): amended, on 5 October 2017, by clause 404(4) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.154: revoked, on 1 November 2022, by clause 95 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.155 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.17 section V part G

Clause 13.155 Heading: amended, on 5 October 2017, by clause 405(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.155: amended, on 15 May 2014, by clause 54 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.155(1)(a): replaced, on 5 October 2017, by clause 405(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.155(2): inserted, on 5 October 2017, by clause 405(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.155: revoked, on 1 November 2022, by clause 96 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.156 [Revoked]

Compare: Electricity Governance Rules 2003 rules 3.18 and 3.18A section V part G

Clause 13.156 Heading: replaced, on 5 October 2017, by clause 406(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.156(1): amended, on 5 October 2017, by clause 406(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.156(2): amended, on 5 October 2017, by clause 406(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.156: revoked, on 1 November 2022, by clause 97 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.157 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.19 section V part G

Clause 13.157(1) and (2): amended, on 5 October 2017, by clause 407 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.157: revoked, on 1 November 2022, by clause 98 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.158 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.20 section V part G

Clause 13.158 Heading: amended, on 5 October 2017, by clause 408(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.158(1)(a): replaced, on 5 October 2017, by clause 408(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.158(2): inserted, on 5 October 2017, by clause 408(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.158: revoked, on 1 November 2022, by clause 99 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.159 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.21 section V part G

Clause 13.159 Heading: replaced, on 5 October 2017, by clause 409(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.159(a) and (b): amended, on 5 October 2017, by clause 409(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.159: revoked, on 1 November 2022, by clause 100 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.160 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.21A section V part G

Clause 13.160: revoked, on 1 November 2022, by clause 101 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.161 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.21B section V part G

Clause 13.161(1): amended, on 5 October 2017, by clause 410(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.161(2)(a): replaced, on 5 October 2017, by clause 410(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.161(3): inserted, on 5 October 2017, by clause 410(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.161: revoked, on 1 November 2022, by clause 102 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.162 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.21C section V part G

Clause 13.162 Heading: amended, on 5 October 2017, by clause 411(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.162(a) and (b): amended, on 5 October 2017, by clause 411(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.162: revoked, on 1 November 2022, by clause 103 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.163 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.22 section V part G

Clause 13.163: amended, on 5 October 2017, by clause 412 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.163: revoked, on 1 November 2022, by clause 104 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.164 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.23 section V part G

Clause 13.164(a) to (d): amended, on 5 October 2017, by clause 413(a) to (d) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.164: revoked, on 1 November 2022, by clause 105 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.165 [Revoked]

Compare: Electricity Governance Rules 2003 rules 3.24 and 3.25 section V part G

Clause 13.165 Heading: replaced, on 5 October 2017, by clause 414(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.165(1): amended, on 5 October 2017, by clause 414(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.165: revoked, on 1 November 2022, by clause 106 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.166 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26 section V part G

Clause 13.166 Heading: amended, on 15 May 2014, by clause 55 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.166(1) and (2): amended, on 15 May 2014, by clause 55 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.166: revoked, on 1 November 2022, by clause 107 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.166A

[Revoked]

Clause 13.166A Heading: amended, on 5 October 2017, by clause 415(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.166A: inserted, on 1 June 2013, by clause 14 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.166A(1): amended, on 5 October 2017, by clause 415(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.166A: revoked, on 1 November 2022, by clause 108 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Publication of interim prices

Cross Heading: replaced, on 1 November 2022, by clause 109 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.167 Clearing manager to make interim prices available

The clearing manager must make interim prices and interim reserve prices for a trading period available on WITS as soon as practicable after the end of that trading period.

Compare: Electricity Governance Rules 2003 rule 3.26A section V part G

Clause 13.167 Heading: amended, on 5 October 2017, by clause 416(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.167: amended, on 5 October 2017, by clause 416(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.167(aa): inserted, on 1 June 2013, by clause 15 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.167(c): amended, on 21 September 2012, by clause 23 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.167(c): amended, on 5 October 2017, by clause 416(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.167: replaced, on 1 November 2022, by clause 110 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Pricing error process

Cross Heading: inserted, on 1 November 2022, by clause 111 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.168 When pricing error may be claimed or investigated

After the clearing manager makes an interim price or interim reserve price available on WITS, but before the relevant price has become a final price or final reserve price (as applicable),—
- (a) a person may make a pricing error claim to the clearing manager in respect of that price under clause 13.170; and
- (b) the clearing manager may investigate a potential pricing error in respect of that price under clause 13.170A.

Compare: Electricity Governance Rules 2003 rule 3.26B section V part G

Clause 13.168: amended, on 5 October 2017, by clause 417 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.168: replaced, on 1 November 2022, by clause 112 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.169 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26C section V part G

Clause 13.169: revoked, on 1 November 2022, by clause 113 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.170 Method and timing for claiming pricing error has occurred

To claim that a pricing error has occurred, an error claimant must—
- (a) submit a pricing error claim to the clearing manager in such manner and form as the clearing manager may specify from time to time; and
- (b) include information in its claim to demonstrate—
  - (i) that, except where the error claimant is the Authority or system operator, the error claimant has been affected by the claimed pricing error; and
  - (ii) the basis for the claim that a pricing error has occurred; and
  - (iii) the trading periods affected by the claimed pricing error; and
- (c) comply with paragraphs (a) and (b) no later than 1200 hours on the 1st business day following the trading day on which the clearing manager made available on WITS the interim price or interim reserve price in respect of which the pricing error has been claimed.

Compare: Electricity Governance Rules 2003 rule 3.26D section V part G

Clause 13.170(b): amended, on 21 September 2012, by clause 24 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.170(c): replaced, on 5 October 2017, by clause 418(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.170(d): amended, on 5 October 2017, by clause 418(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.170: replaced, on 1 November 2022, by clause 114 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.170A

Clearing manager may investigate potential pricing errors

(1) The clearing manager may investigate a potential pricing error.
(2) If the clearing manager decides to investigate a potential pricing error, it must commence the investigation no later than 1200 hours on the 1st business day following the trading day on which the clearing manager made available on WITS the interim price or interim reserve price that is the subject of that investigation.

Clause 13.170A: inserted, on 1 November 2022, by clause 115 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.171 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26E section V part G

Clause 13.171: replaced, on 5 October 2017, by clause 419 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.171: revoked, on 1 November 2022, by clause 116 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.172 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26F section V part G

Clause 13.172: amended, on 5 October 2017, by clause 420 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.172: revoked, on 1 November 2022, by clause 117 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.173 Process when pricing error claim received

(1) If the clearing manager receives a pricing error claim submitted under clause 13.170 by the time prescribed by that clause, the clearing manager must, as soon as practicable,—
- (a) check that the information required by that clause is included in the pricing error claim; and
- (b) confirm to the error claimant that it has received the pricing error claim; and
- (c) either—
  - (i) confirm to the error claimant that the pricing error claim contains the required information; or
  - (ii) if the required information is not contained in the pricing error claim, request that the error claimant provide the clearing manager with the required information.
(2) The clearing manager must, no later than 1300 hours on the 1st business day following the trading day on which the clearing manager made available on WITS the interim price or interim reserve price in respect of which a pricing error has been claimed (with such pricing error claim having been submitted under clause 13.170 by the time prescribed by that clause), give a written notice on WITS and to the Authority, any person that has requested notice and the error claimant advising—
- (a) that a pricing error has been claimed; and
- (b) the name of the error claimant; and
- (c) the reasons the error claimant has given for the claim that a pricing error has occurred; and
- (d) the trading periods that the error claimant claims have been affected by the pricing error.
(3) The clearing manager must, no later than 1700 hours on the 2nd business day following the trading day on which the written notice referred to in subclause (2) was given, provide a report to the Authority that includes the following:
- (a) whether, in the clearing manager’s view, a pricing error has occurred:
- (b) the reasons for the clearing manager’s view:
- (c) a copy of all of the information that the clearing manager considered or received in relation to the pricing error which has been claimed.

Compare: Electricity Governance Rules 2003 rule 3.26G section V part G

Clause 13.173(c): amended, on 5 October 2017, by clause 421 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.173: replaced, on 1 November 2022, by clause 118 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.173A

Process when pricing error investigation commenced

(1) If the clearing manager decides to investigate a potential pricing error under clause 13.170A by the time prescribed by that clause the clearing manager must, no later than 1300 hours on the 1st business day following the trading day on which the clearing manager made available on WITS the interim price or interim reserve price in respect of which the potential pricing error is being investigated, give a written notice on WITS and to the Authority and any person that has requested notice advising—
- (a) that the clearing manager has decided to investigate a potential pricing error; and
- (b) the reasons for the investigation; and
- (c) the trading periods that the clearing manager believes may have been affected by the potential pricing error.
(2) The clearing manager must, no later than 1700 hours on the 2nd business day following the trading day on which the written notice referred to in subclause (1) was given, provide a report to the Authority that includes the following:
- (a) whether, in the clearing manager’s view, a pricing error has occurred:
- (b) the reasons for the clearing manager’s view:
- (d) a copy of all of the information that the clearing manager considered or received in relation to the potential pricing error which was investigated.

Clause 13.173A: inserted, on 1 November 2022, by clause 119 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.173A(2): amended, on 1 March 2024, by clause 75 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.173B

Clearing manager may request information from error claimant or participant when pricing error claim received or pricing error investigation commenced

After the written notice referred to in clause 13.173(2) or 13.173A(1) is given but prior to the clearing manager being required to provide a report to the Authority under clauses 13.173(3) or 13.173A(2) (as applicable)—
- (a) the clearing manager may request that an error claimant or a participant provide the clearing manager with any information that the clearing manager reasonably requires in order to reach a view as to whether a pricing error has occurred; and
- (b) each error claimant and participant must comply with any request made by the clearing manager under paragraph (a) within 1 business day of the request being received.

Clause 13.173B: inserted, on 1 November 2022, by clause 119 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.173C

Authority to determine whether pricing error has occurred

(1) No later than 1700 hours on the 2nd business day following the trading day on which the Authority receives a report from the clearing manager under clause 13.173(3) or clause 13.173A(2), the Authority must determine whether a pricing error has occurred.
(2) The Authority must, as soon as practicable after making its determination,—
- (a) advise the clearing manager of the determination in writing; and
- (b) give a written notice on WITS that includes the following information:
  - (i) the name of the error claimant (where a pricing error has been claimed):
  - (ii) in relation to a claim made under clause 13.170, the reasons the error claimant has given for the claim:
  - (iii) in relation to an investigation commenced by the clearing manager under clause 13.170A, the reasons the clearing manager has given for the investigation pursuant to clause 13.173A(1)(b):
  - (iv) the trading periods specified in the written notice given on WITS under clause 13.173(2) or clause 13.173A(1):
  - (v) the Authority's determination made under subclause (1):
  - (vi) the Authority's reasons for its determination:
  - (vii) in relation to a determination that a pricing error has occurred,—
    - (A) the trading periods affected by the pricing error; and
    - (B) the dispatch prices and dispatch reserve prices to be used to calculate the revised interim price or revised interim reserve price relating to the pricing error.

Clause 13.173C: inserted, on 1 November 2022, by clause 119 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.174 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26H section V part G

Clause 13.174: revoked, on 1 November 2022, by clause 120 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.175 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26I section V part G

Clause 13.175(b): amended, on 5 October 2017, by clause 422 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.175: revoked, on 1 November 2022, by clause 121 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.176 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26J section V part G

Clause 13.176 Heading: amended, on 5 October 2017, by clause 423(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.176: amended, on 5 October 2017, by clause 423(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.176: revoked, on 1 November 2022, by clause 122 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.177 Clearing manager to implement Authority’s determination

Where the Authority advises the clearing manager of its determination that a pricing error has occurred, the clearing manager must, as soon as practicable after receiving the determination,—
- (a) re-calculate the interim price or interim reserve price affected by the pricing error using—
  - (i) the methodology described in clause 13.134A; and
  - (ii) the dispatch prices and dispatch reserve prices specified in the notice given on WITS under clause 13.73C(2); and
- (b) make the revised interim price or revised interim reserve price available on WITS.

Compare: Electricity Governance Rules 2003 rule 3.26K section V part G

Clause 13.177(1)(a), (c) and (2): amended, on 5 October 2017, by clause 424(a), (c) and (d) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.177(1)(b): replaced, on 5 October 2017, by clause 424(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.177: replaced, on 1 November 2022, by clause 123 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.178 Further pricing error may be claimed or investigated in respect of revised interim prices

A person may submit a pricing error claim to the clearing manager under clause 13.170, or the clearing manager may decide to investigate a potential pricing error under clause 13.170A, in respect of a revised interim price or revised interim reserve price made available on WITS under clause 13.177.

Compare: Electricity Governance Rules 2003 rule 3.26L section V part G

Clause 13.178 Heading: replaced, on 5 October 2017, by clause 425(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.178: amended, on 5 October 2017, by clause 425(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.178: replaced, on 1 November 2022, by clause 124 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.178A

Pricing error claim in respect of trading periods prior to 1 November 2022

The pricing error claim process (including related definitions) that existed in the Code as at 31 October 2022 continues to apply to trading periods prior to 1 November 2022, except that the pricing manager’s duties under that process are transferred to the clearing manager.

Clause 13.178A: inserted, on 1 November 2022, by clause 125 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.179 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26M section V part G

Clause 13.179: amended, on 21 September 2012, by clause 25 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.179: amended, on 5 October 2017, by clause 426 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.179: revoked, on 1 November 2022, by clause 126 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.180 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26N section V part G

Clause 13.180(1): amended, on 5 October 2017, by clause 427 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.180: revoked, on 1 November 2022, by clause 127 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.181 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26O section V part G

Clause 13.181(1): amended, on 5 October 2017, by clause 428 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.181: revoked, on 1 November 2022, by clause 128 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.182 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.26P section V part G

Clause 13.182 Heading: amended, on 5 October 2017, by clause 429(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.182(2): amended, on 5 October 2017, by clause 429(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.182: revoked, on 1 November 2022, by clause 129 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Final prices

Cross heading: replaced, on 5 October 2017, by clause 430 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Cross heading: replaced, on 1 November 2022, by clause 130 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.182A

Interim prices become final prices if no pricing error claimed or investigated

(1) This clause applies if, by 1300 hours on the 1st business day following the trading day on which the clearing manager made an interim price or interim reserve price available on WITS, the clearing manager has not given a written notice under clause 13.173(2) or clause 13.173A(1) that a pricing error has been claimed or a potential pricing error is being investigated in respect of that interim price or interim reserve price.
(2) If this clause applies, the relevant interim price or interim reserve price becomes a final price or final reserve price (as applicable) when the clearing manager makes the final price or final reserve price available on WITS, which must be after 1300 hours but no later than 1400 hours on the 1st business day following the trading day on which the clearing manager made the interim price or interim reserve price available on WITS.

Clause 13.182A: inserted, on 1 November 2022, by clause 131 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.182A(2): amended, on 1 March 2024, by clause 76 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.182B

Interim prices become final prices if no pricing error exists

(1) This clause applies if the clearing manager has given a written notice under clause 13.173(2) or clause 13.173A(1) that a pricing error has been claimed or a potential pricing error is being investigated.
(2) If this clause applies, the relevant interim price or interim reserve price becomes a final price or final reserve price (as applicable) when the clearing manager makes the final price or final reserve price available on WITS, which must be as soon as practicable after the Authority has made available on WITS a notice under clause 13.173C(2) advising that no pricing error has occurred.

Clause 13.182B: inserted, on 1 November 2022, by clause 131 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.182B(2): amended, on 1 March 2024, by clause 77 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.183 Final prices not to change

Unless the Authority directs otherwise under clause 5.2, final prices and final reserve prices cannot be changed, despite the fact that a final price or final reserve price may contain an error.

Compare: Electricity Governance Rules 2003 rule 3.27 section V part G

Clause 13.183 Heading: replaced, on 5 October 2017, by clause 431(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.183: amended, on 5 October 2017, by clause 431(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.183: replaced, on 1 November 2022, by clause 132 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.184 Authority may order delay of interim prices becoming final prices

(1) Despite clauses 13.134A to 13.191, the Authority may make available on WITS a notice preventing an interim price or interim reserve price from becoming a final price or final reserve price (as applicable) until such time as the Authority specifies in the notice.
(2) If the Authority makes a notice available on WITS under subclause (1), the clearing manager must not make available on WITS the relevant final price or final reserve price until the time specified in the notice.

Compare: Electricity Governance Rules 2003 rule 3.28 section V part G

Clause 13.184: replaced, on 5 October 2017, by clause 432 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.184: replaced, on 1 November 2022, by clause 133 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.185 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.29 section V part G

Clause 13.185: substituted, on 21 September 2012, by clause 26 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.185: amended, on 5 October 2017, by clause 433 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.185: revoked, on 1 November 2022, by clause 134 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Miscellaneous requirements relating to calculation of prices

13.186 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.30 section V part G

Clause 13.186: revoked, on 1 November 2022, by clause 135 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.187 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.31 section V part G

Clause 13.187: revoked, on 1 November 2022, by clause 136 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.188 [Revoked]

Compare: Electricity Governance Rules 2003 rule 3.32 section V part G

Clause 13.188 Heading: amended, on 5 October 2017, by clause 434(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.188(1) and (3): amended, on 5 October 2017, by clause 434(2) and (3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.188: revoked, on 1 November 2022, by clause 137 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.189 System operator to give Authority list of model variable values

(1) If the value of the model parameters listed in Schedule 13.2 are to be changed, the system operator must immediately give the Authority an updated list of values in writing.
(2) The Authority must acknowledge receipt of the updated list in writing.
(3) Changes specified in any updated list must become effective from a date specified by the system operator, subject to agreement in writing from the Authority.

Compare: Electricity Governance Rules 2003 rule 3.33 section V part G

Clause 13.189 Heading: amended, on 3 November 2016, by clause 5(1) of the Electricity Industry Participation Code Amendment (Dispatchable Demand During Tight Market Conditions) 2016.

Clause 13.189(1): revoked, on 3 November 2016, by clause 5(2) of the Electricity Industry Participation Code Amendment (Dispatchable Demand During Tight Market Conditions) 2016.

Clause 13.189(2): amended, on 3 November 2016, by clauses 5(3) and 5(4) of the Electricity Industry Participation Code Amendment (Dispatchable Demand During Tight Market Conditions) 2016.

Clause 13.189(2A): inserted, on 3 November 2016, by clause 5(5) of the Electricity Industry Participation Code Amendment (Dispatchable Demand During Tight Market Conditions) 2016.

Clause 13.189(3): amended, on 3 November 2016, by clause 5(6) of the Electricity Industry Participation Code Amendment (Dispatchable Demand During Tight Market Conditions) 2016.

Clause 13.189(4): amended, on 3 November 2016, by clause 5(7)(a) and (b) of the Electricity Industry Participation Code Amendment (Dispatchable Demand During Tight Market Conditions) 2016.

Clause 13.189: replaced, on 1 November 2022, by clause 138 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.189A

[Revoked]

Clause 13.189A: inserted, on 15 May 2014, by clause 56 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.189A: revoked, on 1 November 2022, by clause 139 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.190 All information and notices to be unconditional and final

(1) [Revoked]
(2) Except as provided for in this Code, participants may treat all information and notices given under clauses 13.135 to 13.191 as final.

Compare: Electricity Governance Rules 2003 rule 3.34 section V part G

Clause 13.190 Heading: replaced, on 5 October 2017, by clause 435(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.190(1): revoked, on 5 October 2017, by clause 435(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.190(2): amended, on 5 October 2017, by clause 435(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.191 Backup procedures if WITS or approved system is unavailable

(1) If WITS or the approved system is unavailable for the purposes of giving information or making information available under clauses 13.134A to 13.191, each grid owner and the WITS manager must follow the backup procedures specified by the WITS manager.
(2) The backup procedures referred to in subclause (1) must be specified by the WITS manager following consultation with the Authority, generators, purchasers, ancillary service agents, the grid owners and the clearing manager.

Compare: Electricity Governance Rules 2003 rules 3.35 and 3.36 section V part G

Clause 13.191 Heading: amended, on 5 October 2017, by clause 436(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.191(1): replaced, on 5 October 2017, by clause 436(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.191(2): amended, on 5 October 2017, by clause 436(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.191(3): revoked, on 5 October 2017, by clause 436(2)(c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.191: replaced, on 1 November 2022, by clause 140 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Calculation of constrained off amounts

13.192 Constrained off situations may occur

(1) A constrained off situation occurs when—
- (a) a generator (other than a dispatch notification generator) is not given a dispatch instruction, or is not dispatched by the system operator to the level expected based on the generator’s offer compared to the relevant final price, for a trading period despite the generator having offered electricity at a price below the final price for that trading period at the relevant grid injection point; or
- (b) in relation to a block dispatch group or station dispatch group, a generator (other than a dispatch notification generator) is not given a dispatch instruction, or is not dispatched by the system operator to the level expected based on the generator’s offer compared to the final price, for the trading period, despite the generator having offered electricity in the trading period at a grid injection point within the block dispatch group or station dispatch group below the final price at the relevant grid injection point in that trading period, and the aggregate quantity of those offers is greater than the dispatched quantity calculated in accordance with clause 13.194; or
- (c) load to which a nominated dispatch bid (other than a dispatch notification purchaser bid) applies is not dispatched, and where the price in the nominated dispatch bid is above the final price at the relevant GXP.
(2) In this clause,—
- (a) an offer made by a generator means the last offer made by the generator which applied during the relevant trading period; and
- (b) a bid made by a purchaser means the last bid made by the purchaser which applied during the relevant trading period.

Compare: Electricity Governance Rules 2003 rule 4.1 section V part G

Clause 13.192(c): inserted, on 15 May 2014, by clause 57 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.192(c): amended, on 1 December 2015, by clause 7 of the Electricity Industry Participation Code Amendment (Dispatchable Demand: Late Bid Revisions) 2015.

Clause 13.192: replaced, on 1 November 2022, by clause 141 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.192(1)(c): amended, on 1 March 2024, by clause 78 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.192A

No constrained off situation for intermittent generating stations

Despite clause 13.192, no constrained off situation arises in relation to an intermittent generating station.

Clause 13.192A: inserted, at 12.00 pm on 19 September 2019, by clause 28 of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

13.193 Determining affected price bands for block dispatch groups and station dispatch groups

(1) If a constrained off situation occurs for a block dispatch group or station dispatch group during any trading period during a billing period, the clearing manager must determine the affected price bands for that block dispatch group or station dispatch group by—
- (a) taking all the offers made by that block dispatch group or station dispatch group in relation to that trading period, calculating the differences between each offer price and final price for each grid injection point, and ranking the differences in ascending order; and
- (b) identifying each price band ranked under paragraph (a) in which the aggregate quantity in all previous price bands plus the quantity for that price band is greater than 0 or the dispatched quantity calculated in accordance with clause 13.194, but is less than the aggregate quantity for all the generating plant in that block dispatch group or station dispatch group calculated by the clearing manager using the methodology set out in Schedule 13.3. The offer prices corresponding to the ranked price bands identified under this paragraph are the affected price bands for the block dispatch group or station dispatch group for the purposes of clauses 13.194 to 13.196.
(2) In this clause, an offer made by a generator means the last offer made by the generator which applied during the relevant trading period.

Compare: Electricity Governance Rules 2003 rule 4.2 section V part G

Clause 13.193(b): amended, on 1 November 2022, by clause 142(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.193(2): inserted, on 1 November 2022, by clause 142(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.194 Clearing manager to calculate constrained off amounts

(1) Despite clause 13.193, if a constrained off situation occurs in relation to a generator during a trading period, the clearing manager must calculate the constrained off amounts for each generator, for each affected price band, using the following formula:

COF_g = Q_cof * (P_f − P_o)

where

COF_g

is the constrained off amount for a generator

Q_cof

is the dispatched quantity in MWh (calculated under subclause (3)) from that price band in the offer that was constrained off during a trading period, or the positive difference between the reconciliation information and the scheduled quantity, whichever is less

P_o

is the price offered for that price band by that generator for the quantity of electricity from the generating plant that was constrained off

P_f

is the final price for that trading period at the grid injection point.

(2) If a constrained off situation occurs in relation to a dispatch-capable load station during a trading period, the clearing manager must calculate the constrained off amounts for each dispatch-capable load station, for each affected nominated dispatch bid price band, using the following formula:

ConOffAmt_disp = ConOffQ * ( P_b - P_f)

where

ConOffAmt_disp

is the constrained off amount for a dispatch-capable load station for the nominated dispatch bid price band

ConOffQ

is the amount in MWh by which Q_b exceeds the highest of Q_disp and Q_rec

where

Q_b

is the quantity, in MWh, in the nominated dispatch bid band where the bid price is above the final price

Q_disp

is the dispatched quantity, in MWh in the trading period, calculated under subclause (3), dispatched for the nominated dispatch bid price band in the trading period

Q_rec

is the reconciled quantity provided by the reconciliation manager under clause 15.20C allocated by the clearing manager to the nominated dispatch bid price band in the trading period

P_b

is the price bid for the nominated dispatch bid price band for the dispatch-capable load station that was constrained off

P_f

is the final price for the trading period at the grid exit point.

(3) For the purposes of clauses 13.192 to 13.201, dispatched quantity must be calculated taking into account—
- (a) the quantity in MW recorded in the log kept by the system operator in accordance with clause 13.76 and, if required, the clearing manager must aggregate such quantities for—
  - (i) generating stations or generating units in the relevant station dispatch group; or
  - (ii) generating units, if the clearing manager requires the dispatched quantity to be determined on a grid injection point basis; and
- (b) for an offer, the ramp rate applying to that constrained off situation that is specified in the offer submitted by that generator, or—
  - (i) for a block dispatch group or a station dispatch group; or
  - (ii) for generating units, if the clearing manager requires the dispatched quantity to be determined on a grid injection point basis—
- the fastest of the ramp rates applying to that constrained off situation that are specified in the offers submitted by the generator in that block dispatch group, that station dispatch group or those generating units electrically connected to the relevant grid injection point (as the case may be); and
- (c) plus or minus the MW bandwidth applicable for each generator affected by a frequency keeping requirement as advised by the system operator to the clearing manager, and, if required, the clearing manager must aggregate the MW bandwidth applicable to determine the MW bandwidth on a grid injection point basis.
(4) In this clause,—
- (a) an offer made by a generator means the last offer made by the generator which applied during the relevant trading period; and
- (b) a bid made by a purchaser means the last bid made by the purchaser which applied during the relevant trading period.

Compare: Electricity Governance Rules 2003 rule 4.3.1 section V part G

Clause 13.194(1): amended, on 15 May 2014, by clause 58(1) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.194(1): amended, on 1 April 2025, by clause 24 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2025.

Clause 13.194(1A): inserted, on 15 May 2014, by clause 58(2) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.194(2)(b): amended, on 5 October 2017, by clause 437 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.194(2)(b): amended, on 1 November 2018, by clause 90 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.194(2)(b) & (c): amended, on 15 May 2014, by clause 58(3) & (4) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.194(2)(b)(ii): amended, on 21 September 2012, by clause 27 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.194(2)(b): amended, on 23 February 2015, by clause 75 of the Electricity Industry Participation Code Amendment (Distributed Generation) 2014.

Clause 13.194(2)(c): amended, on 15 May 2014, by clause 49 of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 13.194: replaced, on 1 November 2022, by clause 143 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.194(2): amended, on 1 March 2024, by clause 79 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.195 Constrained off amount for block dispatch groups and station dispatch groups

The constrained off amounts for a block dispatch group or station dispatch group must equal the sum of the amounts calculated in accordance with clause 13.194 for the generating plant in block dispatch group or station dispatch group.

Compare: Electricity Governance Rules 2003 rule 4.3.2 section V part G

13.196 Calculation of constrained off amounts attributable to system operator

If a constrained off situation occurs during any trading period in the previous billing period, and the clearing manager receives notice of the constrained off situation under clause 13.76, the clearing manager must determine the portion of the constrained off amounts calculated under clause 13.194 that is attributable to the system operator for each generator as follows:
- (a) if the system operator has advised the clearing manager that a voltage support or other constrained off situation occurred (including, but not limited to, over frequency reserve and instantaneous reserve) the system operator must be allocated the total constrained off amount:
- (b) if the system operator has advised the clearing manager that a non-security constrained off situation occurred, the system operator must be allocated a constrained off amount calculated in accordance with the following formula:

SOCOFNS_so = TCOFP * (SOQcoffns / TQcoff)

where

SOCOFNS_so

is the constrained off amount attributable to the system operator for that non-security constrained off situation

TCOFP

is the total constrained off payment for that trading period

SOQcoffns

is the non-security quantity that was constrained off and advised to the clearing manager by the system operator under clause 13.76 or the total quantity constrained off, whichever is less

TQcoff

is the total quantity constrained off:

(c) if the system operator has advised the clearing manager that a frequency keeping situation occurred in a trading period the system operator must be allocated a constrained off amount calculated in accordance with the following formula:

SOCOFFK_so = TCOFP * (SOQcofffk / TQcoff)

where

SOCOFFK_so

is the constrained off amount attributable to the system operator for that frequency keeping constrained off situation

TCOFP

is the total constrained off payment for the generator for the trading period

SOQcofffk

is the frequency keeping quantity advised to the clearing manager by the system operator under clause 13.76 or the total quantity constrained off for the generator, whichever is less

TQcoff

is the total quantity constrained off for the generator.

Compare: Electricity Governance Rules 2003 rule 4.3.3 section V part G

Clause 13.196 Heading: amended, on 5 October 2017, by clause 438(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.196: amended, on 5 October 2017, by clause 438(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.196(c): amended, on 15 May 2014, by clause 59 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.196(c): amended, on 20 December 2021, by clause 59 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

Clause 13.196: amended, on 1 November 2022, by clause 144 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.197 Timeframe for calculating constrained off amounts

Each billing period, the clearing manager must calculate constrained off amounts for the previous billing period in accordance with clauses 13.194 to 13.196 by the later of—
- (a) 1600 hours on the 8^th business day of the billing period after the previous billing period; and
- (b) 1600 hours on the 1^st business day after the clearing manager receives the information required to calculate constrained off amounts.

Compare: Electricity Governance Rules 2003 rule 4.4 section V part G

Clause 13.197: amended, on 21 September 2012, by clause 28 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.197: replaced, on 1 November 2018, by clause 91 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

13.198 Clearing manager to send constrained off information to system operator

(1) The clearing manager must, at the time specified in clause 13.197, send to the system operator the details of constrained off amounts that are attributable to the system operator (but limited to information about those constrained off amounts that is in the possession of the clearing manager) and the constrained off quantities (in MW) calculated in accordance with clause 13.196 for the previous billing period.
(2) The information must be provided to the system operator in the manner and format agreed between the clearing manager and the system operator from time to time.

Compare: Electricity Governance Rules 2003 rule 4.5 section V part G

Clause 13.198(1): amended, on 15 May 2014, by clause 60 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

13.199 Clearing manager to make details of constrained off amounts available

The clearing manager must, at the time specified in clause 13.197, publish the details of constrained off amounts for each generator and each dispatched purchaser for the previous billing period as follows:
- (a) the constrained off amounts calculated in accordance with clauses 13.194 to 13.196:
- (b) the generator or dispatched purchaser (as the case may be) that was constrained off:
- (c) the applicable grid injection point, or grid exit point, or block dispatch group, or station dispatch group.

Compare: Electricity Governance Rules 2003 rule 4.6 section V part G

Clause 13.199 Heading: amended, on 5 October 2017, by clause 439(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.199: amended, on 15 May 2014, by clause 61 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.199: amended, on 5 October 2017, by clause 439(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.199: amended, on 1 March 2024, by clause 80 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.200 Authority, generators and purchasers have rights to constrained off information

(1) In addition to the information the clearing manager makes available under clause 13.199, a generator or purchaser who reasonably believes it was adversely affected by a constrained off situation occurring, or the Authority, may request information from the system operator about the cause of the constrained off situation.
(2) The system operator must comply with any reasonable request made for such information provided that the information does not include any information that is confidential in respect of any other generator or purchaser.

Compare: Electricity Governance Rules 2003 rule 4.7 section V part G

Clause 13.200(1): amended, on 5 October 2017, by clause 440 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.201 Generators do not get paid constrained off compensation

(1) A generator is not entitled to be paid compensation in respect of any constrained off situation except as provided for in an ancillary service arrangement entered into by the system operator and the generator.
(2) This clause does not affect the rights that a participant has under this Code against the system operator for a failure by the system operator to comply with this Code.

Compare: Electricity Governance Rules 2003 rule 4.8 section V part G

13.201A

Dispatched purchasers entitled to constrained off compensation and purchasers to pay constrained off compensation

(1) A dispatched purchaser in respect of whose dispatch-capable load station there was a constrained off situation as described in clause 13.192(1)(c) is owed constrained off compensation for the constrained off amounts calculated under clause 13.194(2).
(2) A purchaser that purchases electricity at a grid exit point incurs an amount owing to the clearing manager for constrained off compensation, calculated under subclause (6).
(2A) The clearing manager must advise each purchaser of the amount owing by the purchaser for constrained off compensation for a billing period when the clearing manager advises amounts owing under subpart 4 of Part 14.
(3) The clearing manager owes constrained off compensation received under subclause (2), for each dispatch-capable load station, to the dispatched purchaser that purchased electricity for the dispatch-capable load station.
(4) The clearing manager must advise each dispatched purchaser of the amount owing to the dispatched purchaser for constrained off compensation for a billing period when the clearing manager advises amounts owing under subpart 4 of Part 14.
(5) [Revoked]
(6) The clearing manager must calculate constrained off compensation owing by a purchaser under subclause (2) for each trading period using the following formula:

ConOffC_p = ConOffC_DLPs * (Pur_i / TotPur)

where

ConOffC_p

is the constrained off compensation owing by a purchaser

ConOffC_DLPs

is the sum of constrained off compensation owing to all dispatched purchasers for the trading period

Pur_i

is the total quantity in MWh of all purchases by the purchaser from the clearing manager during the trading period, as shown by reconciliation information calculated by the reconciliation manager under Part 15

TotPur

is the quantity in MWh of all purchases by all purchasers from the clearing manager during the trading period, as shown by reconciliation information calculated by the reconciliation manager under Part 15.

Clause 13.201A: inserted, on 15 May 2014, by clause 62 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.201A(1): amended, on 24 March 2015, by clause 12(a) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.201A(2): amended, on 24 March 2015, by clause 12(b) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.201A(2A): inserted, on 24 March 2015, by clause 12(c) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.201A(3): substituted, on 24 March 2015, by clause 12(d) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.201A(4): substituted, on 24 March 2015, by clause 12(e) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.201A(5): revoked, on 24 March 2015, by clause 12(f) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.201A(6): amended, on 24 March 2015, by clause 12(g) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.201A: amended, on 1 November 2022, by clause 145 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Calculation of constrained on amounts

13.202 Constrained on situations may occur

(1) A constrained on situation occurs when—
- (a) a generator is given a dispatch instruction by the system operator and the price offered by the generator for that dispatched quantity of electricity at the relevant grid injection point and trading period is higher than the final price at that grid injection point in the relevant trading period; or
- (b) in relation to a block dispatch group or station dispatch group, a generator is given a dispatch instruction by the system operator and the price offered by the generator for that aggregate dispatched quantity of electricity from that block dispatch group or station dispatch group in the relevant trading period is higher than the final price in the relevant trading period; or
- (c) an ancillary service agent is given a dispatch instruction by the system operator and the price offered by the ancillary service agent for the dispatched instantaneous reserve in the relevant trading period is higher than the final reserve price of the dispatched instantaneous reserve in the relevant trading period; or
- (d) load to which a nominated dispatch bid (other than a dispatch notification purchaser bid) applies is dispatched, and the price in the nominated dispatch bid is below the final price at the relevant GXP.
(2) In this clause,—
- (a) an offer made by a generator means the last offer made by the generator which applied during the relevant trading period; and
- (b) a bid made by a purchaser means the last bid made by the purchaser which applied during the relevant trading period.

Compare: Electricity Governance Rules 2003 rule 5.1 section V part G

Clause 13.202(1): amended, on 1 June 2013, by clause 16(a) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.202(1)(c): amended, on 1 November 2018, by clause 92 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.202(1)(d): inserted, on 15 May 2014, by clause 63 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.202(1)(d): amended, on 1 December 2015, by clause 8 of the Electricity Industry Participation Code Amendment (Dispatchable Demand: Late Bid Revisions) 2015.

Clause 13.202(2): inserted, on 1 June 2013, by clause 16(b) of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Clause 13.202: replaced, on 1 November 2022, by clause 146 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.202(1)(d): amended, on 1 March 2024, by clause 81 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.203 Determining affected price bands for block dispatch groups or station dispatch groups

(1) If a constrained on situation occurred for a block dispatch group or station dispatch group during any trading period during the previous billing period, the clearing manager must determine the affected price bands for that block dispatch group or station dispatch group by—
- (a) taking all the offers made by that block dispatch group or station dispatch group in relation to that trading period, calculating the differences between each offer price and final price for each grid injection point and ranking the differences in ascending order; and
- (b) identifying each price band ranked under paragraph (a) in which the aggregate quantity for that price band plus all the quantity in all previous price bands exceeds the aggregate quantity for all the generating plant in that block dispatch group or station dispatch group calculated by the clearing manager using the methodology set out in Schedule 13.3. The offer prices corresponding to the ranked price bands identified under this paragraph are the affected price bands for that block dispatch group or station dispatch group for the purposes of clause 13.204.
(2) In this clause, an offer made by a generator means the last offer made by the generator which applied during the relevant trading period

Compare: Electricity Governance Rules 2003 rule 5.2 section V part G

Clause 13.203(b): amended, on 1 November 2022, by clause 147(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.203(2): inserted, on 1 November 2022, by clause 147(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.204 Calculation of constrained on amounts

(1) If a constrained on situation occurs during any trading period during a previous billing period,—
- (a) the clearing manager must calculate the constrained on amounts for a constrained on situation described in clause 13.202(1)(a) or (b) for each generator for each affected price band in accordance with the following formula:

COC = Q_con * (P_o-P_f)

where

COC

is the constrained on amount for a generator

Q_con

is the dispatched quantity in MWh (calculated under paragraph (b)) from that price band in the offer that was constrained on during a trading period, or the positive difference between the reconciliation information and the scheduled quantity, whichever is less

P_o

is the price offered for that price band by the generator for the quantity of electricity from the generating plant which was constrained on

P_f

is the final price for that trading period at the grid injection point; and

(aa) the clearing manager must calculate the constrained on amounts for a constrained on situation described in clause 13.202(1)(d) for each dispatch-capable load station for each affected nominated dispatch bid price band, using the following formula:

ConOnAmt = ConOnQ* (P_f-P_b)

where

ConOnAmt

is the constrained on amount for a dispatch-capable load station for the nominated dispatch bid price band

ConOnQ

is the amount in MWh by which the lowest of Q_disp and Q_rec _exceeds Q_b

Q_b

is the quantity, in MWh, in the nominated dispatch bid price band where the bid price is below the final price.

Q_disp

is the dispatched quantity in MWh in the trading period, calculated under paragraph (b), for the nominated dispatch bid price band in the trading period

Q_rec

is the reconciled quantity provided by the reconciliation manager under clause 15.20C allocated by the clearing manager to the nominated dispatch bid price band in the trading period

P_f

is the final price for the trading period at the grid exit point

P_b

is the price bid for the nominated dispatch bid price band for the dispatch-capable load station that was constrained on; and

- (b) for the purposes of clauses 13.202 to 13.211 dispatched quantity must be calculated taking into account—
  - (i) the quantity in MW recorded in the log kept by the system operator in accordance with clause 13.76; and if required, the clearing manager must aggregate such quantities for—
    - (A) generating stations or generating units in the relevant station dispatch group; or
    - (B) generating units, if the clearing manager requires a dispatched quantity to be determined on a grid injection point basis; and
  - (ii) for an offer, the ramp rate applying to that constrained on situation that is specified in the offer submitted by the generator, or—
    - (A) for a block dispatch group or a station dispatch group; or
    - (B) for generating units, if the clearing manager requires the dispatched quantity to be determined on a grid injection point basis—
  - the fastest of the ramp rates applying to that constrained on situation that are specified in the offers submitted by the generator in that block dispatch group, that station dispatch group or those generating units electrically connected to the relevant grid injection point (as the case may be); and
  - (iii) plus or minus the MW bandwidth applicable for each generator affected by a frequency keeping requirement as advised by the system operator to the clearing manager under clause 13.76 and, if required, the clearing manager must aggregate the MW bandwidth applicable to determine the MW bandwidth on a grid injection point basis; and
- (c) the clearing manager must calculate the constrained on amounts for a constrained on situation described in clause 13.202(1)(c) for each ancillary service agent for each affected price band in accordance with the following formula:

COC = Q_con * (P_o-P_f)

where

COC

is the constrained on amount for an ancillary service agent

Q_con

is the dispatched quantity of instantaneous reserve in MW (calculated under paragraph (d)) from that price band in the reserve offer that was constrained on during a trading period

P_o

is the price offered for that price band by that ancillary service agent for the quantity Q_con

P_f

is the final reserve price for that trading period at the point of connection on the grid; and

- (d) for the purposes of paragraph (c), in determining the dispatched quantity, the clearing manager must take into account the quantity in MW of instantaneous reserve dispatched for the ancillary service agent recorded in the log kept by the system operator in accordance with clause 13.76; and
- (e) the constrained on amounts for a block dispatch group or station dispatch group equal the sum of the amounts calculated in accordance with paragraphs (a) and (b) for the generating plant in that block dispatch group or station dispatch group (as the case may be); and
- (f) in relation to any 2 adjacent trading periods, a generator is entitled to be paid for the 2^nd trading period at the final price for the grid injection point if the generator—
  - (i) was in a constrained on situation in the 1^st trading period; and
  - (ii) continues to generate in the 2^nd trading period as a result of a dispatch instruction given for the 1^st trading period; but
  - (iii) has not made an offer in the 2^nd trading period.
(2) To avoid doubt, nothing in this clause entitles the system operator to issue any instruction to a generator in relation to unoffered generation.
(3) In this clause,—
- (a) an offer made by a generator means the last offer made by the generator which applied during the relevant trading period; and
- (b) a bid made by a purchaser means the last bid made by the purchaser which applied during the relevant trading period.

Compare: Electricity Governance Rules 2003 rule 5.3 section V part G

Clause 13.204(1)(a): amended, on 5 October 2017, by clause 441 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.204(1)(a): amended, on 1 November 2022, by clause 148(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.204(1)(aa): inserted, on 15 May 2014, by clause 64(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.204(1)(aa): amended, on 1 November 2022, by clause 148(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.204(1)(b): amended, on 1 November 2022, by clause 148(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.204(1)(b)(ii): amended, on 15 May 2014, by clause 64(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.204(1)(b)(ii): amended, on 23 February 2015, by clause 75 of the Electricity Industry Participation Code Amendment (Distributed Generation) 2014.

Clause 13.204(1)(b)(ii): amended, on 5 October 2017, by clause 441 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.204(1)(c): amended, on 21 September 2012, by clause 29 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 13.204(1)(c): amended, on 1 November 2022, by clause 148(4) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.204(1)(d): amended, on 1 November 2022, by clause 148(5) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.204(3): inserted, on 1 November 2022, by clause 148(6) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.204(1)(aa): amended, on 1 March 2024, by clause 82 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.205 Calculation of constrained on amounts attributable to system operator

If a constrained on situation occurs during a trading period in a previous billing period, and the clearing manager receives notice of the constrained on situation under clause 13.76, the clearing manager must determine the portion of the constrained on amounts calculated under clause 13.204 attributable to the system operator for each generator or each ancillary service agent as follows:
- (a) if the system operator has advised the clearing manager that a voltage support or other constrained on situation occurred (including but not limited to over frequency reserve and instantaneous reserve) the system operator must be allocated the total constrained on amount for that trading period:
- (b) if the system operator has advised the clearing manager that a non-security constrained on situation occurred the system operator must be allocated a constrained on amount calculated in accordance with the following formula:

SOCONNS_go = TCONP * (SOQconns / TQcon)

where

SOCONNS_go

is the constrained on amount attributable to the system operator for that non-security constrained on situation

TCONP

is the total constrained on payment for that trading period

SOQconns

is the non-security quantity that was constrained on and advised to the clearing manager by the system operator under clause 13.76, or the total quantity constrained on, whichever is less

TQcon

is the total quantity constrained on:

(c) if the system operator has advised the clearing manager that a frequency keeping situation occurred the system operator must be allocated a constrained on amount calculated in accordance with the following formula:

SOCONFK_go = TCONP * (SOQconfk / TQcon)

where

SOCONFK_go

is the constrained on amount attributable to the system operator for that frequency keeping constrained on situation

TCONP

is the total constrained on payment for the generator for the trading period

SOQconfk

is the frequency keeping quantity that was advised to the clearing manager by the system operator under clause 13.76 , or the total quantity constrained on for the generator, whichever is less

TQcon

is the total quantity constrained on for the generator.

Compare: Electricity Governance Rules 2003 rule 5.4 section V part G

Clause 13.205: amended, on 15 May 2014, by clause 65 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.205: amended, on 5 October 2017, by clause 442 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.205: amended, on 1 November 2022, by clause 149(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13.205(c): amended, on 1 November 2022, by clause 149(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.206 Timeframe for calculating constrained on amounts

Each billing period, the clearing manager must calculate constrained on amounts for the previous billing period in accordance with clauses 13.204 and 13.205 by the later of—
- (a) 1600 hours on the 8^th business day of the billing period after the previous billing period; and
- (b) 1600 hours on the 1^st business day after the clearing manager receives the information required to calculate constrained on amounts.

Compare: Electricity Governance Rules 2003 rule 5.5 section V part G

Clause 13.206 Heading: amended, on 5 October 2017, by clause 443(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.206: substituted, on 15 May 2014, by clause 4 of the Electricity Industry Participation (Time Frames for Invoicing) Code Amendment 2014.

Clause 13.206(b): replaced, on 5 October 2017, by clause 443(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.206: replaced, on 1 November 2018, by clause 93 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

13.207 Clearing manager to send constrained on information to system operator

(1) The clearing manager must, at the time specified in clause 13.206, send to the system operator the details of constrained on amounts that are attributed to the system operator (but limited to information about those constrained on amounts that is in the possession of the clearing manager) and the constrained on quantities (in MW) calculated in accordance with clause 13.205 for the previous billing period.
(2) The information must be provided to the system operator in the manner and format agreed between the clearing manager and the system operator from time to time.

Compare: Electricity Governance Rules 2003 rule 5.6 section V part G

13.208 Clearing manager to make details of constrained on amounts available

The clearing manager must, at the time specified in clause 13.206, publish the details of constrained on amounts in relation to each generator, ancillary service agent, and dispatched purchaser for the previous billing period calculated in accordance with clauses 13.204 and 13.205 as follows:
- (a) the aggregate constrained on amounts calculated under clauses 13.204 and 13.205:
- (b) the generator, ancillary service agent, or dispatched purchaser (as the case may be) that was constrained on:
- (c) the applicable grid injection point, grid exit point, block dispatch group, or station dispatch group.

Compare: Electricity Governance Rules 2003 rule 5.7 section V part G

Clause 13.208 Heading: amended, on 5 October 2017, by clause 444(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.208: amended, on 15 May 2014, by clause 66 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.208: amended, on 5 October 2017, by clause 444(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.208: amended, on 1 March 2024, by clause 83 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.209 Authority, generators, ancillary service agents, and purchasers have rights to constrained on information

(1) In addition to the information the clearing manager makes available under clause 13.208, the Authority, or a generator, ancillary service agent, or purchaser who reasonably believes it was adversely affected by a constrained on situation occurring, may request information from the system operator about the cause of the constrained on situation.
(2) The system operator must comply with any reasonable request for such information except that the information must not include any information that is confidential in respect of any other generator, ancillary service agent, or purchaser.

Compare: Electricity Governance Rules 2003 rule 5.8 section V part G

Clause 13.209(1): amended, on 5 October 2017, by clause 445 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.210 [Revoked]

Compare: Electricity Governance Rules 2003 rule 5.9 section V part G

Clause 13.210: revoked, on 5 October 2017, by clause 446 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.211 Backup procedures if the clearing manager’s external system is unavailable

(1) If the clearing manager’s external system is unavailable for the purposes of making information available under clauses 13.199 and 13.208, the clearing manager must follow backup procedures agreed between it and the Authority and published by the Authority.
(2) [Revoked]

Compare: Electricity Governance Rules 2003 rules 5.10 and 5.11 section V part G

Clause 13.211: replaced, on 5 October 2017, by clause 447 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.211 Heading: amended, on 1 March 2024, by clause 84(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.211(1): amended, on 1 March 2024, by clause 84(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.211(2): revoked, on 1 March 2024, by clause 84(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.212 Payment of constrained on compensation

(1) For each trading period,—
- (a) a generator or ancillary service agent is owed constrained on compensation for constrained on amounts determined under clauses 13.204 and 13.205; and
- (b) a dispatched purchaser is owed constrained on compensation for constrained on amounts determined under clause 13.204.
(1A) Constrained on compensation for each dispatch-capable load station is an amount owing to the dispatched purchaser that purchased electricity for the dispatch-capable load station.
(2) The system operator must pay to a generator, or ancillary service agent any constrained on amount calculated under clause 13.205.
(3) The clearing manager must advise each generator, ancillary service agent, and dispatched purchaser of the amount owing to the generator, ancillary service agent, or dispatched purchaser for constrained on compensation for a billing period when the clearing manager advises amounts owing under subpart 4 of Part 14.
(4) [Revoked]
(5) Each purchaser that purchases electricity at a grid exit point incurs an amount owing to the clearing manager for constrained on compensation, calculated under subclause (7).
(5A) [Revoked]
(6) Instantaneous reserve constrained on compensation is an instantaneous reserve cost that must be allocated in accordance with clauses 8.59 to 8.66.
(7) The clearing manager must calculate constrained on compensation for each trading period using the following formula:

COC_p = (COC_g − COC_so) * (P_q / TP_q)

where

COC_p

is the constrained on compensation owing by a purchaser

COC_g

is the sum of constrained on compensation owing to all generators and all dispatched purchasers for the trading period calculated in accordance with clause 13.204(1)(a) and 13.204(1)(aa)

COC_so

is the sum of constrained on compensation for that trading period payable by the system operator to generators under subclause (2)

P_q

is the total electricity purchased by that purchaser from the clearing manager during the trading period as shown by the reconciliation information calculated by the reconciliation manager under Part 15

TP_q

is the total electricity purchased by all purchasers from the clearing manager during the trading period as shown by reconciliation information calculated by the reconciliation manager under Part 15.

(8) The clearing manager must advise each purchaser of the amount owing by the purchaser for constrained on compensation for a billing period when the clearing manager advises amounts owing under subpart 4 of Part 14.

Compare: Electricity Governance Rules 2003 rule 6 section V part G

Clause 13.212(1): substituted, on 15 May 2014, by clause 67(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.212(1): amended, on 24 March 2015, by clause 13(a) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.212(1A): inserted, on 15 May 2014, by clause 67(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.212(1A): amended, on 24 March 2015, by clause 13(b) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.212(3) & (4): amended, on 15 May 2014, by clause 67(b) & (c) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.212(3): substituted, on 24 March 2015, by clause 13(c) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.212(4): revoked, on 24 March 2015, by clause 13(d) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.212(5): substituted, on 15 May 2014, by clause 67(d) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.212(5): substituted, on 24 March 2015, by clause 13(e) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.212(5A): inserted, on 15 May 2014, by clause 67(d) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.212(5A): revoked, on 24 March 2015, by clause 13(f) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.212(7): amended, on 15 May 2014, by clause 67(e) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 13.212(7): amended, on 24 March 2015, by clause 13(g) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.212(8): substituted, on 24 March 2015, by clause 13(h) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

No payment of constrained on and off compensation for frequency keeping

Cross heading: inserted, on 1 May 2016, by clause 4 of the Electricity Industry Participation Code Amendment (Removal of In-band Frequency Keeping Compensation) 2015.

13.212A

No payment of constrained on and off compensation for frequency keeping

(1) Despite clause 13.192 to clause 13.212, the system operator must not pay a frequency keeping ancillary service agent—
- (a) constrained on compensation in respect of any constrained on situation; or
- (b) constrained off compensation in respect of any constrained off situation.
(2) Subclause (1) applies in respect of any reconciled quantity of electricity the frequency keeping ancillary service agent produces—
- (a) while providing frequency keeping; and
- (b) between—
  - (i) the level of active power (expressed in MW) dispatched in a trading period to the ancillary service agent’s generating plant; and
  - (ii) the level of active power (expressed in MW) generated by the ancillary service agent’s generating plant in a trading period, measured by a metering installation.

Clause 13.212A: inserted, on 1 May 2016, by clause 4 of the Electricity Industry Participation Code Amendment (Removal of In-band Frequency Keeping Compensation) 2015.

No payment of constrained on compensation for generators at maximum ramp down rate

Cross heading: inserted, on 26 March 2020, by clause 4 of the Electricity Industry Participation Code Amendment (Removal of Constrained on Compensation for Ramp Constrained Generators) 2020.

13.212B

No payment of constrained on compensation for generators at maximum ramp down rate

(1) Despite clause 13.202 to clause 13.212, the clearing manager must not pay a generator constrained on compensation in respect of any constrained on situation.
(2) Subclause (1) applies in respect of any reconciled quantity of electricity the generator's generating unit produces in a trading period, only if:
- (a) the generating unit is reducing generation as a result of the generator having received a dispatch instruction for the trading period or part of the trading period; and
- (b) the dispatch instruction requires the generating unit to reduce generation at the generating unit's maximum ramp down rate.

Clause 13.212B: inserted, on 26 March 2020, by clause 4 of the Electricity Industry Participation Code Amendment (Removal of Constrained on Compensation for Ramp Constrained Generators) 2020.

[Revoked]

Cross heading: revoked, on 1 November 2022, by clause 150 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.213 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.1 section V part G

Clause 13.213(1) and 2(a): amended, on 5 October 2017, by clause 448 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.213: revoked, on 1 November 2018, by clause 94 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

13.214 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.2 section V part G

Clause 13.214 Heading: amended, on 5 October 2017, by clause 449(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.214(1): amended, on 5 October 2017, by clause 449(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.214(2): revoked, on 5 October 2017, by clause 449(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.214: revoked, on 1 November 2018, by clause 95 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

13.215 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.3 section V part G

Clause 13.215(1): amended, on 5 October 2017, by clause 450 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.215(1): replaced, on 1 November 2018, by clause 96 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2018.

Clause 13.215(1): amended, on 20 December 2021, by clause 60 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

Clause 13.215: revoked, on 1 November 2022, by clause 151 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.216 [Revoked]

Compare: Electricity Governance Rules 2003 rule 7.4 section V part G

Clause 13.216: amended, on 5 October 2017, by clause 451 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.216: revoked, on 19 September 2019, by clause 4 of the Electricity Industry Participation Code Amendment (Revocation of Requirement to Provide Daily Situation Report) 2019.

Subpart 5—Hedge arrangement disclosure

13.217 Purpose of this subpart

This subpart provides for the disclosure of information about risk management contracts, in order to—
- (a) facilitate the ready comparison of electricity prices and other key terms of risk management contracts; and
- (b) enable persons to formulate their own historic contract curves for electricity; and
- (c) provide a more informed basis for the Authority to monitor and assess the market for risk management contracts in respect of electricity, for the purposes of its functions under section 16 of the Act.

Compare: Electricity Governance Rules 2003 rule 1 section VI part G

Clause 13.217 Heading: amended, on 30 October 2024, by clause 5(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.217: amended, on 30 October 2024, by clause 5(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.217(b): amended, on 30 October 2024, by clause 5(3) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.217(c): amended, on 30 October 2024, by clause 5(4) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.218 Parties required to submit information

(1) The following parties to risk management contracts are required to submit the information specified in clauses 13.219 and 13.223 using an approved system:
- (a) the seller, if the seller is a participant; or
- (b) the buyer, if the buyer is a participant and the seller is not a participant.
(2) [Revoked]

Compare: Electricity Governance Rules 2003 rule 2 section VI part G

Clause 13.218: amended, on 5 October 2017, by clause 452 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.218(a): amended, on 21 September 2012, by clause 30 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012

Clause 13.218(1): amended, on 30 October 2024, by clause 6(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.218(2): inserted, on 29 October 2020, by clause 5 of the Electricity Industry Participation Code Amendment (Securing Access to Exchange Data) 2020.

Clause 13.218(2): amended, on 1 March 2024, by clause 85 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Clause 13.218(2): revoked, on 30 October 2024, by clause 6(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.219 Information that must be submitted

(1) The party specified in clause 13.218 must submit the following information to the approved system in relation to every risk management contract, excluding exchange-traded risk management contracts where the parties have provided consent under clause 13.236AA:
- (a) each party’s legal name:
- (b) each party’s email address for notice:
- (c) the trade date:
- (d) the effective date:
- (e) the end date:
- (f) the quantity:
- (g) whether the contract is a contract for differences, a fixed-price physical supply contract, an options contract or, if the contract is a type of risk management contract prescribed by the Authority under clause 13.219B, the type of risk management contract:
- (h) if the contract is an options contract—
  - (i) whether it is a call option or a put option; and
  - (ii) if it is a call option, whether the buyer has the right to buy less than the quantity; and
  - (iii) whether it is a cap option or floor option; and
  - (iv) the option style (for example, American or Asian):
- (i) the fuel type (for example, solar, wind, thermal, or hydro), if specified in the contract:
- (j) the premium, if specified in the contract:
- (k) the trading periods during which each price in the contract applies:
- (l) in relation to each trading period during which a price in the contract applies—
  - (i) the node at which each price is set; and
  - (ii) the price or series of prices to be paid at each relevant node; and
  - (iii) if applicable, the specified volume of electricity for each price to be paid at each relevant node:
- (m) whether price (or prices) in the contract are linked to consumption or generation of electricity:
- (n) whether there is an adjustment clause:
- (o) whether there is a force majeure clause:
- (p) whether there is a special credit clause:
- (q) whether there is a suspension clause:
- (r) whether there are any other clauses providing for the pass-through of certain costs, levies or tax or some form of carbon-related cost:
- (s) whether the contract uses any version of the International Swaps and Derivatives Association Master Agreement (ISDA Master Agreement) (including where the schedule to the form of the ISDA Master Agreement used for the contract makes an amendment to the main part of the ISDA Master Agreement):
- (t) any other information specified in a notice published by the Authority under clause 13.219A.
(2) The party specified in clause 13.218 must submit the information required by this clause in the form specified by the Authority and in accordance with clause 13.225(1).

Compare: Electricity Governance Rules 2003 rule 3 section VI part G

Clause 13.219(1), (2), (3), (4) and (6): amended, on 5 October 2017, by clause 453 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.219: replaced, on 30 October 2024, by clause 7 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.219A

Authority may prescribe additional information that must be submitted

(1) The Authority may publish a notice prescribing additional information relating to a risk management contract that must be submitted under clause 13.219(1)(t).
(2) The Authority may prescribe additional information under subclause (1) only for a purpose specified in clause 13.217.
(3) Before publishing a notice under subclause (1), the Authority must—
- (a) publish a proposed notice that contains—
  - (i) the information relating to a risk management contract that the Authority intends to prescribe as additional information that must be submitted under clause 13.219(1)(t); and
  - (ii) the Authority’s purpose in requiring disclosure of the additional information; and
  - (iii) the Authority’s assessment of the likely benefits of requiring the disclosure of the additional information prescribed in the proposed notice and whether those benefits are expected to outweigh the likely costs; and
  - (iv) the proposed date or dates on which the disclosure of the additional information will apply; and
- (b) provide a reasonable opportunity for persons to make submissions to the Authority on the proposed notice; and
- (c) consider submissions received under paragraph (b) in deciding whether to—
  - (i) make any reasonable changes to the additional information required by the proposed notice; and
  - (ii) publish the notice.

Clause 13.219A: inserted, on 30 October 2024, by clause 8 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.219B

Authority may prescribe additional risk management contract

(1) The Authority may publish a notice prescribing any type of contract used to manage risk in relation to the spot market for electricity as a risk management contract to which this subpart applies.
(2) The Authority may prescribe any type of contract as a risk management contract under subclause (1) only for a purpose specified in clause 13.217.
(3) Before publishing a notice under subclause (1), the Authority must—
- (a) publish a proposed notice that contains—
  - (i) the type or types of contract that the Authority intends to prescribe as a risk management contract; and
  - (ii) the Authority’s purpose in prescribing the type or types of contract as a risk management contract; and
  - (iii) the Authority’s assessment of the likely benefits of prescribing the type or types of contract as a risk management contract and whether those benefits are expected to outweigh the likely costs; and
  - (iv) a list of any additional information that parties to the type or types of contract must submit to the Authority under clause 13.219A; and
  - (v) the proposed date or dates on which this subpart will apply to the type or types of contract; and
- (b) provide a reasonable opportunity for persons to make submissions to the Authority on the proposed notice; and
- (c) consider submissions received under paragraph (b) in deciding whether to—
  - (i) make any reasonable changes to the proposed notice; and
  - (ii) publish the notice.

Clause 13.219B: inserted, on 30 October 2024, by clause 9 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.220 Calculation of contract prices

(1) Following the receipt of information submitted under clause 13.219, the WITS manager must calculate—
- (a) the time weighted contract price in accordance with subclause (2); and
- (b) the load weighted contract price in accordance with subclause (3).
(2) The time weighted contract price is to be calculated in accordance with the following formula:

where

CP_tw

is the time weighted contract price

n

is the number of different prices within the contract

P_i

is the price specified in the contract

TP_i

is the number of trading periods during which each price in the contract applies

LF

is the location factor, for the relevant node at which the price is set in the contract, as published by the WITS manager in accordance with clause 13.221

LAF

means a loss adjustment factor, which is,—

(a) if the time weighted contract price for the contract is referenced to a point of connection on the grid, 1; or
(b) for all other contracts, 0.937 (being the difference between 1 and the loss factor of 0.063).

(3) The load weighted contract price is to be calculated in accordance with the following formula:

where

CP_lw

is the load weighted contract price

n

is the number of different prices within the contract

P_i

is the price specified in the contract

V_i

is the volume of electricity for each trading period during which each price in the contract applies

LF

is the location factor, for the relevant node at which the price is set in the contract, as published by the WITS manager in accordance with clause 13.221

LAF

means a loss adjustment factor, which is,—

(a) if the load weighted contract price for the contract is referenced to a point of connection on the grid, 1; or
(b) for all other contracts, 0.937 (being the difference between 1 and the loss factor of 0.063).

(4) Where a risk management contract includes prices at more than 1 node, the WITS manager will calculate the time weighted contract price and load weighted contract price at each node.
(5) To avoid doubt, if a risk management contract includes an adjustment clause, the time weighted contract price and load weighted contract price is that which applies before the adjustment clause takes effect.

Compare: Electricity Governance Rules 2003 rule 4 section VI part G

Clause 13.220(2): amended, on 5 October 2017, by clause 454 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.220: replaced, on 30 October 2024, by clause 10 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.221 Node and grid zone area information

(1) The WITS manager must publish annually,—
- (a) a list of all nodes at which the clearing manager makes final prices available on WITS; and
- (b) a corresponding location factor for each such node; and
- (c) a corresponding grid zone area for each such node; and
- (d) a list of nominated zone nodes, being 1 node at which the clearing manager makes final prices available on WITS, within each grid zone area.
(2) For the purposes of subclause (1)(b), the location factor for each such node must be calculated as follows:

LF = A/B

where

A

is the average final price made available on WITS at that node over the 12 month period preceding the month before the date on which the location factors are published

B

is the average final price made available on WITS at the relevant nominated zone node, as published in accordance with subclause (1)(d), for the 12 month period preceding the month before the date on which the location factors are published

LF

is the location factor to be published in accordance with subclause (1)(b).

Compare: Electricity Governance Rules 2003 rule 5 section VI part G

Clause 13.221(1) and (2): amended, on 5 October 2017, by clause 455 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.221(1)(a) and (d): amended, on 1 November 2022, by clause 152 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13.222 [Revoked]

Compare: Electricity Governance Rules 2003 rule 6 section VI part G

Clause 13.222(1): amended, on 5 October 2017, by clause 456 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.222: revoked, on 30 October 2024, by clause 11 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.222A

Information about other contracts that must be submitted

If a participant enters into a contract where a substantial purpose is to manage risk for the participant in relation to the spot market for electricity, but that contract is not a risk management contract, the participant must submit to the approved system—
- (a) notification that the participant has entered into the contract; and
- (b) a description of the key terms of the contract.

Clause 13.222A: inserted, on 30 October 2024, by clause 12 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.223 Modified or amended information

(1) If a risk management contract is modified or amended after the information referred to in clause 13.219 is submitted to the approved system and the effect of the modification or amendment is that the information submitted to the approved system is no longer correct or complete, the party specified in clause 13.218 must submit the modified or amended information to the approved system.
(2) The party specified in clause 13.218 must submit the information under subclause (1)—
- (a) so that it identifies in each case the information that has been modified or amended; and
- (b) in the form specified by the Authority; and
- (c) in accordance with clause 13.225(2).

Compare: Electricity Governance Rules 2003 rule 7 section VI part G

Clause 13.223(1): amended, on 5 October 2017, by clause 457 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.223(1): replaced, on 30 October 2024, by clause 13(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.223(2): amended, on 30 October 2024, by clause 13(2) to (5) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.224 Correction of information

Except when clause 13.223 applies, if the party specified in clause 13.218 discovers that information previously submitted to the approved system about that risk management contract is incorrect or incomplete, that party must—
- (a) seek to agree with the other party to the risk management contract that the information is incorrect or incomplete and how it should be corrected; and
- (b) when both parties have agreed that the incorrect or incomplete information should be corrected, submit the corrected information to the approved system in accordance with clause 13.225(3).

Compare: Electricity Governance Rules 2003 rule 8 section VI part G

Clause 13.224: amended, on 5 October 2017, by clause 458 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.224: amended, on 30 October 2024, by clause 14 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.225 Timeframes for submitting information

(1) The party specified in clause 13.218 must submit the information specified in clause 13.219 to the approved system—
- (a) in respect of a contract for differences or an options contract, no later than 5pm, 5 business days after the trade date; and
- (b) for any other type of risk management contract, no later than 5pm, 10 business days after the trade date.
(2) The party specified in clause 13.218 must submit any modified or amended information under clause 13.223(1) to the approved system no later than 5pm, 5 business days after the amendment or modification to the risk management contract is made.
(3) A participant that discovers under clause 13.224 that information it submitted to the approved system is incorrect or incomplete must submit the corrected information to the approved system no later than 5pm, 2 business days after both parties to the risk management contract have agreed how the incorrect or incomplete information should be corrected.
(4) The party specified in clause 13.227A(3) must submit the corrected information agreed under clause 13.227(3A) to the approved system no later than 5pm on the date that is 2 business days after the date that the parties to the risk management contract agreed on the corrected information.

Compare: Electricity Governance Rules 2003 rule 9 section VI part G

Clause 13.225(1) to (4): amended, on 5 October 2017, by clause 459 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.225(1): amended, on 30 October 2024, by clause 15(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.225(2): amended, on 30 October 2024, by clause 15(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.225(4): replaced, on 30 October 2024, by clause 15(3) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.226 WITS manager must make certain information available to Authority

(1) The WITS manager must, as soon as practicable, make the following information in relation to every risk management contract available to the Authority:
- (a) information submitted under clause 13.219:
- (b) whether the contract applies to all trading periods within its term:
- (c) the time weighted contract price and load weighted contract price calculated in accordance with clause 13.220 or, if clause 13.220(4) applies, the time weighted contract prices and load weighted contract prices:
- (d) the premium, expressed as an amount of dollars per MWh:
- (e) the grid zone area in which the, or each, time weighted contract price and load weighted contract price is determined or applies:
- (f) where any information is submitted under clauses 13.223(1) and 13.224,—
  - (i) that information, to the extent that it modifies, amends, or corrects information made available under paragraph (a); and
  - (ii) any necessary amendments to the information made available under paragraphs (b) to (e).
(1A) The WITS manager must, as soon as practicable, make information submitted under clause 13.222A available to the Authority.
(2) At the same time that it makes information submitted under clause 13.219 or 13.223(1) available in accordance with subclause (1), the WITS manager must—
- (a) [Revoked]
- (b) for a risk management contract other than a fixed-price physical supply contract, give a written notice to the other party to the contract—
  - (i) (if the other party is a participant) requiring the other party to submit a verification notice to the approved system within 2 business days of receiving the notice confirming whether or not the information is correct; or
  - (ii) (if the other party is not a participant) giving the other party the option to submit a verification notice to the approved system within 2 business days of receiving the notice confirming whether or not the information is correct; or
- (c) if the contract is a fixed-price physical supply contract, give a written notice to the other party giving the other party the option to submit a verification notice to the approved system within 2 business days confirming whether or not the information is correct.
(3) A participant that receives a verification notice under subclause (2)(b)(i) must comply with the written notice.

Compare: Electricity Governance Rules 2003 rule 10 section VI part G

Clause 13.226 Heading: replaced, on 5 October 2017, by clause 460(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.226 Heading: amended, on 30 October 2024, by clause 16(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.226(1): replaced, on 5 October 2017, by clause 460(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.226(1): replaced, on 30 October 2024, by clause 16(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.226(1A): inserted, on 30 October 2024, by clause 16(3) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.226(2): amended, on 5 October 2017, by clause 460(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.226(2): amended, on 30 October 2024, by clause 16(4) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.226(2)(a): revoked, on 30 October 2024, by clause 16(5) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.226(2)(b): amended, on 30 October 2024, by clause 16(6) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.226(3): amended, on 5 October 2017, by clause 460(4) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.226A

Authority must make certain information publicly available

(1) Subject to subclause (2), the Authority must, as soon as practicable after the WITS manager makes information available to the Authority under clause 13.226(1), publish the following information in relation to every risk management contract:
- (a) information submitted under clauses 13.219(1)(c) to 13.219(1)(h), 13.219(1)(j), and 13.219(1)(m) to 13.219(1)(s):
- (b) information made available under clauses 13.226(1)(b) to (e):
- (c) where any information is submitted under clauses 13.223(1) and 13.224, —
  - (i) that information, to the extent that it modifies, amends, or corrects information published under paragraph (a); and
  - (ii) any necessary amendment to the information published under paragraph (b).
(2) If the risk management contract is for the purchase of electricity linked to generation at a particular generating plant or generating plants, or generating station or generating stations, the Authority may also publish the following information in relation to the risk management contract:
- (a) information submitted under clauses 13.219(1)(c), 13.219(1)(f) to 13.219(1)(h), and 13.219(1)(m) to 13.219(1)(s):
- (b) information made available under clause 13.226(1)(b):
- (c) where any information is submitted under clauses 13.223(1) and 13.224,—
  - (i) that information, to the extent that it modifies, amends, or corrects information published under paragraph (a); and
  - (ii) any necessary amendment to the information published under paragraph (b).
(3) When information submitted under clause 13.219 or 13.223(1) is first published under subclause (1) or (2), the Authority must indicate that the information is unverified.
(4) The Authority must, as soon as practicable, update the indication made under subclause (3) to verified, pending verification, not disputed, disputed or subject to a long-term dispute every time the WITS manager notifies the Authority of a change in accordance with clauses 13.227(1) to (3), 13.227(4) and 13.227A(4).

Clause 13.226A: inserted, on 30 October 2024, by clause 17 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.227 Process on verification of information or otherwise

(1) The WITS manager must notify the Authority, as soon as practicable, that the information made available under clause 13.226(1) is verified if the other party to a risk management contract submits a verification notice to the approved system within 2 business days of receiving notice under clause 13.226(2) confirming that the information made available under clause 13.226(1) is correct.
(2) The WITS manager must notify the Authority, as soon as practicable, that the information made available under clause 13.226(1) is not disputed, if—
- (a) the other party to a risk management contract other than a fixed-price physical supply contract is not a participant and does not submit a verification notice to the approved system within 2 business days of receiving notice under clause 13.226(2)(b)(ii); or
- (b) the other party to a fixed-price physical supply contract does not submit a verification notice to the approved system within 2 business days of receiving notice under clause 13.226(2)(c).
(3) The WITS manager must notify the Authority, as soon as practicable, that the information made available under clause 13.226(1) is disputed if the other party to a risk management contract submits a verification notice to the WITS manager within 2 business days of receiving notice under clause 13.226(2) advising that the information made available under clause 13.226(1) is not correct.
(3A) If the information made available under clause 13.226(1) is disputed, the WITS manager must give the parties to the relevant risk management contract a written notice requiring the parties to use all reasonable endeavours to agree within 10 business days of receiving the notice on—
- (a) whether the information made available under clause 13.226(1) is correct; and
- (b) if not, what corrections should be made to the information.
(4) If the other party to a risk management contract other than a fixed-price physical supply contract is a participant that has not submitted a verification notice within 2 business days of receiving notice in accordance with clause 13.226(2)(b)(i), the WITS manager must—
- (a) notify the Authority, as soon as practicable, that the information made available in accordance with clause 13.226(1) is pending verification; and
- (b) give the other party a written reminder notice requiring the other party to submit a verification notice as soon as possible.
(5) [Revoked]
(6) [Revoked]
(7) [Revoked]
(8) [Revoked]
(9) [Revoked]

Compare: Electricity Governance Rules 2003 rule 11 section VI part G

Clause 13.227 Heading: amended, on 30 October 2024, by clause 18(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.227(1): amended, on 5 October 2017, by clause 461(1) and (2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.227(1): amended, on 30 October 2024, by clause 18(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.227(2): amended, on 30 October 2024, by clause 18(3) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.227(2): amended, on 5 October 2017, by clause 461(2) and (3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.227(2)(a): amended, on 30 October 2024, by clause 18(4) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.227(3): amended, on 5 October 2017, by clause 461(2) and (4) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.227(3): replaced, on 30 October 2024, by clause 18(5) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.227(3A): inserted, on 30 October 2024, by clause 18(6) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.227(4): amended, on 30 October 2024, by clause 18(7) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.227(4): amended, on 5 October 2017, by clause 461(2), (5) and (6) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.227(4)(a): amended, on 30 October 2024, by clause 18(8) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.227(5): amended, on 5 October 2017, by clause 461(2), (6) and (7) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.227(6): amended, on 5 October 2017, by clause 461(8) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.227(7): amended, on 5 October 2017, by clause 461(2) and (9) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.227(8): amended, on 5 October 2017, by clause 461(2) and (9) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.227(9): amended, on 5 October 2017, by clause 461(10) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clauses 13.227(5), (6), (7), (8) and (9): revoked, on 30 October 2024, by clause 18(9) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.227A

Parties to comply with written notices from WITS manager

(1) The parties must comply with any written notice from the WITS manager under clause 13.227(3A) or (4)(b).
(2) If the parties to the risk management contract agree under clause 13.227(3A) that the information made available under clause 13.226(1) is correct, the other party must submit a verification notice to the approved system confirming that the information is correct.
(3) If the parties to the risk management contract agree under clause 13.227(3A) to a correction to the information made available under clause 13.226(1), the party that submitted that information to the approved system must submit the corrected information in accordance with clause 13.225(4).
(4) If the parties to the risk management contract have not complied with subclauses (2) or (3) within 10 business days of receiving the written notice from the WITS manager under clause 13.227(3A) or (4)(b), the WITS manager must notify the Authority that the information is subject to a long term dispute.

Clause 13.227A: inserted, on 30 October 2024, by clause 19 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.228 Confirmation of information submitted through approved system

(1) The WITS manager must, using the approved system, confirm receipt of any information received by it under clauses 13.219, 13.222A, 13.223 or 13.224.
(2) Each confirmation under subclause (1) must contain a copy of the information received using the approved system, together with the date and time of receipt.

Compare: Electricity Governance Rules 2003 rule 12 section VI part G

Clause 13.228 Heading: amended, on 5 October 2017, by clause 462(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.228(1): amended, on 5 October 2017, by clause 462(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.228(1): amended, on 30 October 2024, by clause 20 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.228(2): amended, on 5 October 2017, by clause 462(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.229 Submitting party or participant to check if no confirmation received

(1) If a party or participant does not receive confirmation from the WITS manager under clause 13.228(1) within 6 hours of submitting the information, they must contact the WITS manager within 1 business day from the end of that 6 hour period to check whether the approved system has received the information.
(2) If the WITS manager advises the party or participant that the approved system has not received the information, the party or participant must resubmit the information.
(3) This process must be repeated until the WITS manager has confirmed receipt of the information from the party or participant in accordance with clause 13.228.

Compare: Electricity Governance Rules 2003 rule 13 section VI part G

Clause 13.229 Heading: amended, on 30 October 2024, by clause 21(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.229(1): replaced, on 5 October 2017, by clause 463(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.229(1): replaced, on 30 October 2024, by clause 21(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.229(2) and (3): amended, on 5 October 2017, by clause 463(b) and (c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.229(2) and (3): amended, on 30 October 2024, by clause 21(3) and (4) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.230 Certification of information

(1) Each participant that has submitted information to the approved system in accordance with this subpart in a particular year ending 31 March must, by 30 June that year certify to the Authority that the information submitted was correct.
(2) The certification provided under subclause (1) must be—
- (a) [Revoked]
- (b) in the prescribed form; and
- (c) signed and dated by either—
  - (i) a director of the participant; or
  - (ii) the participant's chief financial officer, or person holding an equivalent position; or
  - (iii) the participant's chief executive officer, or person holding an equivalent position.

Compare: Electricity Governance Rules 2003 rule 14 section VI part G

Clause 13.230(1): replaced, on 5 October 2017, by clause 464(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.230(1): amended, on 30 October 2024, by clause 22(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.230(2): amended, on 5 October 2017, by clause 464(2)(a) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.230(2)(a): revoked, on 5 October 2017, by clause 464(2)(b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.230(2)(b): amended, on 30 October 2024, by clause 22(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.230(2)(c): replaced, on 5 October 2017, by clause 464(2)(c) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.231 Appointment of auditor

(1) The Authority may, in its discretion, require an audit as to whether a participant has complied with this subpart.
(2) If the Authority requires an audit under subclause (1),—
- (a) the Authority must require the participant to nominate an appropriate auditor; and
- (b) the participant must provide that nomination within a reasonable timeframe; and
- (c) the Authority may direct the participant to appoint the auditor nominated by the participant; and
- (d) if the participant fails to nominate an appropriate auditor within 20 business days, the Authority may direct the participant to appoint an auditor of the Authority’s choice.
(2A) The participant must appoint an auditor in accordance with a direction made under paragraph (2)(c) or (2)(d).
(3) [Revoked]
(4) [Revoked]
(4A) [Revoked]
(5) [Revoked]

Compare: Electricity Governance Rules 2003 rule 15 section VI part G

Clause 13.231 Heading: amended, on 30 October 2024, by clause 23(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.231(1): amended, on 30 October 2024, by clause 23(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.231(2): amended, on 5 October 2017, by clause 465 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.231(2): replaced, on 30 October 2024, by clause 23(3) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.231(2A): inserted, on 30 October 2024, by clause 23(4) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.231(4): substituted, on 1 February 2016, by clause 86(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.231(4A): inserted, on 1 February 2016, by clause 86(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.231(5): amended, on 1 February 2016, by clause 86(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13.231(3), (4), (4A) and (5): revoked, on 30 October 2024, by clause 23(5) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.231A

Audit process

(1) A participant subject to an audit under this clause must, on request from the auditor, provide the auditor with a copy of every risk management contract that it has entered into in the previous 12 months or within such other period specified by the auditor.
(2) The participant must provide the information no later than 20 business days after receiving a request from the auditor for the information.
(3) The participant must ensure that the auditor produces an audit report on the participant’s compliance with this subpart and submits the audit report to the Authority within the timeframe specified by the Authority.
(4) Before the audit report is submitted to the Authority, the auditor must refer any apparent failure by the participant to comply with this subpart that the auditor has identified to the participant for comment within the timeframe specified by the auditor.
(5) The audit report must include any comments from the participant on any apparent non-compliance that the auditor referred to the participant under subclause (4) if the participant provided comments to the auditor within the time specified by the auditor.
(6) The audit report does not need to contain a copy of any risk management contract that the participant has provided to the auditor in accordance with subclause (1), unless the Authority has specifically required the auditor to include a copy of any risk management contract in the audit report.

Clause 13.231A: inserted, on 30 October 2024, by clause 24 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.232 Payment of costs relating to audits

(1) If an audit establishes to the reasonable satisfaction of the Authority that a participant may not have complied with this subpart, the participant must pay for the audit even if the Authority declines to appoint an investigator to investigate the alleged breach.
(2) If the Authority considers that the apparent non-compliance of the participant is minor or relates to some (but not all) of the clauses in this subpart, the Authority may, in its discretion, make an assessment regarding the proportion of the costs of the audit that are to be paid by the participant, and those costs must be paid by the participant.
(3) If an audit establishes to the reasonable satisfaction of the Authority that the participant has complied with this subpart, the participant is not required to pay any of the auditor’s costs.

Compare: Electricity Governance Rules 2003 rule 16 section VI part G

Clause 13.232(1): amended, on 30 October 2024, by clause 25(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.232(2): amended, on 30 October 2024, by clause 25(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.233 WITS manager and Authority must keep certain information confidential

(1) The Authority must keep, and ensure that the WITS manager keeps, information submitted to the approved system under this subpart confidential, unless—
- (a) the information is provided by the Authority to subcontractors or service providers that the Authority appoints to provide services for the purposes of this subpart, and those subcontractors or service providers have agreed to keep that information confidential, on the same terms as apply to the Authority under this clause; or
- (b) disclosure is required to enable the Authority or the WITS manager to carry out its obligations and duties under the Act, this Code or the Electricity Industry (Enforcement) Regulations 2010 or is otherwise required by law; or
- (c) the party, parties or other persons to whom the information relates have provided written consent to the disclosure; or
- (d) [Revoked]
- (e) the information is otherwise publicly available at the time that the Authority discloses it.
(1A) The obligation in subclause (1) does not prevent the Authority from—
- (a) using the information for any purpose in connection with the Authority’s objectives set out in section 15 of the Act or the Authority’s functions in section 16 of the Act or section 14 of the Crown Entities Act 2004; or
- (b) disclosing the information in connection with a purpose referred to in paragraph (a) in anonymised form or in consolidated form.
(2) The Authority may use copies of a risk management contract provided to the Authority under clause 13.231A(6) only for purposes related to this subpart and the enforcement of this subpart.

Compare: Electricity Governance Rules 2003 rule 17 section VI part G

Clause 13.233 Heading: amended, on 5 October 2017, by clause 466(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.233 Heading: amended, on 30 October 2024, by clause 26(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.233(1): amended, on 30 October 2024, by clause 26(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.233(1)(b): replaced, on 30 October 2024, by clause 26(3) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.233(1)(c): amended, on 30 October 2024, by clause 26(4) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.233(1)(d): revoked, on 30 October 2024, by clause 26(5) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.233(1)(e): inserted, on 30 October 2024, by clause 26(6) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.233(1A): inserted, on 30 October 2024, by clause 26(7) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.233(1) and (2): amended, on 5 October 2017, by clause 466(2)(a) and (b) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.233(2): amended, on 30 October 2024, by clause 26(8) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.234 No misleading information

A party may not submit any information that, at the time the information was submitted, was misleading or deceptive or likely to mislead or deceive.

Compare: Electricity Governance Rules 2003 rule 18 section VI part G

13.235 Risk management contracts must be lawful

A party may not submit information if that party knows or ought reasonably to know that the risk management contract to which that information applies would contravene any law.

Compare: Electricity Governance Rules 2003 rule 19 section VI part G

13.236 Availability of information

The WITS manager may only remove information that is submitted under clauses 13.219, 13.223, or 13.224 from the approved system 12 months after the termination of the risk management contract that the information relates to.

Compare: Electricity Governance Rules 2003 rule 20 section VI part G

Clause 13.236: amended, on 5 October 2017, by clause 467 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236: replaced, on 30 October 2024, by clause 27 of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

13.236AA

Requirement to provide consent to exchange

(1) Each participant must ensure that, before placing any bid or offer for, or entering into, an exchange-traded risk management contract, it has provided the consent described in clause 13.236AA(2) to the exchange through which the bid or offer will be placed or contract entered into, which consent must continue to be in effect at the time any such bid or offer is placed or contract is entered into.
(2) The participant must ensure that the consent is in the prescribed form and allows the exchange to provide any of the following de-anonymised information (including historical information) to the Authority at such frequency as may be required by the Authority from time to time:
- (a) any information, documents or data in relation to bids or offers placed for risk management contracts, or in relation to such contracts entered into, by, or on behalf of, the participant (including in relation to buy and sell prices, trading periods, volumes and quantities):
- (b) any information, documents or data in relation to the number of outstanding risk management contracts held by, or on behalf of, the participant at the end of each trading day:
- (c) where the participant has an agreement with an exchange that imposes requirements on the participant in relation to the exchange’s market-making scheme for risk management contracts, any other information, documents or data that the Authority may require in relation to the participant’s performance of its obligations under that agreement.
(3) The participant must ensure that all necessary arrangements are in place with any agent, associate, contractor, service provider, or other person acting on behalf of, or on the instructions of the participant, immediately after providing consent in accordance with subclause (1), to permit and facilitate the provision of all information described in subclause (2) by the exchange to the Authority.
(4) The participant must, within 5 business days of receiving a written request from the Authority, supply the Authority with such evidence as may be reasonably required by the Authority to satisfy itself that the consent and arrangements required by this clause 13.236AA are in full force and effect.
(5) The Authority may issue guidelines to assist participants to identify the types of information the Authority may obtain from an exchange and the types of arrangements it expects participants to put in place to permit and facilitate the provision of such information.

Clause 13.236AA: inserted, on 29 October 2020, by clause 4 of the Electricity Industry Participation Code Amendment (Securing Access to Exchange Data) 2020.

Clause 13.236AA(2): amended, on 30 October 2024, by clause 28(1) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.236AA(3): replaced, on 30 October 2024, by clause 28(2) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Clause 13.236AA(4): amended, on 30 October 2024, by clause 28(3) of the Electricity Industry Participation Code Amendment (Hedge Disclosure Obligations) 2024.

Subpart 5A—Spot price risk disclosure

Subpart 5A: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

13.236AB

Purpose of spot price risk disclosure

The purpose of this subpart is:
- (a) to promote awareness by each disclosing participant of its exposure to spot price risk:
- (b) to encourage each disclosing participant to take active steps to prudently and proactively manage its exposure to spot price risk:
- (c) to emphasise that each disclosing participant is responsible for the extent to which it is exposed to spot price risk:
- (d) to set out reporting requirements that ensure the stress testing regime is fit for purpose in a renewables-based system:
- (e) to provide the Authority with more information on which to assess long-term issues and risks for the purposes of its objectives in section 15 of the Act and its functions in section 16 of the Act.

Clause 13.236AB: inserted, on 15 May 2025, by clause 5 of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2025.

13.236A

Disclosing participants must prepare and submit spot price risk disclosure statements

(1) Each disclosing participant must prepare a spot price risk disclosure statement for each quarter beginning 1 January, 1 April, 1 July, and 1 October in each year for that quarter and the following 11 quarters in accordance with this subpart.
(2) [Revoked]
(3) The disclosing participant must submit the spot price risk disclosure statement to the person appointed by the Authority to receive spot price risk disclosure statements no later than 5 business days before the beginning of the quarter to which the statement relates.
(4) A participant is not required to comply with this clause for a quarter if it is a disclosing participant in relation to the quarter only because it is subject to a wash-up in that quarter.

Clause 13.236A: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

Clause 13.236A(1) and (2): amended, on 5 October 2017, by clause 468 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236A(1): amended, on 15 May 2025, by clause 6(1) of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2025.

Clause 13.236A(2): revoked, on 15 May 2025, by clause 6(2) of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2025.

Clause 13.236A(4): inserted, on 1 February 2016, by clause 87 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

13.236B

Authority must appoint a person to receive and analyse spot price risk disclosure statements

(1) The Authority must appoint an independent person to receive and analyse spot price risk disclosure statements.
(2) The Authority must enter into a contract with the person appointed to receive and analyse spot price risk disclosure statements.
(3) The contract with the person appointed to receive and analyse spot price risk disclosure statements must include the following:
- (a) a requirement that the person does not disclose any spot price risk disclosure statement to any other person, including that it does not disclose any spot price risk disclosure statement to the Authority:
- (b) a requirement that the person provide information regarding spot price risk disclosure statements to the Authority in a form that does not identify the disclosing participant to which it relates.

Clause 13.236B: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

13.236C

Authority may approve consolidated spot price risk disclosure statements

On application by 1 or more disclosing participants, the Authority may approve those disclosing participants preparing and submitting a consolidated spot price risk disclosure statement.

Clause 13.236C: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

13.236D

Authority must publish base case, stress test, and method for calculating target cover ratio

(1) The Authority must publish a notice setting out the following:
- (a) a base case:
- (b) 1 or more stress tests:
- (c) 1 or more methods for calculating a disclosing participant's actual and target cover ratio.
(2) If the Authority has not published a notice under subclause (1) at least 30 business days before the start of a quarter in respect of which a spot price risk disclosure statement is required to be prepared, a disclosing participant is not required to prepare or submit a spot price risk disclosure statement for the next quarter.
(3) If the Authority publishes an amendment to a notice, or revokes and replaces a notice, within 30 business days before the start of a quarter in respect of which a spot price risk disclosure statement is required to be prepared, disclosing participants must prepare spot price risk disclosure statements for the immediately following quarter in accordance with the notice as in force immediately before the amendment or replacement was made and not in accordance with the notice as amended or replaced.

Clause 13.236D: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

Clause 13.236D Heading: amended, on 5 October 2017, by clause 469(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236D: amended, on 5 October 2017, by clause 469(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236D(1)(c): amended, on 15 May 2025, by clause 7 of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2025.

13.236E

Content of spot price risk disclosure statements

(1) A spot price risk disclosure statement submitted under this subpart must include the following:
- (a) the disclosing participant's annual net cash flow from operating activities as set out in the disclosing participant's most recent set of audited annual financial statements:
- (b) the disclosing participant's level of shareholders' equity as set out in the disclosing participant's most recent set of audited annual financial statements:
- (c) the disclosing participant's estimate of the value of electricity that it expects to sell to the clearing manager during the period to which the stress test relates when the stress test is applied, minus the disclosing participant's estimate of the value of that electricity under the base case for that period:
- (d) the disclosing participant's estimate of the value of electricity that it expects to purchase from the clearing manager during the period to which the stress test relates when the stress test is applied, minus the disclosing participant's estimate of the value of that electricity under the base case for that period:
- (e) the disclosing participant's estimate of the projected net cash flows from operating activities of the disclosing participant during the period to which the stress test relates when the stress test is applied, minus the disclosing participant's estimate of those cash flows under the base case for that period:
- (f) a statement as to whether the disclosing participant has an explicit risk management policy in respect of its exposure to the wholesale market:
- (g) if the disclosing participant has an explicit risk management policy, the disclosing participant's—
  - (i) target cover ratio, for each stress test, calculated in accordance with the relevant method published by the Authority under clause 13.236D for the quarter to which the statement relates; and
  - (ii) actual cover ratio for the quarter before the quarter in which the spot price risk disclosure statement is prepared and submitted if the information that enables this to be calculated exists.
(1A) Despite subclause (1), a disclosing participant is not required to include the information in subclause (1) in its spot price risk disclosure statement for a quarter if—
- (a) the disclosing participant expects that a change in spot prices would not affect the disclosing participant's cash flow from operating activities in the quarter; and
- (b) the disclosing participant’s spot price risk disclosure statement for the quarter includes a statement that the disclosing participant expects that a change in spot prices would not affect the disclosing participant's cash flow from operating activities in the quarter.
(2) For the purposes of subclause (1),—
- (a) electricity is deemed to be sold to the clearing manager by a disclosing participant if it is sold to the clearing manager on the disclosing participant's behalf; and
- (b) electricity is deemed to be purchased from the clearing manager by a disclosing participant if it is purchased from the clearing manager on the disclosing participant's behalf.
(3) The disclosing participant must ensure that a spot price risk disclosure statement is signed and dated by a director, or the chief executive officer, or the chief financial officer, or a person holding a position equivalent to one of those positions, of the disclosing participant no earlier than 20 business days and no later than 5 business days before the beginning of the quarter to which the statement relates.
(4) In preparing a spot price risk disclosure statement, a disclosing participant must have regard to all relevant factors, including (without limitation)—
- (a) any financial instruments in which the disclosing participant has an interest; and
- (b) any other measures that the disclosing participant has in effect to manage the risk arising from its exposure to the wholesale market; and
- (c) any other arrangements that the disclosing participant has in place to manage that risk; and
- (d) any amounts of electricity that the disclosing participant expects to buy from, or sell to, the clearing manager.

Clause 13.236E: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

Clause 13.236E(1)(g) and (3): amended, on 5 October 2017, by clause 470 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236E(1A): inserted, on 6 November 2017, by clause 4 of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2017.

Clause 13.236E(1)(g): replaced, on 15 May 2025, by clause 8 of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2025.

13.236F

Certification of spot price risk disclosure statement

(1) A disclosing participant who has submitted a spot price risk disclosure statement in accordance with this subpart must certify to the Authority—
- (aa) that the board of the disclosing participant confirms that the disclosing participant has complied with the spot price risk disclosure statement requirements in clauses 13.236A and 13.236E; and
- (a) that the board of the disclosing participant has considered—
  - (i) every spot price risk disclosure statement submitted under this subpart by the disclosing participant in the period to which the certification relates; and
  - (ii) the projected change in net cash flows from operating activities of the disclosing participant as a result of applying the stress test or stress tests that relate to each period to which each spot price risk disclosure statement relates; and
- (b) that the disclosing participant has provided to each of the disclosing participant's customers who, in the period to which the certification relates, has entered into or renewed a contract with the disclosing participant that results in any electricity supplied to the customer being determined directly by reference to the final price at a GXP, information to enable the customer to consider the outcomes of applying the stress test or stress tests to the customer; and
- (c) if the disclosing participant has an explicit risk management policy in respect of its exposure to the wholesale market, that the board of the disclosing participant—
  - (i) has approved the policy; and
  - (ii) considers the policy to be appropriate for the disclosing participant’s requirements, having regard to all the relevant factors, including the nature of price volatility in electricity spot markets, the disclosing participant’s business scope, physical assets and financial resources; and
  - (iii) actively monitors the disclosing participant’s compliance with the policy; and
  - (iv) has reviewed the policy in the last 3 years.
(2) Each certification must be submitted as follows:
- (a) in the case of the first certification submitted by a disclosing participant, no later than the end of the fourth quarter following the quarter in which the first spot price risk disclosure statement is submitted by that disclosing participant (in which case the certification must relate to every spot price risk disclosure statement made by the disclosing participant in the preceding quarters):
- (b) in the case of every subsequent certification, no later than the end of the fifth quarter following the quarter in which the last certification was submitted (in which case the certification must relate to every spot price risk disclosure statement made by the disclosing participant since the last certification was submitted).
(3) Each certification submitted under subclause (2) must be—
- (a) in the form specified by the Authority; and
- (b) signed and dated by a director of the disclosing participant and either—
  - (i) another director of the disclosing participant; or
  - (ii) the disclosing participant's chief executive officer, or person holding an equivalent position; or
  - (iii) the disclosing participant's chief financial officer, or person holding an equivalent position.

Clause 13.236F: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

Clause 13.236F(1): amended, on 5 October 2017, by clause 471(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236F(1)(aa): inserted, on 15 May 2025, by clause 9(1) of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2025.

Clause 13.236F(1)(b): amended, on 15 May 2025, by clause 9(2) of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2025.

Clause 13.236F(1)(c): inserted, on 15 May 2025, by clause 9(3) of the Electricity Industry Participation Code Amendment (Spot Price Risk Disclosure) 2025.

Clause 13.236F(2): amended, on 5 October 2017, by clause 471(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236F(3): replaced, on 5 October 2017, by clause 471(3) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.236G

Authority may require disclosing participant to submit new spot price risk disclosure statement

(1) The Authority may, by notice in writing to a disclosing participant who submitted a spot price risk disclosure statement, require the disclosing participant to submit a new spot price risk disclosure statement.
(2) If a disclosing participant receives a request from the Authority under subclause (1), the disclosing participant must submit a new spot price risk disclosure statement to the person appointed by the Authority to receive spot price risk disclosure statements within 10 business days after the date on which the disclosing participant received the request.
(3) Clause 13.236E applies to a spot price risk disclosure statement submitted under this clause.

Clause 13.236G: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

Clause 13.236G(2): amended, on 5 October 2017, by clause 472 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.236H

Authority may require independent audit of spot price risk disclosure statement or certification

(1) The Authority may, in its discretion, on the recommendation of the person appointed to receive and analyse spot price risk disclosure statements or on its own motion, require an audit of 1 or more of the following:
- (a) a spot price risk disclosure statement:
- (b) part of a spot price risk disclosure statement:
- (c) the information set out in the certification given under clause 13.236F.
(2) If the Authority requires an audit under subclause (1), the Authority must require the relevant disclosing participant to nominate an appropriate auditor.
(3) The disclosing participant must provide that nomination within a reasonable timeframe.
(4) The Authority may direct the disclosing participant to appoint the auditor nominated by the disclosing participant.
(5) If the disclosing participant fails to nominate an appropriate auditor within 5 business days, the Authority may direct the disclosing participant to appoint an auditor of the Authority's choice.
(6) The disclosing participant must appoint an auditor in accordance with a direction made under subsection (4) or subsection (5).
(7) A disclosing participant subject to an audit under this clause must, on request from the auditor, provide the auditor with such information as the auditor reasonably requires in order to audit the spot price risk disclosure statement or the information set out in the certification given under clause 13.236F (as the case may be).
(8) The disclosing participant must provide the information no later than 10 business days after receiving a request from the auditor for the information.
(9) The disclosing participant must ensure that the auditor produces an audit report on the spot price risk disclosure statement or the information set out in the certification given under clause 13.236F (as the case may be) and submits the audit report to the Authority.
(10) Before the audit report is submitted to the Authority, any failure of the spot price risk disclosure statement or the information set out in the certification given under clause 13.236F (as the case may be) to comply with this subpart must be referred back to the disclosing participant for comment.
(11) The comments of the disclosing participant must be included in the audit report.
(12) The disclosing participant may require that the auditor does not provide the Authority with a copy of any information that the disclosing participant has provided to the auditor in accordance with subclause (7).

Clause 13.236H Heading: amended, on 5 October 2017, by clause 473(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236H: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

Clause 13.236H(1), (5), (7), (8), (9) and (10): amended, on 5 October 2017, by clause 473(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.236I

Payment of auditor’s costs

(1) If an audit establishes, to the Authority's reasonable satisfaction, that a disclosing participant's spot price risk disclosure statement or the information set out in the certification given under clause 13.236F (as the case may be) has not complied with this subpart (whether or not the Authority appoints an investigator to investigate the alleged breach), the disclosing participant must pay the auditor's costs.
(2) If the Authority considers that the disclosing participant's non-compliance is minor, the Authority may, in its discretion, determine the proportion of the auditor's costs that the disclosing participant must pay, and the disclosing participant must pay those costs.
(3) If an audit establishes to the Authority's reasonable satisfaction that a disclosing participant's spot price risk disclosure statement or the information set out in the certification given under clause 13.236F (as the case may be) has complied with this subpart, the Authority must pay the auditor's costs.

Clause 13.236I: inserted on 1 December 2011, by clause 5 of the Electricity Industry Participation Code (Spot Price Risk Disclosure) Amendment 2011.

Clause 13.236I(1) and (3): amended, on 5 October 2017, by clause 474 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.236I(3): amended, on 21 September 2012, by clause 31 of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Subpart 5B—Hedge market arrangements

Heading: inserted on 3 February 2020, by clause 5 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2020.

Heading: revoked on 3 November 2020, in accordance with section 40(2)(b) of the Electricity Industry Act 2010.

Heading: replaced on 27 April 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2021.

13.236J

Contents of this subpart

This subpart provides for an active market for trading financial hedge contracts for electricity by specifying requirements for certain participants.

Clause 13.236J: inserted on 3 February 2020, by clause 5 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2020.

Clause 13.236J: revoked on 3 November 2020, in accordance with section 40(2)(b) of the Electricity Industry Act 2010.

Clause 13.236J: replaced on 27 April 2021, by clause 6 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2021.

13.236K

Application of subpart

(1) Subject to subclause (2), this subpart applies to the following participants:
- (a) Contact Energy Limited;
- (b) Genesis Energy Limited;
- (c) Mercury NZ Limited;
- (d) Meridian Energy Limited.
(2) This subpart applies to a participant specified in subclause (1) if that participant—
- (a) is not a party to a NZEF market-making agreement that includes the requirements set out in clause 13.236L; or
- (b) does not perform market-making services in accordance with the NZEF market-making agreement on three or more separate occasions in a period of 90 days, and that non-performance is not permitted by an exemption or otherwise under the NZEF market-making agreement.
(3) A participant to whom subclause (2) applies is relieved of its obligations under this subpart when the Authority—
- (a) is satisfied that the participant has complied with its obligations under this subpart for a period of 90 days; and
- (b) has given written notice to that effect to the participant, which the Authority must do within 5 business days of being satisfied as to compliance.

Clause 13.236K: inserted on 3 February 2020, by clause 5 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2020.

Clause 13.236K: revoked on 3 November 2020, in accordance with section 40(2)(b) of the Electricity Industry Act 2010.

Clause 13.236K: replaced on 27 April 2021, by clause 7 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2021.

Clause 13.236K(2)(a): amended on 12 September 2024, by clause 4 of the Electricity Industry Participation Code Amendment (Changed requirements for regulated market-makers) 2024 and expired on 12 June 2025.

13.236L

Requirement to quote

(1) Subject to subclauses (2) to (5), the participant must, for a minimum of 25 minutes in every NZEF market-making period, provide quotes for a minimum of—
- (a) 24 monthly NZ electricity futures for each of the Otahuhu reference node and the Benmore reference node (being 24 buy quotes and 24 sell quotes for each reference node) for the current month and each of the five months following the current month; and
- (b) 24 quarterly NZ electricity futures for each of the Otahuhu reference node and the Benmore reference node (being 24 buy quotes and 24 sell quotes for each reference node) for each calendar quarter that is available for trade on an exchange.
(2) The participant must not provide a quote under subclause (1) with a bid-ask spread that exceeds the greater of 3% or NZ$2. For the avoidance of doubt, where there are multiple buy orders and sell orders for a particular reference node for a particular month or calendar quarter in a NZEF market-making period, the requirement in this subclause means the bid-ask spread between the lowest priced buy order and the highest priced sell order (across those multiple orders) must not exceed the greater of 3% or NZ$2.
(3) Under subclause (1) for each NZEF market-making period, the participant must provide a quantity of initial quotes and (as applicable) volume refresh its quotes until it has traded the total required volume for each of the Otahuhu reference node and the Benmore reference node in relation to each particular month and calendar quarter as follows:
- (a) when first placing orders at or after the start of the NZEF market-making period, the participant is required to place a buy order of at least 12 quotes in total and a sell order of at least 12 quotes in total:
- (b) if either initial buy order or sell order is fully traded then that participant must (as applicable) volume refresh its order(s) such that where the amount of the total traded NZEF up to that point in time in the NZEF market-making period is—
  - (i) 12, then at the end of the volume refresh period the buy order must comprise at least 12 quotes and the sell order must comprise at least 12 quotes:
  - (ii) greater than 12, then at the end of the volume refresh period that participant must ensure that the number of quotes comprising each of the buy order and sell order respectively are a minimum of X, where—

X = 24 quotes – total traded NZEF

- (c) once the participant has traded the total required volume it may withdraw any remaining quotes.
(4) A participant required to volume refresh in accordance with clause 13.236L(3)(b) may also carry out any other changes not inconsistent with their obligations under this subpart that the participant chooses to make to any other order(s) for the particular month or calendar quarter and particular reference node that is the subject of the volume refresh.
(5) For the purpose of determining whether a participant has met the minimum time requirement of 25 minutes under clause 13.236L(1), a quote will not be treated as being provided during a volume refresh period.

Clause 13.236L: inserted on 3 February 2020, by clause 5 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2020.

Clause 13.236L: revoked on 3 November 2020, in accordance with section 40(2)(b) of the Electricity Industry Act 2010.

Clause 13.236L: replaced on 27 April 2021, by clause 8 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2021.

Clause 13.236L: replaced on 1 September 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2022.

Clause 13.236L(2): amended on 12 September 2024, by clause 5 of the Electricity Industry Participation Code Amendment (Changed requirements for regulated market-makers) 2024 and expired on 12 June 2025.

13.236LA

[Expired]

Clause 13.236LA: inserted on 12 September 2024, by clause 6 of the Electricity Industry Participation Code Amendment (Changed requirements for regulated market-makers) 2024 and expired on 12 June 2025.

13.236M

[Revoked]

Clause 13.236M: inserted on 3 February 2020, by clause 5 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2020.

Clause 13.236M: revoked on 3 November 2020, in accordance with section 40(2)(b) of the Electricity Industry Act 2010.

13.236N

Exemptions from requirement to quote

(1) The participant is exempt from the requirements in clause 13.236L in the following circumstances:
- (a) for a NZEF market-making period if—
  - (i) the participant cannot comply with a requirement in clause 13.236L in that NZEF market-making period because an exchange trading platform is disrupted or unavailable; or
  - (ii) in the reasonable opinion of the participant, entering into a contract for a NZ electricity future in that NZEF market-making period may cause the participant to breach an applicable law;
- (b) in addition to the exemptions in paragraph (a), for up to two NZEF market-making periods within any 20 consecutive NZEF market-making periods at the participant’s discretion.
(2) To avoid doubt, if the participant meets the criteria for exemption in subclause (1)(a)(i) or (1)(a)(ii) in relation to a NZEF market-making period, that NZEF market-making period will not count towards the participant’s two exemptions in subclause (1)(b).
(3) If the participant relies on an exemption under this clause 13.236N from the requirement to quote, the participant must notify the Authority of the exemption it has relied on and the basis for the exemption as soon as practicable but in any case no later than 1700 New Zealand time on the same business day that an exemption is relied on.

Clause 13.236N: inserted on 3 February 2020, by clause 5 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2020.

Clause 13.236N: revoked on 3 November 2020, in accordance with section 40(2)(b) of the Electricity Industry Act 2010.

Clause 13.236N: replaced on 27 April 2021, by clause 9 of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2021.

Clause 13.236N(1)(b): amended on 1 September 2022, by clause 6(1) of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2022.

Clause 13.236N(3): amended on 1 September 2022, by clause 6(2)(a) and (b) of the Electricity Industry Participation Code Amendment (Hedge Market Arrangements) 2022.

Subpart 6—Financial transmission rights

Heading: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.237 Contents of this subpart

This subpart provides for the processes by which—
(a) the FTR manager prepares and publishes the FTR allocation plan; and
(b) the Authority approves the FTR allocation plan; and
(c) the FTR manager allocates and creates FTRs; and
(d) the FTR manager operates the FTR register and collects information from the grid owner and clearing manager; and
(e) FTRs may be assigned; and
(f) the clearing manager collects and allocates FTR auction revenue and collects information from the FTR manager; and
(g) the Authority may direct the FTR manager to suspend the allocation of FTRs.

Clause 13.237: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.237(c): amended, on 1 November 2014, by clause 5 of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

FTR allocation plan

Heading: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.238 Preparation and publication of FTR allocation plan

(1) The FTR manager must prepare and publish an FTR allocation plan that complies with Schedule 13.5.
(2) The FTR manager must keep the FTR allocation plan published at all times.
(3) Subject to subclause (4), if Schedule 13.5 is amended, the FTR manager must, no later than 3 months after the date on which the amendment comes into force, submit to the Authority for approval under clause 13.241(4), a variation to the FTR allocation plan to make the FTR allocation plan consistent with Schedule 13.5.
(4) The FTR manager is not required to comply with subclause (3) if no amendment is necessary to make the FTR allocation plan consistent with Schedule 13.5.

Clause 13.238: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.238(2): replaced, on 5 October 2017, by clause 475 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.239 FTR manager gives draft FTR allocation plan to Authority

(1) The FTR manager must submit to the Authority for approval a draft FTR allocation plan by the date specified in the market operation service provider agreement between the FTR manager and the Authority.
(2) In preparing the draft FTR allocation plan, the FTR manager must—
- (a) consult with persons that the FTR manager thinks are representative of the interests of persons likely to be substantially affected by the plan; and
- (b) consider submissions made on the plan.
(3) The FTR manager must provide a copy of each submission received under subclause (2) to the Authority.

Clause 13.239: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.240 Authority approves FTR allocation plan

(1) The Authority must, as soon as practicable after receiving the draft FTR allocation plan, by notice in writing to the FTR manager—
- (a) approve the plan; or
- (b) decline to approve the plan.
(2) If the Authority declines to approve the draft FTR allocation plan, the Authority must publish the changes that the Authority wishes the FTR manager to make to the draft plan.
(3) When the Authority publishes the changes that the Authority wishes the FTR manager to make to the draft FTR allocation plan under subclause (2), the Authority must give written notice to the FTR manager and interested parties of the date by which submissions on the changes must be received by the Authority.
(4) Each submission on the changes to the draft FTR allocation plan must be made in writing to the Authority and be received on or before the date specified by the Authority under subclause (3).
(5) The Authority must—
- (a) provide a copy of each submission received to the FTR manager; and
- (b) publish the submissions.
(6) The FTR manager may make its own submission on the changes to the draft FTR allocation plan and the submissions received in relation to the changes. The Authority must publish the FTR manager's submission when it is received.
(7) The Authority must consider the submissions made to it on the changes to the draft FTR allocation plan.
(8) Following the consultation required by subclauses (3) to (7), the Authority may approve the FTR allocation plan subject to the changes that the Authority considers appropriate being made by the FTR manager.

Clause 13.240: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.240(3): amended, on 5 October 2017, by clause 476 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.241 Variations to FTR allocation plan

(1) A participant or the Authority may submit a proposal for a variation to the FTR allocation plan to the FTR manager.
(2) The FTR manager must provide a copy of each proposed variation received from a participant under subclause (1) to the Authority.
(3) The FTR manager must consider a proposed variation to the FTR allocation plan submitted under subclause (1).
(4) The FTR manager may submit a request for a variation to the FTR allocation plan to the Authority.
(5) The consultation and approval requirements under clause 13.239(2) and (3) and clause 13.240 apply to a request for a variation submitted under subclause (4) as if references to the draft plan were a reference to the requested variation.
(6) If the FTR manager does not submit a request for a variation submitted under subclause (1) to the Authority under subclause (4), the Authority may consider the proposal and require the FTR manager to submit a request for a variation based on the proposal to the Authority, and subclause (5) applies accordingly.
(7) The Authority may approve a variation requested under subclause (4) or subclause (6) without complying with the provisions referred to in subclause (5) if—
- (a) the Authority considers that it is necessary or desirable in the public interest that the requested variation be made urgently; and
- (b) the Authority publishes a notice of the variation and a statement of the reasons why the urgent variation is needed.
(8) Every variation made under subclause (7) expires on the date that is 9 months after the date on which the variation is made.

Clause 13.241: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Allocation, creation and reconfiguration of FTRs

Heading: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Heading: amended, on 1 November 2014, by clause 6 of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

13.242 FTR manager must allocate and create FTRs

(1) The FTR manager must conduct an FTR auction in accordance with the FTR allocation plan approved under clause 13.240 to—
- (a) allocate FTRs; and
- (b) create FTRs; and
- (c) reconfigure FTRs.
(2) Every FTR must relate to—
- (a) a minimum amount of electricity (in MW) of 0.1 MW; and
- (b) an amount of electricity (in MW) that is a multiple of 0.1 MW.

Clause 13.242: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.242(2): substituted, on 1 June 2012, by clause 4 of the Electricity Industry Participation (Removal of Quantity Limit for Financial Transmission Rights) Code Amendment 2012.

Clause 13.242 heading: amended, on 1 November 2014, by clause 7(a) of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

Clause 13.242(1): amended, on 1 November 2014, by clause 7(b) of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

13.242A

FTR manager to adjust offered FTR and FTR acquisition cost after FTR reconfiguration auction

After each FTR reconfiguration auction, the FTR manager must—
(a) reduce the amount of electricity (in MW) to which each offered FTR relates by the amount of electricity (in MW) to which the relevant reconfigured FTR relates; and
(b) adjust the FTR acquisition cost of the offered FTR by subtracting the FTR reconfiguration amount of the relevant reconfigured FTR from the FTR acquisition cost of the offered FTR.

Clause 13.242A: inserted, on 1 November 2014, by clause 8 of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

13.243 Participation in FTR auction

The FTR manager must not allow a person to participate in an FTR auction unless the FTR manager is satisfied that the person complies with prudential requirements in Part 14A.

Clause 13.243: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.243: amended, on 24 March 2015, by clause 14 of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

13.244 Acceptance of bids and offers in FTR auction

(1) The FTR manager must not accept a bid or an offer in an FTR auction if the FTR manager considers that the bid or the offer, if accepted, would cause the person making the bid or the offer to incur an obligation for which it does not have sufficient acceptable security under Part 14A.
(2) For the purposes of subclause (1), the FTR manager must, based on information received from the clearing manager, determine the maximum liability that each person can incur in respect of its bids or offers in the FTR auction.

Clause 13.244: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.244 heading: amended, on 1 November 2014, by clause 9(a) of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

Clause 13.244(1): amended, on 1 November 2014, by clause 9(b) and (c) of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

Clause 13.244(1): amended, on 24 March 2015, by clause 15 of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.244(2): amended, on 1 November 2014, by clause 9(d) of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

Auction revenue and FTR receipts and payments

Heading: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.245 Clearing manager must collect and allocate auction revenue

The clearing manager must collect the FTR auction revenue and allocate it in accordance with Part 14.

Clause 13.245: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.246 Clearing manager must deal with FTR receipts and payments

The clearing manager must deal with all receipts and payments in respect of FTRs in accordance with Part 14.

Clause 13.246: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

FTR register

Heading: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.247 FTR manager must operate FTR register

(1) The FTR manager must create and operate an FTR register that records—
- (a) the holdings of FTRs; and
- (b) the FTR acquisition cost for each FTR; and
- (c) assignments of FTRs including any price disclosed under clause 13.249; and
- (d) the amount of electricity (in MW) to which each FTR relates; and
- (e) the reconfiguration of each offered FTR.
(2) The FTR register must contain an account for each holder of an FTR.
(3) The FTR manager must assign a registered number to each FTR recorded in the FTR register.
(4) The FTR manager must maintain, publish, and keep published at all times, an up to date copy of the FTR register.

Clause 13.247: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.247(1)(d): inserted, on 1 June 2012, by clause 5 of the Electricity Industry Participation (Removal of Quantity Limit for Financial Transmission Rights) Code Amendment 2012.

Clause 13.247(1)(b): amended, on 1 November 2012, by clause 5 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2012.

Clause 13.247(1)(e): inserted, on 1 November 2014, by clause 10 of the Electricity Industry Participation (FTR Reconfiguration Auctions) Code Amendment 2014.

Clause 13.247(4): replaced, on 5 October 2017, by clause 477 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Assignment of FTRs

Heading: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.248 Assignment of FTRs

(1) If a person ("assignor") wishes to assign an FTR or part of an FTR to another person ("assignee"), the assignor and assignee must complete and sign Form 1 in Schedule 13.6 and provide it to the FTR manager.
(2) The completed form may be provided to the FTR manager under subclause (1) in electronic form if—
- (a) both the assignor and assignee consent to completing and signing the form electronically; and
- (b) the electronic form contains all of the information required by Form 1 in Schedule 13.6; and
- (c) the notification of assignment to the FTR manager is in a format specified by the FTR manager.
(3) The FTR manager must not register an assignment in the FTR register unless the FTR manager is satisfied that the assignee complies with prudential requirements in Part 14A.
(4) The FTR manager, on being satisfied that all requirements for an assignment are met, must register the assignment on the FTR register.
(4A) If an assignment is made under this clause in respect of part of an FTR, the FTR manager must register the assignment as follows:
- (a) create a new record for an FTR in respect of the amount of electricity (in MW) to which the assignment relates; and
- (b) amend the record for the FTR retained by the assignor by reducing the amount of electricity (in MW) to which the FTR relates so as to reflect the assignment.
(5) An assignment of an FTR or part of an FTR is not effective unless it is registered on the FTR register by the FTR manager.
(6) The FTR manager must not register an assignment that is expressed to have effect after the end of the billing period to which the FTR relates.

Clause 13.248: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.248(1): amended, on 1 June 2012, by clause 6(1) of the Electricity Industry Participation (Removal of Quantity Limit for Financial Transmission Rights) Code Amendment 2012.

Clause 13.248(2): amended, on 5 October 2017, by clause 478 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.248(3): amended, on 24 March 2015, by clause 16 of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.248(4A): inserted, on 1 June 2012, by clause 6(2) of the Electricity Industry Participation (Removal of Quantity Limit for Financial Transmission Rights) Code Amendment 2012.

Clause 13.248(5): amended, on 1 June 2012, by clause 6(3) of the Electricity Industry Participation (Removal of Quantity Limit for Financial Transmission Rights) Code Amendment 2012.

13.249 Liability for FTR acquisition cost when FTR assigned and price disclosed

(1) This clause applies if—
- (a) an FTR is assigned under clause 13.248; and
- (b) the notification of assignment discloses the price (being an amount that may be positive or negative) at which the FTR has been assigned.
(2) The FTR manager must provide a copy of the notification of assignment to the clearing manager.
(3) The assignee owes the clearing manager the amount disclosed under subclause (1)(b) when it becomes due on settlement of the FTR.
(4) If the price disclosed in the notification is less than the FTR acquisition cost in respect of the FTR that would, if the assignment had not taken place, become owing on settlement of the FTR, the assignor owes the clearing manager an amount equal to the difference between the FTR acquisition cost and the price at which the FTR has been assigned.
(5) The clearing manager must advise the assignor of the amount owing under subclause (4) when the clearing manager advises amounts owing under subpart 4 of Part 14 for the billing period in which the assignment took place.
(6) The clearing manager must apply any amount owing by a participant to the clearing manager under this clause to the settlement of FTRs, but an amount must not be applied to the settlement of an FTR until the billing period in which the FTR is settled.
(7) If the price disclosed in the notification is more than the FTR acquisition cost in respect of the FTR that would, if the assignment had not taken place, become owing on settlement of the FTR, the clearing manager owes the assignor on settlement of the FTR an amount equal to the difference between the price at which the FTR has been assigned and the FTR acquisition cost.

Clause 13.249: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.249 Heading: amended, on 1 November 2012, by clause 6(1) of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2012.

Clause 13.249(1)(b): amended, on 1 November 2012, by clause 6(2) of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2012.

Clause 13.249(3): amended, on 24 March 2015, by clause 17(a) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.249(4): amended, on 1 November 2012, by clause 6(3) of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2012.

Clause 13.249(4): amended, on 24 March 2015, by clause 17(b) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.249(5): amended, on 24 March 2015, by clause 17(c) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.249(6): substituted, on 24 March 2015, by clause 17(d) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.249(7): amended, on 1 November 2012, by clause 6(4) of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2012.

Clause 13.249(7): amended, on 24 March 2015, by clause 17(e) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

13.250 Liability for FTR acquisition cost when FTR assigned and price not disclosed

(1) This clause applies if—
- (a) an FTR is assigned under clause 13.248; and
- (b) the notification of assignment does not disclose the price at which the FTR has been assigned.
(2) The FTR manager must provide a copy of the notification of assignment to the clearing manager.
(3) The assignee owes the clearing manager the FTR acquisition cost in respect of the FTR that has been assigned when it becomes due on settlement of the FTR.

Clause 13.250: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.250 Heading: amended, on 1 November 2012, by clause 7(1) of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2012.

Clause 13.250(3): amended, on 1 November 2012, by clause 7(2) of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2012.

Clause 13.250(3): amended, on 24 March 2015, by clause 18 of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Provision of information to the FTR manager and clearing manager

Heading: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.251 Information to be provided to FTR manager

(1) Each grid owner must provide a written forecast of the configuration and capacity of the grid owner's grid for the FTR period (as advised to each grid owner by the FTR manager) to the FTR manager for use in determining the FTRs to be offered in each FTR auction.
(2) The information that each grid owner must provide must include relevant planned outages.
(3) Except as otherwise agreed with the FTR manager, each grid owner must provide the information to the FTR manager no later than 1 month before the date (as advised to each grid owner by the FTR manager) on which an FTR auction is to be held.
(4) The clearing manager must advise the FTR manager in writing—
- (a) whether a person who has applied to participate in an FTR auction complies with prudential requirements in Part 14A; and
- (b) the amount of security that a person who has applied to participate in an FTR auction has provided that exceeds that person's other obligations under Parts 14 and 14A.
(5) Except as otherwise agreed with the FTR manager, the clearing manager must provide the information to the FTR manager no later than 2 business days before the date (as advised to the clearing manager by the FTR manager) on which an FTR auction is to be held.
(6) If the information referred to in subclause (4) changes, the clearing manager must, if requested by the person who has applied to participate in an FTR auction, provide the updated information in writing to the FTR manager.
(7) The clearing manager must inform the FTR manager in writing, as soon as practicable after receiving a request from the FTR manager, whether an assignee of an FTR meets the prudential security requirements in Part 14A.

Clause 13.251: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.251(1), (4), (6) and (7): amended, on 5 October 2017, by clause 479 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 13.251(4): amended, on 24 March 2015, by clause 19(a) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

Clause 13.251(7): amended, on 24 March 2015, by clause 19(b) of the Electricity Industry Participation (Settlement and Prudential Security) Code Amendment 2013.

13.252 Information to be provided to clearing manager

(1) The FTR manager must provide the following information to the clearing manager in writing in relation to each successful bidder in an FTR auction:
- (a) the details of each FTR allocated under an FTR auction, including—
  - (i) the period to which the FTR applies; and
  - (ii) whether the FTR is an option FTR or an obligation FTR; and
  - (iii) the formula under which the FTR hedge value is to be calculated for the settlement of the FTR:
- (b) the FTR acquisition cost in respect of each FTR.
(2) The FTR manager must provide the information specified in subclause (1) to the clearing manager as soon as practicable and no later than 1 week after each FTR auction.

Clause 13.252: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.252(1): amended, on 1 November 2012, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2012.

Clause 13.252(1): amended, on 5 October 2017, by clause 480 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.253 [Revoked]

Clause 13.253: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.253: revoked, on 5 October 2017, by clause 481 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

13.254 Publication of results of FTR auctions

The FTR manager must, as soon as practicable after each FTR auction, publish and keep published the results of each FTR auction in accordance with the FTR allocation plan.

Clause 13.254: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.254: amended, on 5 October 2017, by clause 482 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Suspension of FTR allocation

Heading: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

13.255 Authority may direct FTR manager to suspend allocation of FTRs

The Authority may direct the FTR manager to suspend the allocation of FTRs if there is any situation that—
- (a) threatens, or may threaten, confidence in, or the integrity of, the allocation or settlement of FTRs; and
- (b) in the reasonable opinion of the Authority, cannot satisfactorily be resolved by any other mechanism available under this Code.

Clause 13.255: inserted, on 1 October 2011, by clause 8 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Clause 13.255: amended, on 18 July 2013, by clause 9(1) of the Electricity Industry Participation (Undesirable Trading Situation) Code Amendment 2013.

Clause 13.255(a): substituted, on 18 July 2013, by clause 9(2) of the Electricity Industry Participation (Undesirable Trading Situation) Code Amendment 2013.

Clause 13.255(b): amended, on 18 July 2013, by clause 9(3) of the Electricity Industry Participation (Undesirable Trading Situation) Code Amendment 2013.

Provision of internal transfer pricing information by generator retailers

Heading: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.256 Generator retailers must provide ITP information to the Authority

(1) Each generator retailer must provide the ITP information in relation to the generator retailer to the Authority in the form and by the means specified by the Authority no later than 90 days after the end of the financial year of the generator retailer.
(2) The ITP information must consist of the following information in relation to the generator retailer’s financial year:
- (a) the average load weighted retail ITP, calculated by dividing the total notional cost of electricity under the retail ITP arrangements of the generator retailer by the total amount of electricity in MWh sold by the generator retailer to mass market customers:
- (b) information on how the generator retailer determined the retail ITP, at a sufficient level of detail to enable a reasonable person, being a person who has a reasonably sophisticated understanding of the operation of the electricity industry and the wholesale market, to determine how the generator retailer determined the retail ITP.
(3) The information provided by a generator retailer under subclause (2)(b) must include the following:
- (a) a breakdown of the key components or factors which make up the retail ITP expressed as an amount in dollars and cents per MWh that each key component or factor comprises of the average load weighted retail ITP required by subclause (2)(a), and which must include (if relevant) the following components or factors:
  - (i) prices in ASX NZ electricity futures:
  - (ii) the distribution of the total electrical load across locations, including the adjustment, calculated on an average load weighted basis in MWh, that the retailer generator used to determine the retail ITP for the electricity sold to mass market customers beyond a node specified in an ASX NZ electricity future:
  - (iii) administrative fees, including management fees, notionally charged by the generator retailer to the generator retailer’s retail arm:
  - (iv) the level of discretionary judgement the generator retailer exercised to amend or otherwise modify the draft retail ITP before it was finalised:
  - (v) all other key components or factors the generator retailer relied on to determine the retail ITP, and any other material information used by the generator retailer to determine the retail ITP that is not publicly available:
- (b) any residual components or factors that make up the retail ITP, but which are not components or factors required by paragraph (a), expressed as one combined amount in dollars and cents per MWh:
- (c) an explanation of the methodology the generator retailer used to determine or to assist in determining the retail ITP, and which must include (if relevant) the following:
  - (i) the assumed process used by the generator retailer to build the hedge book of ASX NZ electricity futures, including the following:
    - (A) the proportion of ASX NZ electricity futures the generator retailer assumed would be purchased and the assumed timing of those assumed purchases:
    - (B) the relative weighting of ASX NZ electricity futures relating to Benmore as compared to those relating to Otahuhu:
    - (C) the types of ASX NZ electricity futures the generator retailer assumed to be purchased and the maturities purchased:
    - (D) the basis on which the ASX NZ electricity futures are priced:
  - (ii) the approach the generator retailer took to adjust for:
    - (A) differences in the within day electrical load and cost profile underlying the ASX NZ electricity futures and the generator retailer’s mass market customers load profile:
    - (B) distribution of electrical load across locations, including the relative use of FTRs or historical price differences to price for load by location:
  - (iii) the approach or methodology used to determine the electrical load profile, including the following:
    - (A) whether actual or assumed load profiles are relied upon:
    - (B) the degree of granularity of load with respect to location, seasonality and intra-day:
    - (C) the percentage of load by regional geographical location:
  - (iv) the basis for and determination of fees, including management or associated fees, the generator retailer notionally charged its retail arm:
  - (v) the basis for and rationale behind any discretion the generator retailer exercised:
  - (vi) any other details the generator retailer considers material to explain the methodology the generator retailer used to determine or assist in determining the retail ITP:
- (d) the key non-price parameters the generator retailer used to determine the retail ITP including whether or not the retail ITP is:
  - (i) for fixed or variable volume of electricity; or
  - (ii) for a fixed or variable price of electricity:
- (e) the purposes for which the retail ITP is used by the generator retailer, including whether the retail ITP is used as part of setting the price of electricity sold to mass market customers by the generator retailer:
- (f) if relevant, and if not disclosed under paragraph (e), any matters relating to the generator retailer which the retail ITP directly or indirectly affects.
(4) Where a generator retailer and one or more other generator retailers are related companies, as defined in section 2 of the Companies Act 1993, and are required by subclause (1) to provide ITP information to the Authority, the obligation in subclause (1) is met by one of those generator retailers providing the ITP information relating to all the generator retailers on a consolidated basis for the generator retailers to the Authority.
(5) If a generator retailer provides ITP information on behalf of other generator retailers under subclause (4), the generator retailer providing the ITP information must identify the other generator retailers as part of the ITP information provided.

Clause 13.256: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.257 Disclosure of change of methodology

(1) This clause applies if—
- (a) a generator retailer changes the methodology used to determine the retail ITP for a financial year (“the current financial year”) from the methodology used in a previous financial year for which the generator retailer provided ITP information under clause 13.256, other than where that change relates solely to the distribution of the customer load base or the input prices (ASX NZ electricity futures prices and locational prices as provided for in clause 13.256(3)(a)(i) and (ii)); and
- (b) that change in methodology has the effect of modifying the retail ITP by an amount in excess of 5% from the retail ITP contained in the most recent ITP information the generator retailer provided under clause 13.256.
(2) Where this clause applies, the generator retailer must also provide the following information to the Authority in the form and by the means specified by the Authority:
- (a) details of the impact on the average load weighted retail ITP disclosed under clause 13.256 for any of the previous three financial years if the new methodology had been used to determine the generator retailer’s retail ITP for those previous financial years:
- (b) details of the impact on the average load weighted retail ITP for the current financial year if the methodology used in any of those previous financial years was used to determine the generator retailer’s retail ITP for the current financial year.
(3) The generator retailer must provide the information required by subclause (2) to the Authority at the same time as providing the ITP information required under clause 13.256 for the current financial year.
(4) Where a generator retailer and one or more other generator retailers are related companies, as defined in section 2 of the Companies Act 1993, and are required by subclause (2) to provide information to the Authority, the obligations in subclause (2) are met by one of those generator retailers providing the information relating to all the generator retailers on a consolidated basis for all the generator retailers to the Authority.
(5) If a participant provides information on behalf of other generator retailers under subclause (4), the generator retailer providing the information must identify the other generator retailers as part of the information provided.

Clause 13.257: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.258 Publication of ITP information by the Authority

The Authority may publish any ITP information or information submitted to it under clause 13.257, as the Authority sees fit.

Clause 13.258: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

Provision of retail gross margin reports by retailers

Heading: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.259 Provision of retail gross margin report by retailers

(1) Each retailer must provide a retail gross margin report to the Authority no later than 90 days after the end of the retailer’s financial year.
(2) Subclause (1) does not apply to any retailer who was recorded in the registry in any of the preceding 12 months as being responsible for less than 1% of the total number of ICPs registered in the registry with an ICP status of “Active”.
(3) The retail gross margin report must consist of the following information relating to the sale of electricity to mass market customers for the financial year by the retailer:
- (a) the total amount of electricity sold by the retailer to mass market customers expressed as MWhs:
- (b) revenue derived from the sale of electricity to mass market customers expressed as an amount of dollars per MWh:
- (c) cost of electricity sold by the retailer to mass market customers, including the cost of electricity derived from retail ITP, expressed as an amount of dollars per MWh:
- (d) cost of metering services associated with the sale of electricity to mass market customers expressed as an amount per MWh:
- (e) cost of distribution services associated with the sale of electricity to mass market customers expressed as an amount per MWh:
- (f) cost of transmission services, being those services provided by Transpower under a transmission agreement, paid by the retailer associated with the supply of electricity to mass market customers by the retailer expressed as an amount per MWh:
- (g) cost of levies associated with the supply of electricity to mass market customers by the retailer expressed as an amount per MWh.
(4) A retail gross margin report must be prepared in accordance with generally accepted accounting practices and in the form specified by the Authority.
(5) Where a retailer and one or more other retailers are related companies, as defined in section 2 of the Companies Act 1993, and are required by subclause (1) to provide a retail gross margin report to the Authority—
- (a) the obligation in subclause (1) is met by one of those retailers providing the retail gross margin report relating to all the retailers on a consolidated basis for all the retailers to the Authority; and
- (b) in any such case, the retailer providing the information must identify the other retailers, as part of the information provided.

Clause 13.259: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.260 Publication of information contained in retail gross margin reports by the Authority

The Authority may publish the information received in a retail gross margin report, except that information contained in a retail gross margin report submitted by a retailer with less than 5% of total market share by ICP with a status of “Active” must be anonymised so as not to identify that retailer.

Clause 13.260: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

Authority may require review of ITP information and retail gross margin reports

Heading: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.261 Authority may require review of ITP information and retail gross margin reports by independent person

The Authority may, in its discretion, require a review by an independent person of whether—
- (a) a generator retailer may not have complied with one or both of clauses 13.256 or 13.257; and
- (b) a retailer may not have complied with clause 13.259.

Clause 13.261: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.262 Nomination of independent person to undertake review

(1) If the Authority requires a review under clause 13.261—
- (a) the Authority must require the generator retailer or retailer to nominate an appropriate independent person to undertake the review; and
- (b) the generator retailer or retailer must provide that nomination within a reasonable timeframe.
(2) The Authority may direct the generator retailer or retailer to appoint the person nominated under subclause (1) or to nominate another person for approval.
(3) If the generator retailer or retailer fails to nominate an appropriate person under subclause (1) within 5 business days, the Authority may direct the generator retailer or retailer to appoint a person of the Authority’s choice.
(4) The generator retailer or retailer must appoint a person to undertake the review in accordance with a direction made under subclause (2) or subclause (3).

Clause 13.262: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.263 Factors relevant to a direction under clause 13.262

(1) In making the direction required by clause 13.262(2) or clause 13.262(3), the Authority may have regard to any factors it considers relevant in the circumstances, including the following:
- (a) the degree of independence between the generator retailer or retailer and the person nominated under clause 13.262(1); and
- (b) the expected quality of the review; and
- (c) the expected costs of the review.
(2) For the purposes of subclause (1)(a), the Authority may have regard to the special definition of independent under clause 1.4 but it is not bound by that definition.

Clause 13.263: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.264 Carrying out of review by independent person

(1) A generator retailer or retailer subject to a review under clause 13.261 must, on request from the person undertaking the review, provide that person with such information as the person reasonably requires in order to carry out the review.
(2) The generator retailer or retailer must provide the information no later than 10 business days after receiving a request from the person for the information.
(3) The generator retailer or retailer must ensure that the person undertaking the review—
- (a) produces a report on whether, in the opinion of that person, the generator retailer or retailer may not have complied with clauses 13.256, 13.257 or 13.259 (as specified by the Authority under clause 13.261); and
- (b) submits the report to the Authority within the timeframe specified by the Authority.
(4) The report produced under subclause (3)(a) must include any other information that the Authority may reasonably require.
(5) Before the report is submitted to the Authority, any identified failure of the generator retailer or retailer to comply with clauses 13.256, 13.257 or 13.259 must be referred back to the generator retailer or retailer for comment.
(6) The comments of the generator retailer or retailer must be included in the report.

Clause 13.264: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.265 Payment of review costs

(1) If a report received under clause 13.264(3)(a) establishes, to the Authority’s reasonable satisfaction, that the generator retailer or retailer may not have complied with clauses 13.256, 13.257 or 13.259 (whether or not the Authority appoints an investigator to investigate the alleged breach), the generator retailer or retailer must pay the costs of the person who undertook the review.
(2) Despite subclause (1), if a report establishes, to the Authority’s reasonable satisfaction that any non-compliance of the generator retailer or retailer is minor or there is any other reason in the Authority’s view that means the generator retailer or retailer should not pay the costs of the person who undertook the review, the Authority may, in its discretion, determine the proportion of the person’s costs that the generator retailer or retailer must pay, and the generator retailer or retailer must pay those costs.
(3) If a report establishes to the Authority’s reasonable satisfaction that the generator retailer or retailer has complied with clauses 13.256, 13.257 and 13.259 (if relevant), the Authority must pay the person’s costs.

Clause 13.265: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

13.266 Requirement to provide complete and accurate information

(1) In addition to the requirements of clause 13.2, the generator retailer or retailer must take all practicable steps to ensure that the information that the generator retailer or retailer is required to provide to any person under clauses 13.256, 13.257 or 13.259 is complete and correct.
(2) If a generator retailer or retailer becomes aware that any information the generator retailer or retailer provided under clauses 13.256, 13.257 or 13.259 does not comply with subclause (1) or clause 13.2, even if the generator retailer or retailer has taken all practicable steps to ensure that the information complies, the generator retailer or retailer must, as soon as practicable, provide such further information as is necessary to ensure that the information provided complies with clauses 13.256, 13.257, 13.259 or clause 13.2 (as relevant).

Clause 13.266: inserted, on 30 November 2021, by clause 5 of the Electricity Industry Participation Code Amendment (Internal Transfer Prices and Segmented Profitability Reporting) 2021.

Subpart 7—Restrictions on materially large contracts

Heading: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Heading: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Heading: inserted, on 19 May 2023, by clause (2)(1) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

13.267 Contents of this subpart

This subpart provides for—
(a) restrictions on giving effect to materially large contracts; and
(b) information disclosure requirements to support compliance with this subpart; and
(c) a clearance regime for materially large contracts.

Clause 13.267: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.267: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.267: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.268 Definition of materially large contract

(1) A materially large contract is—
- (a) a contract that—
  - (i) is not entered into through a derivatives exchange; and
  - (ii) includes terms under which the buyer itself will consume electricity; and
  - (iii) relates to a net quantity of electricity that equals or exceeds 150 MW consumed at a point in time; or
- (b) two or more contracts where:
  - (i) all the contracts satisfy paragraph (a)(i); and
  - (ii) at least one contract satisfies paragraph (a)(ii); and
  - (iii) the contracts when taken together satisfy paragraph (a)(iii) and meet one of the descriptions set out in paragraph (c) below:
- (c) the descriptions referred to at paragraph (b)(iii) above are:
  - (i) two or more contracts between a generator and a buyer; or
  - (ii) at least one contract between a generator and a buyer and at least one contract between that generator or its related company and that buyer or its related company; or
  - (iii) at least one contract between a generator and a buyer and at least one contract involving a second generator and the same buyer where the contracts rely on each other or are otherwise interdependent; or
  - (iv) at least one contract between a generator and a buyer and at least one contract between the same generator and a second generator where the contracts rely on each other or are otherwise interdependent; or
  - (v) any other arrangement that is substantially of the same kind as that described in any of subparagraphs (i)-(iv).
(2) For materially large contracts made up of two or more different generators’ contracts, any reference to materially large contract in the following clauses must be read as only referring to an individual generator’s contract(s) that forms part of a materially large contract, rather than as a reference to the multiple generators’ contracts.
(3) Where a materially large contract allows for the possibility of varying quantities of electricity consumption at any one time, the maximum quantity of electricity consumption possible under the contract at any one time is to be used for the purpose of determining whether the MW threshold in subclause (1)(a)(iii) is met.
(4) For the purpose of subclause (1)(a)(iii), the net quantity of electricity is the total MW consumed at a point in time (calculated in accordance with subclause (3)) less any MW generated from new generation, where the materially large contract is material to the generator’s decision to invest in the new generation.
(5) For the purpose of this subpart, related company has the meaning set out in section 2(3) of the Companies Act 1993.

Clause 13.268: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.268: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.268: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.269 Restriction on materially large contracts

(1) A generator must not give effect to a materially large contract unless—
- (a) the net value of the materially large contract to the generator calculated in accordance with clause 13.270 is a positive value; or
- (b) the materially large contract allows the buyer to on-sell all unused MW quantities under the materially large contract without the buyer being subject to any worse terms than if it had consumed the relevant quantity itself; or
- (c) the Authority has provided a clearance under clause 13.273 in respect of the materially large contract and that clearance remains effective and applicable.
(2) Nothing in this clause prevents a generator entering into a materially large contract that provides that it is conditional on the Authority providing a clearance under clause 13.273.
(3) This clause only applies to materially large contracts entered into, extended or modified on or after the date this clause came into force.

Clause 13.269: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.269: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.269: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.270 Calculation of net value of the materially large contract to the generator

(1) The net value of the materially large contract to the generator is the value of the contract to the generator less the value of the generator’s best alternative.
(2) The calculation of the value of the generator’s best alternative must take into account the generator’s reasonable expectations as to whether in the absence of the materially large contract the buyer would have exited completely, reduced consumption, not expanded, or not entered the domestic market.
(3) The calculation of the value of the contract to the generator and the calculation of the value of the generator’s best alternative must take into account any direct value components that are reasonably relevant to the calculation, which may include (without limitation)—
- (a) contract price:
- (b) prices for baseload futures contracts over the period covered by the materially large contract and, where a materially large contract covers a period in time not yet covered by base load futures contracts, the generator’s reasonable expectations as to base forward prices over this period, which may include consideration of the long run marginal cost of electricity, the levelised cost of electricity and other factors:
- (c) node location:
- (d) load profile differing from base load:
- (e) demand response provisions:
- (f) price separation provisions:
- (g) contract price pegged to an index provision:
- (h) value of maintaining an uninterrupted commercial relationship with the buyer:
- (i) relative counterparty risk:
- (j) any other financial inducements or benefits associated with the materially large contract.
(4) For the avoidance of doubt, indirect effects of the materially large contract on the generator’s wider portfolio (for example, revenues from other customers) must not be taken into account when calculating the value of the contract to the generator and the value of the generator’s best alternative.
(5) Each value component used under subclause (3) must be assigned a monetary value that reasonably equates to its value to the generator.
(6) Each assigned monetary value for a value component must be aggregated to derive the value of the contract to the generator and the value of the generator’s best alternative (as applicable).
(7) The relevant point in time at which the generator’s reasonable expectations at subclause (2) and any assumptions relied on under subclause (3) are to be assessed is the duration of the 30 business days immediately preceding the generator (as applicable)—
- (a) entering into the materially large contract; or
- (b) seeking a clearance from the Authority for the materially large contract.

Clause 13.270: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.270: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.270: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.271 Disclosure of materially large contracts

(1) Except where clause 13.276 applies, a generator must provide the information specified in this clause to the Authority in the form and by the means specified by the Authority no later than 5 business days after—
- (a) entering into a materially large contract:
- (b) changing a materially large contract’s price, volume, term or on-selling arrangements or any other provision of a materially large contract that may affect the calculation of the net value of the materially large contract to the generator if the generator is relying on clause 13.269(1)(a) to give effect to the materially large contract:
- (c) changing a materially large contract’s on-selling arrangements if the generator is relying on clause 13.269(1)(b) to give effect to the materially large contract:
- (d) a change to the volume or timing of any new generation taken into account in reliance on clause 13.268(4) where:
  - (i) the quantity of electricity generated from new generation has decreased; and
  - (ii) the net quantity of electricity for any contract exceeds the threshold in clause 13.268(1)(a)(iii).
(2) The information to be provided must consist of the following in relation to the materially large contract:
- (a) a copy of the materially large contract signed by the parties; and
- (b) a statement of the generator’s reasons as to how the materially large contract satisfies either clause 13.269(1)(a) or clause 13.269(1)(b); and
- (c) evidence to support the generator’s reasons at paragraph (b).
(3) Where a generator seeks to rely on clause 13.269(1)(a), the evidence under subclause (2)(c) must include—
- (a) the generator’s calculation of the net value of the materially large contract to the generator in accordance with clause 13.270, including—
  - (i) the generator’s calculation of the value of the contract to the generator and the generator’s best alternative in accordance with clause 13.270; and
  - (ii) the value component(s) taken into account by the generator when calculating the value of the contract to the generator; and
  - (iii) the value component(s) taken into account by the generator when calculating the value of the generator’s best alternative; and
  - (iv) the monetary value assigned to any value component taken into account by the generator; and
  - (v) a justification for the monetary value assigned to any value component, including any assumptions relied on and (if available) evidence to show whether those assumptions are consistent with similar assumptions being made elsewhere in the generator’s business in the 60 business days immediately preceding the date the generator entered into the materially large contract; and
  - (vi) the generator’s reasonable expectations taken into account under clause 13.270(2) and an explanation of the basis for these expectations and (if available) evidence to support those expectations; and
- (b) all other information and documents that are in the possession, or under the control, of the generator and that are material to an assessment of a generator’s compliance with clause 13.269(1)(a).
(4) Where a generator seeks to rely on clause 13.269(1)(b), the evidence under subclause (2)(c) must include—
- (a) a statement of the buyer’s rights to on-sell any unused MW quantities under the materially large contract and an explanation of the terms on which it can do so; and
- (b) all other information and documents that are in the possession, or under the control, of the generator and that are material to an assessment of a generator’s compliance with clause 13.269(1)(b).

Clause 13.271: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.271: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.271: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.272 Application to the Authority for clearance of a materially large contract

(1) A generator may submit an application to the Authority for clearance of a materially large contract that—
- (a) is expressed as conditional on the Authority providing a clearance under this subpart; or
- (b) has not yet been signed by the parties.
(2) Where a generator has not provided the information specified at clause 13.271 in respect of the materially large contract the application must include all information specified in clause 13.271 that would otherwise be required to be provided by the generator after entering the materially large contract.
(3) The application must be submitted in the form and by the means specified by the Authority.

Clause 13.272: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.272: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.272: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.273 Authority may provide clearance for a materially large contract

(1) Where the Authority receives an application that complies with clause 13.272 the Authority shall either—
- (a) provide a clearance by notice in writing in respect of the materially large contract if it is satisfied that either clause 13.269(1)(a) or 13.269(1)(b) is met, in which case the Authority must specify which clause it is satisfied in respect of; or
- (b) decline by notice in writing to provide a clearance in respect of the materially large contract if it is not satisfied that either clause 13.269(1)(a) or 13.269(1)(b) is met, in which case the Authority must give the generator reasons for its decision.
(2) The Authority may use the information provided to it in the application and any other information the Authority considers relevant for the purposes of its decision, including any further information the Authority requests from the generator.
(3) The Authority must make a decision on the application and notify the generator of the outcome of its application no later than 45 business days after the date on which the generator has provided the Authority with all required information (including any further information requested by the Authority for the purpose of making its decision), or such longer period as the Authority and the generator agree.
(4) If the period specified in subclause (3) expires without the Authority having provided a clearance for the materially large contract and without having given a notice under subclause (1)(b), the Authority shall be deemed to have declined to give a clearance.
(5) The Authority may publish the outcome of the application.
(6) A clearance provided by the Authority under this clause does not apply to a materially large contract if—
- (a) any changes are made to the price, volume, term, on-selling arrangements or any other provision of the materially large contract that may affect the calculation of the net value of the materially large contract to the generator and the Authority provided its clearance on the basis of clause 13.269(1)(a); or
- (b) any changes are made to the materially large contract’s on-selling arrangements and the Authority provided its clearance on the basis of clause 13.269(1)(b); or
- (c) there has been a change to the volume or timing of any new generation taken into account in reliance on clause 13.268(4) where:
  - (i) the quantity of electricity generated from new generation has decreased; and
  - (ii) the net quantity of electricity for any contract exceeds the threshold in clause 13.268(1)(a)(iii).
(7) Where the Authority provides a clearance in respect of a materially large contract not yet signed by the parties, the clearance will expire and be of no effect if the contract is not signed by the parties within 20 business days of the Authority providing the clearance.
(8) The Authority may revoke a clearance if it was based on information provided by the generator that was false or misleading in a material particular.

Clause 13.273: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.273: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.273: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.273(1)(a) and (2): amended, on 1 March 2024, by clause 86(1) and (2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.274 Reconsideration by Authority of clearance decision

(1) Where the Authority declines to provide a clearance, the Authority may, at its discretion, reconsider its decision if—
- (a) the generator provides further information or reasons (which may include making changes to the materially large contract) to the Authority in support of its position no later than 10 business days after notification of the Authority’s decision under clause 13.273; and
- (b) the Authority considers that the further information or reasons may alter or affect the Authority’s decision under clause 13.273.
(2) The Authority must make any decisions under this clause within such timeframes as it reasonably considers appropriate.

Clause 13.274: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.274: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.274: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.275 Right of appeal against clearance decision

(1) A party to a materially large contract may appeal to the Rulings Panel a decision by the Authority under clause 13.273 not to provide a clearance in respect of the materially large contract.
(2) Despite subclause (1) a party to a materially large contract may not appeal to the Rulings Panel where the reason for the decision not to provide clearance relates to a failure by the generator to provide required information.
(3) The appeal must be made to the Rulings Panel no later than 20 business days after the Authority notifies the generator of its decision under clause 13.273.
(4) The Rulings Panel, in determining an appeal, must either approve the decision of the Authority or direct the Authority to reconsider the decision in full or by reference to specified matters.

Clause 13.275: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.275: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.275: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.276 Disclosure of cleared materially large contract

(1) This clause applies to a materially large contract that has been provided with a clearance under clause 13.273 provided the clearance remains effective and applicable.
(2) Where this clause applies, a generator must provide to the Authority a copy of the materially large contract signed by the parties in the form and by the means specified by the Authority no later than 5 business days after entering into the materially large contract.

Clause 13.276: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.276: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.276: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.277 Requirement to provide complete and accurate information

(1) In addition to the requirements of clause 13.2, the generator must take all practicable steps to ensure that the information that the generator is required to provide under this subpart is complete and accurate as at the date it is required to be provided under this subpart.
(2) If the generator later becomes aware that any information provided under this subpart was not complete or accurate as at the date it was required to be provided under this subpart, it must as soon as practicable provide to the Authority such further information as is necessary to make the information complete or accurate as at the date it was required to be provided under this subpart.

Clause 13.277: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.277: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.277: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.278 Authority must keep information confidential

The Authority must keep all information provided to it under this subpart confidential except to the extent that disclosure is required to enable the Authority to carry out its obligations and duties under the Electricity Industry Act 2010, the Code or the Electricity Industry (Enforcement) Regulations or is otherwise required by law.

Clause 13.278: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.278: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.278: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.279 Appointment of auditor

(1) The Authority may, in its discretion, carry out an audit as to whether a generator has complied with this subpart.
(2) If the Authority decides under subclause (1) that a generator should be subject to an audit—
- (a) the Authority must require the generator to nominate an appropriate auditor; and
- (b) the generator must provide that nomination to the Authority within a reasonable timeframe.
(3) The Authority may appoint the auditor nominated by the generator or a different auditor, having regard to any factors it considers relevant in the circumstances, including—
- (a) the expected quality of the audit:
- (b) the expected costs of the audit.
(4) If the generator fails to nominate an appropriate auditor within 20 business days, the Authority may appoint an auditor of its own choice.

Clause 13.279: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.279: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.279: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.280 Carrying out of audit

(1) A generator subject to an audit under clause 13.279 must, on request from the auditor, provide the auditor with such information as the auditor reasonably requires in order to carry out the audit.
(2) The generator must provide the information no later than 20 business days after receiving a request from the auditor for the information.
(3) The generator must ensure that the auditor provides the Authority with an audit report on the generator’s compliance with this subpart within the timeframe specified by the Authority.
(4) The audit report must include any other information the Authority may reasonably require.
(5) Before the audit report is provided to the Authority, any identified failure of the generator to comply with this subpart must be referred back to the generator for comment.
(6) The comments of the generator must be included in the audit report.
(7) The audit report must not contain any contract that the generator has provided to the auditor unless the contract meets the definition of a materially large contract.

Clause 13.280: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.280: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.280: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

13.281 Payment of costs relating to audits

(1) If an audit establishes, to the reasonable satisfaction of the Authority, that a generator may not have complied with this subpart (whether or not the Authority appoints an investigator to investigate the alleged breach), the generator must pay for the audit.
(2) If the Authority considers that the non-compliance of the generator is minor or there is any other reason in the Authority’s view that means the generator should not pay the costs of the audit, the Authority may, in its discretion, determine the proportion of the costs of the audit that are to be paid by the generator, and those costs must be paid by the generator with any remaining proportion of costs paid by the Authority.
(3) If an audit establishes to the reasonable satisfaction of the Authority that the generator has complied with this subpart, the generator is not required to pay any of the auditor’s costs and the Authority will pay the auditor’s costs.

Clause 13.281: inserted, on 19 August 2022, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2022.

Clause 13.281: revoked, on 18 May 2023, by clause 2(2) of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.281: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Clause 13.281(2): amended, on 1 March 2024, by clause 87 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

13.282 Transitional arrangements

(1) Where:
- (a) an application has been made to the Authority for clearance of a materially large contract pursuant to clause 13.272 prior to 19 May 2023; and
- (b) as at 19 May 2023:
  - (i) the Authority has not yet made a decision on the application and notified the generator of the outcome; and
  - (ii) the period specified in clause 13.272(3) has either:
    - (A) not yet expired; or
    - (B) has been extended by agreement between the Authority and the generator;
  - then, the Authority shall make a decision on the application as if this subpart, as it existed on 18 May 2023, continued in force.
(2) Once the Authority has made a decision on an application to which subclause (1) applies, the matters and arrangements which were subject of the application shall be dealt with in accordance with this subpart.
(3) Where:
- (a) an application has been made to the Authority for clearance of a materially large contract pursuant to clause 13.272 prior to 19 May 2023; and
- (b) the Authority has, pursuant to clause 13.273(1)(a), provided a clearance by notice in writing prior to 19 May 2023;
  - then, the materially large contract and the matters and arrangements which were subject of the application, shall be dealt with in accordance with this subpart.

Clause 13.282: inserted, on 19 May 2023, by clause 5 of the Electricity Industry Participation Code Amendment (Restrictions on Materially Large Contracts) 2023.

Schedule 13.1

cls 13.9, 13.13, 13.38 and 13.64

Forms 1 to 9

Heading: amended, on 1 November 2022, by clause 153 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Schedule 13.1.pdf

1 July 2025 11 pages

View pdf

Schedule 13.1.html

1 July 2025

View html

Schedule 13.2

cls 13.58AA and 13.189

Model parameters

Heading: amended, on 1 November 2022, by clause 158 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

1 Model parameters

The system operator must, in accordance with clause 13.189 of the Code, provide the Authority with a list specifying the values for the following model parameters:
- (a) deficit bus generation:
- (b) surplus bus generation:
- (c) deficit 6s reserve for a contingent event as defined in clause 12.3 of the Policy Statement:
- (d) deficit 6s reserve for an extended contingent event as defined in clause 12.3 of the Policy Statement:
- (e) deficit 60s reserve for a contingent event as defined in clause 12.3 of the Policy Statement:
- (f) deficit 60s reserve for an extended contingent event as defined in clause 12.3 of the Policy Statement:
- (g) deficit branch group constrained:
- (h) surplus branch group constrained:
- (i) deficit bus group constrained:
- (j) surplus bus group constrained:
- (k) deficit ramp rate:
- (l) surplus ramp rate:
- (m) market node/trader capacity deficit:
- (n) deficit branch flow:
- (o) surplus branch flow:
- (p) deficit M-node constrained:
- (q) surplus M-node constrained.

Compare: Electricity Governance Rules 2003 schedule G2 part G

Schedule 13.2, Clause 1: amended, on 1 November 2022, by clause 159 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Schedule 13.3

cls 13.29, 13.33, 13.57, 13.58, 13.58AA, 13.58A, 13.69A, 13.69AA, 13.193, and 13.203

The Modelling System

Heading: amended, on 28 June 2012, by clause 53 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Heading: substituted, on 15 May 2014, by clause 54(1) of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Heading: amended, on 1 November 2022, by clause 160 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Inputs into the modelling system

1 Purpose of modelling system

(1) The purpose of the modelling system is to provide schedules of quantities and prices that maximise the gross purchaser benefit from purchases of electricity from the clearing manager less the total cost of production of electricity and instantaneous reserves as specified in this Schedule.
(2) [Revoked]
(2A) A price-responsive schedule and non-response schedule must use the scheduled generation at the end of the previous trading period as the expected output for the purpose of clause 9A(b).
(3) The modelling system must provide prices for electricity and instantaneous reserve that are consistent with the above purpose and the scheduled quantities of electricity and instantaneous reserve.
(4) The modelling system must be used, using different inputs, to produce—
- (a) price-responsive schedules; and
- (b) non-response schedules; and
- (c) dispatch schedules
- (d) [Revoked]
- (e) [Revoked]
- (f) [Revoked]
- (g) [Revoked]

Compare: Electricity Governance Rules 2003 clause 1.1 schedule G6 part G

Clause 1 Heading: amended, on 15 May 2014, by clause 54(2) of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clause 1(1): amended, on 28 June 2012, by clause 54(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 1(1): amended, on 21 September 2012, by clause 32(1) of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 1(2): substituted, on 15 May 2014, by clause 69 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 1(2): revoked, on 1 November 2022, by clause 161(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 1(2A): inserted, on 15 May 2014, by clause 69 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 1(2A): amended, on 1 November 2022, by clause 161(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 1(3): amended, on 28 June 2012, by clause 54(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 1(4): substituted, on 28 June 2012, by clause 54(3) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 1(4)(c): amended, on 1 November 2022, by clause 161(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clauses 1(4)(d) to (g): revoked, on 1 November 2022, by clause 161(4) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

2 [Revoked]

Compare: Electricity Governance Rules 2003 clause 1.2 schedule G6 part G

Clause 2 Heading: amended, on 28 June 2012, by clause 55(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 2(a), (c), (d) and (e): amended, on 28 June 2012, by clause 55(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 2(b): revoked, on 28 June 2012, by clause 55(2)(c) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 2(c): amended, on 15 May 2014, by clause 70 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 2: revoked, on 1 November 2022, by clause 162 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Inputs used at each stage

3 Specific inputs must be used in schedules

The schedules must be prepared using the following inputs:
- (a) for each price-responsive schedule, the inputs set out in clause 13.58A(1)
- (b) for each non-response schedule, the inputs set out in clause 13.58A(2)
- (c) for each dispatch schedule, the inputs set out in clause 13.69B
- (d) [Revoked]
- (e) [Revoked]

Compare: Electricity Governance Rules 2003 clause 1.3 schedule G6 part G

Clause 3: substituted, on 28 June 2012, by clause 56 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 3: amended, on 1 November 2022, by clause 163(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 3(c): amended, on 1 November 2022, by clause 163(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 3(d) and (e): revoked, on 1 November 2022, by clause 163(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

4 [Revoked]

Clause 4: revoked, on 28 June 2012, by clause 57 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

5 [Revoked]

Clause 5: revoked, on 28 June 2012, by clause 57 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

6 [Revoked]

Compare: Electricity Governance Rules 2003 clause 1.3.3 schedule G6 part G

Clause 6 Heading: amended, on 28 June 2012, by clause 58(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 6: amended, on 28 June 2012, by clause 58(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 6(a): substituted, on 15 May 2014, by clause 71(1) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 6(1)(a)(v): inserted, at 12.00 pm on 19 September 2019, by clause 30(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 6(c): amended, on 15 May 2014, by clause 71(2) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 6(c): amended, on 15 May 2014, by clause 54(3) of the Electricity Industry Participation (Minor Code Amendments) Code Amendment 2014.

Clauses 6(2) and (3): inserted, at 12.00 pm on 19 September 2019, by clause 30(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 6: revoked, on 1 November 2022, by clause 164 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

7 [Revoked]

Compare: Electricity Governance Rules 2003 clause 1.3.4 schedule G6 part G

Clause 7 Heading: amended, on 28 June 2012, by clause 59(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 7: amended, on 28 June 2012, by clause 59(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 7(a): substituted, on 27 May 2015, by clause 17 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 7(a)(i), (a)(ii) and (d): revoked, at 12.00 pm on 19 September 2019, by clause 31(a) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 7(b): substituted, on 28 June 2012, by clause 59(2)(b) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 7(b): substituted, on 15 May 2014, by clause 72(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 7(e): replaced, at 12.00 pm on 19 September 2019, by clause 31(b) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 7(g)(i) and (iii): amended, on 20 December 2021, by clause 61 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

Clause 7(g)(ii): substituted, on 1 November 2012, by clause 6(1) of the Electricity Industry Participation (HVDC Link Pole 3 Standing Data) Code Amendment 2012.

Clause 7(i): amended, on 15 May 2014, by clause 72(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 7: revoked, on 1 November 2022, by clause 165 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

The objective function

8 The objective function

(1) The objective function of the modelling system is described mathematically as:

where

i

is a price band of a bid / offer or a reserve offer

j

is a generating unit / generating station, or a purchaser

D_i,j

is the scheduled demand corresponding to price band i of the bid for purchaser j where the relevant bids used here are formed from a combination of the following, as appropriate to the schedule being calculated:

(a) nominated bids:
(b) the forecast prepared under clause 13.7A(1):
(c) difference bids (if difference bids are used, the quantities must be added or subtracted, as appropriate, from the forecast prepared under clause 13.7A(1)):
(d) the system operator’s expectation of the profile of demand during the relevant period covered by the schedule being calculated:

BP_i,j

is the bid prices corresponding to price band i of the bid for purchaser j where the relevant bid prices used here are formed from a combination of the following, as appropriate to the schedule being calculated:

(a) nominated bids:
(b) the values assigned under clause 13.58AA(1).

G_i,j

is the scheduled generation corresponding to price band i of the offer for unit / station j

OP_i,j

is the offer price corresponding to price band i of the offer for unit / station j

is the scheduled fast GR corresponding to price band i of the fast reserve offer for unit / station j

is the scheduled sustained GR corresponding to price band i of the reserve offer for unit / station j

is the reserve offer price corresponding to price band i of the fast GR reserve offer for unit / station j

is the reserve offer price corresponding to price band i of the sustained GR reserve offer for unit / station j

is the scheduled fast IL corresponding to price band for i of the reserve offer for purchaser j

is the scheduled sustained IL corresponding to price band i of the reserve offer for purchaser j

is the reserve offer price corresponding to price band i of the fast IL reserve offer for purchaser j

is the reserve offer price corresponding to price band i of the sustained IL reserve offer for purchaser j

GR

is generation reserve

IL

is interruptible load

fast

is fast instantaneous reserve

sustained

is sustained instantaneous reserve.

(2) The objective must be maximised to an accuracy specified in the model formulation.

Compare: Electricity Governance Rules 2003 clause 2 schedule G6 part G

Clause 8, definition of Dij: amended, on 28 June 2012, by clause 60 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 8(1) definition of Dij: amended, on 15 May 2014, by clause 73 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 8(1): amended, on 3 May 2022, by clause 10 of the Electricity Industry Participation Code Amendment (Enabling Energy Storage Systems to Offer Instantaneous Reserve) 2022.

Clause 8(1) definition of Dij: amended, on 1 November 2022, by clause 166(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 8(1) definition of BPij: amended, on 1 November 2022, by clause 166(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

9 Constraints

In maximising the objective function, the system operator must ensure that the following constraints are met to an accuracy specified in the model formulation:
- (a) [Revoked]
- (b) each constraint relating to generation set out in clause 9A:
- (c) the constraint relating to demand set out in clause 10:
- (d) each constraint relating to the transmission system set out in clause 11:
- (e) each constraint relating to instantaneous reserve set out in clause 12.

Compare: Electricity Governance Rules 2003 clauses 3 and 3.1 schedule G6 part G

Clause 9: amended, on 28 June 2012, by clause 61 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 9: amended, on 15 May 2014, by clause 74 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 9: amended, on 1 November 2022, by clause 167 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

9A

Constraints relating to generation

The constraints for the purpose of clause 9(b) are that—
(a) for each price band, the modelling system does not schedule electricity generation that would result in the scheduled quantity of electricity to be generated by a generator being greater than the quantity offered by the generator for the price band; and
(b) the modelling system schedules electricity generation for each generating unit or generating station in a trading period within the offered maximum ramp up and ramp down rates of the generating unit or generating station, given the expected (or actual) output at the start of the trading period; and
(c) the modelling system schedules electricity generation for each intermittent generating station in a trading period at a level that is no higher than the potential output of the intermittent generating station, determined as follows:
- (i) in relation to the price-responsive schedule, in accordance with clause 13.58A(1)(aa):
- (ii) in relation to the non-response schedule, in accordance with clause 13.58A(2)(aa):
- (iii) in relation to the dispatch schedule, in accordance with clause 13.71(3):
- (iv) in relation to the input information referred to in clause 13.141, in accordance with clause 13.141(1)(caa):
- (v) [Revoked]

Clause 9A: inserted, on 15 May 2014, by clause 75 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 9A(b): amended, at 12.00 pm on 19 September 2019, by clause 32(1) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 9A(c): inserted, at 12.00 pm on 19 September 2019, by clause 32(2) of the Electricity Industry Participation Code Amendment (Wind Offer Arrangements) 2019.

Clause 9A(c)(v): revoked, on 1 November 2022, by clause 168 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

10 Constraint relating to demand

The constraint relating to demand for the purpose of clause 9(c) is that, for each price band, the modelling system does not schedule electricity demand that would result in the scheduled quantity of demand being greater than the quantity bid by the purchaser for the price band.

Compare: Electricity Governance Rules 2003 clause 3.2 schedule G6 part G

Clause 10: substituted, on 28 June 2012, by clause 62 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 10: substituted, on 15 May 2014, by clause 76 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

11 Constraints relating to transmission system

The final schedule provided by the modelling system must have the following characteristics (all of which must be met to an accuracy to be specified in the model formulation):
- (a) the total scheduled flow into and out of a grid injection point or grid exit point must equal 0 for all grid injection points and grid exit points:
- (b) the modelling system must calculate losses in transmission lines, the HVDC link, and transformers. Those losses must be approximated using the information provided by grid owners under clauses 13.29 to 13.31, for transmission lines, the HVDC link and transformers respectively:
- (c) the modelling system must calculate the electricity flows into individual transmission lines and flows into the connection points of transformers connected at the same grid injection point or grid exit point using an established DC power flow technique within the limitations imposed by the technique that—
  - (i) correctly adjusts flows for transmission system losses; and
  - (ii) correctly apportions flows in transmission system loops, whether or not those loops contain transmission constraints.

Compare: Electricity Governance Rules 2003 clause 3.3 schedule G6 part G

Clause 11 Heading: amended, on 15 May 2014, by clause 77 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 11(b) and (c): amended, on 1 February 2016, by clause 88 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 11(c): amended, on 23 February 2015, by clause 75 of the Electricity Industry Participation Code Amendment (Distributed Generation) 2014.

Clause 11(c): amended, on 5 October 2017, by clause 484 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 11(c): amended, on 1 November 2022, by clause 169 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

12 Constraints relating to instantaneous reserve

(1) The modelling system must simultaneously calculate the amount of fast instantaneous reserve and sustained instantaneous reserve to be provided by each ancillary service agent in each island to meet the requirements of the dispatch objective in each island.
(2) In making the calculation in subclause (1), the modelling system must identify the risk (in MW) associated with the largest “Contingent Event” as the largest of—
- (a) the transfer on a single pole of the HVDC link; or
- (b) the generation from a single generating unit (whether or not this is a generator’s generating unit); or
- (c) any other risk specified in the dispatch objective.
(3) The modelling system must calculate the total amount of fast instantaneous reserve and sustained instantaneous reserve required to meet the requirements of the dispatch objective. The amount of fast instantaneous reserve and sustained instantaneous reserve to be provided by each ancillary service agent is this amount less any instantaneous reserve being provided by any other person who is not an ancillary service agent (as advised by the system operator).
(4) The modelling system must not schedule instantaneous reserve at a generating unit or generating station that would result in the scheduled quantity of electricity to be generated plus the scheduled quantity of instantaneous reserve to be provided that is greater than the maximum generator effective reserve capacity of that generating unit or generating station as specified in the reserve offer for that generating unit or generating station.
(5) The modelling system must use the price and quantity values set out in the table in clause 13.58AA(3) for the following model parameters:
- (a) fast instantaneous reserve contingent event risk violation:
- (b) sustained instantaneous reserve contingent event risk violation.

Compare: Electricity Governance Rules 2003 clause 3.4 schedule G6 part G

Clause 12(2)(b): amended, on 21 September 2012, by clause 32(2) of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 12 Heading: amended, on 15 May 2014, by clause 78 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 12(3): amended, on 5 October 2017, by clause 485 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 12(5): inserted, on 1 November 2022, by clause 170 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

13 Adjustments to schedules to meet dispatch objective

(1) As soon as practicable after each price-responsive schedule and non-response schedule has been completed and each dispatch schedule has been implemented, the system operator must give notice on WITS to participants of any adjustments required to the price-responsive schedule, non-response schedule or dispatch schedule (as the case may be) to meet the dispatch objective, including adjustments for—
- (a) voltage support; and
- (b) frequency keeping reserves; and
- (c) over-frequency arming; and
- (d) additional transmission constraints; and
- (e) instantaneous reserve.
(2) The adjustments identified in subclause (1) must be made by setting 1 or a combination of the following parameters:
- (a) minimum generation (in MW) required at a grid injection point or group of grid exit points:
- (b) maximum generation (in MW) required at a grid injection point or group of grid exit points:
- (c) minimum flow limits (in MW) on a transmission line or a transformer:
- (d) maximum flow limits (in MW) on a transmission line or a transformer:
- (e) minimum flow limits (in MW) on a group of transmission lines or transformers:
- (f) maximum flow limits (in MW) on a group of transmission lines or transformers:
- (g) the reserve modelling parameters as contained in Form 7 in Schedule 13.1.
(3) [Revoked]
(4) [Revoked]

Compare: Electricity Governance Rules 2003 clauses 4.1 and 4.2 schedule G6 part G

Clause 13 Heading: substituted, on 28 June 2012, by clause 63(1) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13(1): amended, on 5 October 2017, by clause 486 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clauses 13(1), (3) and (4): substituted, on 28 June 2012, by clause 63(2) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 13(1): amended, on 1 November 2022, by clause 171(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 13(2)(e) and (f): amended, on 1 February 2016, by clause 89 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 13(3) and (4): revoked, on 1 November 2022, by clause 171(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

14 Principles to be followed by system operator

In suggesting changes and making adjustments under clause 13, the system operator must have regard to the following principles:
- (a) constraints must be imposed on generating plant only if the system operator has a specific requirement from the generating plant to meet the requirements of the dispatch objective:
- (b) constraints must be imposed on a transmission line or transformer only if the system operator has a specific requirement from the line or the transformer to meet the requirements of the dispatch objective:
- (c) adjustments must be made to instantaneous reserve modelling parameters only if the system operator has a specific requirement for instantaneous reserve to meet the requirements of the dispatch objective.

Compare: Electricity Governance Rules 2003 clause 4.3 schedule G6 part G

Clause 14(b): amended, on 28 June 2012, by clause 64 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

15 [Revoked]

Compare: Electricity Governance Rules 2003 clause 5 schedule G6 part G

Clause 15: amended, on 28 June 2012, by clause 65 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 15(aa): inserted, on 15 May 2014, by clause 79(a) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 15(d)(i) and (iii): amended, on 20 December 2021, by clause 62 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2019.

Clause 15(d)(ii): substituted, on 1 November 2012, by clause 6(2) of the Electricity Industry Participation (HVDC Link Pole 3 Standing Data) Code Amendment 2012.

Clause 15(e): amended, on 15 May 2014, by clause 79(b) of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Clause 15: revoked, on 1 November 2022, by clause 172 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

16 Calculation of prices, marginal location factors and reserve prices

(1) The modelling system must calculate the following set of prices:
- (a) prices for electricity at each grid injection point and grid exit point, and at each reference point:
- (b) reserve prices for each island:
- (c) marginal location factors for each grid injection point and each grid exit point. Those factors must be determined by dividing the price at that grid injection point or grid exit point by the price at the reference point relevant to that grid injection point or grid exit point.
(2) The modelling system must assign—
- (a) a price for electricity at each grid injection point and grid exit point that is electrically disconnected in the modelling system; and
- (b) a 0 price for electricity at each grid injection point and grid exit point that is subject to a surplus bus generation infeasibility.”
(3) The prices described in subclause (1) must be used—
- (a) for a price-responsive schedule or a non-response schedule, as—
  - (i) forecast prices; and
  - (ii) forecast reserve prices:
- (b) for a dispatch schedule or for preparing the information referred to in Schedule 13.3B as—
  - (i) dispatch prices; and
  - (ii) dispatch reserve prices.

Compare: Electricity Governance Rules 2003 clauses 6 to 6.2 schedule G6 part G

Clause 16(3): amended, on 28 June 2012, by clause 66 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 16(c): revoked, on 28 June 2012, by clause 66(d) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 16(1)(a): amended, on 21 September 2012, by clause 32(3) of the Electricity Industry Participation (Minor Amendments) Code Amendment 2012.

Clause 16(2): amended, on 5 October 2017, by clause 487 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 16(2): amended, on 1 November 2022, by clause 173(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 16(3): amended, on 1 November 2022, by clause 173(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

17 What modelling system must take into account when calculating prices

The modelling system must calculate the prices in clause 16 consistent with the objective function, and consistent with the quantities of electricity and instantaneous reserve scheduled, while meeting all constraints, and in particular—
- (a) prices for electricity at each grid injection point or grid exit point must be consistent with the treatment of transmission system losses and the transmission system power flow; and
- (b) subject to the rights of the system operator described in clause 13, a generator at a grid injection point must be scheduled to generate a quantity of electricity from a price band if the price determined by the modelling system at the reference point multiplied by the marginal location factor at that grid injection point is greater than or equal to the price offered in that price band; and
- (c) subject to the rights of the system operator described in clause 13, a generator at a grid injection point must not be scheduled to generate a quantity of electricity from a price band if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at that grid injection point is less than the price offered in that price band; and
- (d) for nominated bids, subject to the obligations of the system operator described in clause 13, a purchaser at a grid exit point—
  - (i) must be scheduled to purchase a quantity of electricity from a price band if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at the grid exit point is less than the price bid for the price band; and
  - (ii) must not be scheduled to purchase a quantity of electricity from a price band if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at the grid exit point is greater than the price bid for the price band; and
  - (iii) where the system operator has agreed to model a nominated dispatch bid for a dispatch-capable load station as a binary load, must only be scheduled to purchase the full quantity of MW specified in a price band in the nominated dispatch bid (and not a quantity of electricity that corresponds to only part of the MW specified in a price band in the nominated dispatch bid) or 0 MW. This subparagraph applies despite anything in subparagraphs (i) and (ii); and
- (e) for positive difference bids, subject to the obligations of the system operator described in clause 13, a purchaser at a grid exit point—
  - (i) must be scheduled to increase a quantity of electricity if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at the grid exit point is less than the price bid for the price band; and
  - (ii) must not be scheduled to increase a quantity of electricity if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at the grid exit point is greater than the price bid for the price band; and
- (ea) for negative difference bids, subject to the obligations of the system operator described in clause 13, a purchaser at a grid exit point—
  - (i ) must be scheduled to decrease a quantity of electricity if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at that grid exit point is greater than the price bid for the price band; and
  - (ii) must not be scheduled to decrease a quantity of electricity if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at that grid exit point is less than the price bid for the price band; and
- (eb) subject to the obligations of the system operator described in clause 13, a purchaser at a conforming GXP that does not submit a difference bid in relation to the GXP—
  - (i) must be scheduled to purchase a quantity of electricity from a price band if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at the grid exit point is less than the relevant scarcity price band as described in clause 13.58AA(3); and
  - (ii) must not be scheduled to purchase a quantity of electricity from a price band if the price determined by the modelling system at the reference point multiplied by the relevant marginal location factor at the grid exit point is greater than the relevant scarcity price band as described in clause 13.58AA(3); and
- (f) subject to the rights of the system operator described in clause 13, an ancillary service agent who has made a reserve offer must be scheduled to provide a quantity of instantaneous reserve from a reserve price band only if the reserve price determined by the modelling system is greater than or equal to the total price offered for that reserve price band. In the case of a reserve offer for a generating unit, the total price offered for a price band must be equal to the amount required to ensure that that ancillary service agent is indifferent as to whether it generates electricity or provides instantaneous reserve plus the price offered in that reserve price band; and
- (g) subject to the rights of the system operator described in clause 13, an ancillary service agent who has made a reserve offer must not be scheduled to provide a quantity of instantaneous reserve from a price band if the reserve price determined by the modelling system is less than the total price offered for that price band. In the case of a reserve offer for a generating unit, the total price offered for a price band is equal to the amount required to ensure that that ancillary service agent is indifferent as to whether it generates electricity or provides instantaneous reserve plus the price offered in that reserve price band.

Compare: Electricity Governance Rules 2003 clause 6.3 schedule G6 part G

Clause 17(d) and (e): substituted, on 28 June 2012, by clause 66A(a) and (b) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 17(ea): inserted, on 28 June 2012, by clause 66A(c) of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

Clause 17(d)(iii): inserted, on 1 November 2022, by clause 174(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 17(eb): inserted, on 1 November 2022, by clause 174(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 17(b) and (c): amended, on 1 March 2024, by clause 88 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

Schedule 13.3A

cl 13.135B

[Revoked]

Schedule 13.3A: inserted, on 1 June 2013, by clause 17 of the Electricity Industry Participation (Scarcity Pricing) Code Amendment 2011.

Schedule 13.3A: revoked, on 1 November 2022, by clause 175 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Schedule 13.3AA

cls 13.69AA and 13.69B

Managing an unsupplied demand situation in the dispatch schedule

Schedule 13.3AA: inserted, on 1 November 2022, by clause 176 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

1 Contents of this Schedule

This Schedule sets out the processes by which the system operator—
- (a) assigns price and quantity values as specified in clause 13.69AA:
- (b) adjusts the expected profile of demand in accordance with clause 13.69B(1)(d)(i) used in the preparation of the dispatch schedule under clause 13.69A.

2 Calculating unsupplied demand quantity and price values

(1) For each dispatch schedule prepared under clause 13.69A, the system operator must assign the price and quantity values specified by clause 13.69AA to all non-dispatchable demand according to the methodology in subclause (3).
(2) The methodology in subclause (3) applies at each GXP that is—
- (a) not the subject of a nominated dispatch bid; and
- (b) subject to a nominated non-dispatch bid.
(3) The methodology for calculating the quantity of demand for each price tranche is—

demand (t) = demand (GXP) x fraction (T)

where

demand (t)

is the demand for one of the tranches specified by clause 13.58AA(2)

demand (GXP)

is the total non-dispatchable demand at the GXP

fraction (T)

is the percentage of the relevant demand tranche specified by clause 13.58AA(2).

3 Adjusting expected profile of demand for demand that was unable to be supplied

(1) As soon as practicable after the system operator instructs the electrical disconnection of demand in accordance with Schedule 8.3, Technical Code B, clause 6(1)(d) or 6(2)(d), the system operator must—
- (a) calculate and record the demand limit for each relevant GXP; and
- (b) record the Short-Term Load Forecast values for the relevant load forecast regions for all available 5-minute market intervals in the future, being the linear interpolation across time of the load forecast prepared under clause 13.7A.
(2) After the system operator has instructed the electrical disconnection of demand described in subclause (1), the expected profile of demand used in the dispatch schedule, for the purposes of calculating dispatch prices, is—

expected profile of demand (GXP) = current GXP demand + unsupplied demand (GXP)

where

current GXP demand

is the demand measured according to the information provided by the grid owner under clause 13.69AAA, or an appropriate substitute where information under clause 13.69AAA is unavailable

unsupplied demand (GXP)

is the quantity calculated in subclause (3).

(3) The system operator must apply the following calculation to determine the quantity of demand that was unable to be supplied for the market interval ‘i’:

unsupplied demand (GXP, i) = predicted demand (GXP, i) – demand limit (GXP, i)

where

predicted demand (GXP, i)

is the quantity calculated in subclause (4)

demand limit (GXP, i)

is the limit recorded under subclause (1).

(4) The predicted demand referred to in subclause (3) is the amount of demand that was expected to be present at a given conforming GXP in interval ‘i’ absent the instruction to electrically disconnect demand referred to in subclause (1), estimated at the time of the instruction referred to in subclause (1), calculated as follows:

predicted demand (GXP, i) = current GXP demand x [STLF(i) / STLF (0)]

where

current GXP demand

is the amount of demand at a given GXP at the time of the recording of the instruction referred to in subclause (1), determined according to the system operator’s methodology made available under the policy statement

market interval ‘i’

is the period of time of 5-minute duration for which the relevant dispatch schedule is calculating the expected profile of demand

STLF(i)

is the Short-Term Load Forecast value for the relevant load forecast region in which the GXP is located, for market interval ‘i’

STLF(0)

is the Short-Term Load Forecast for the relevant load forecast region in which the GXP is located, for the market interval in which the instruction referred to in subclause (1) was recorded

in the case of a GXP which is subject to a nominated non-dispatch bid, [STLF(i) / STLF(0)] = 1.

Schedule 13.3B

cls 13.59, 13.69C, 13.104 and 13.104A

Information for schedules prepared by system operator

Schedule 13.3B: inserted, on 1 November 2022, by clause 177 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

1 Purpose of this schedule

(1) This Schedule sets out the information required to be contained in, and/or published by, the dispatch schedule, price-responsive schedule and non-response schedule.
(2) Contents of schedules, columns 1, 2, and 3, are those values derived by the modelling system using the input information listed in clause 13.69B for the dispatch schedule and clause 13.58A for the price-responsive schedule and non-response schedule.
(3) Published information, columns 4, 5, and 6, are those values that are required to be transmitted by the system operator to the WITS manager for public consumption at the time the schedules are published.

		1	2	3	4	5
Information required		Contents of schedules			To be published
Row	Schedule	PRS	NRS	Dispatch	PRS	NRS	Dispatch
1	scheduled average level of electricity output for each generating plant or generating unit	X	X
2	scheduled level of electricity output for each generating plant or generating unit			X
3	scheduled average level of instantaneous reserve for each generating plant or generating unit	X	X
4	scheduled level of instantaneous reserve for each generating plant or generating unit			X
5	scheduled average level of interruptible load for each ancillary service agent for each grid exit point or interruptible load group grid exit point	X	X
6	scheduled level of interruptible load for each ancillary service agent for each grid exit point or interruptible load group grid exit point			X
7	scheduled frequency keeping units for each island	X	X			X
8	expected average level of demand at each grid exit point	X	X		X	X
9	expected level of demand at each grid exit point			X			X
10	forecast prices	X	X		X	X
11	dispatch prices			X			X
12	forecast reserve prices	X	X		X	X
13	dispatch reserve prices			X			X
14	start time (to the nearest second) for each dispatch price and each dispatch reserve price						X
15	forecast marginal location factors for each grid injection point and each grid exit point	X	X		X	X
16	dispatch marginal location factors for each grid injection point and each grid exit point			X			X
17	scheduled largest single reserve risk in each island	X	X	X	X	X	X
18	scheduled number of reserve risks for each island	X	X	X	X	X	X
19	for each island, the scheduled number of reserve risks subject to the fast instantaneous reserve contingent event risk violation and sustained instantaneous reserve contingent event risk violation model parameters set out in Schedule 13.2	X	X	X	X	X	X
20	scheduled level of fast instantaneous reserve and sustained instantaneous reserve in each island	X	X	X	X	X	X
21	separate stacks of reserve offers for fast instantaneous reserve and sustained instantaneous reserve for each island (ranking in price order from lowest to highest)	X	X	X	X	X	X
22	separate stacks of all reserve offers for fast instantaneous reserve and sustained instantaneous reserve for each island (ranking in price order from lowest to highest) adjusted for the expected level of energy output for each generating plant or generating unit	X	X	X	X	X	X
23	scheduled HVDC component flows	X	X	X	X	X	X
24	scheduled HVDC risk offsets	X	X	X	X	X	X
25	expected near-constraint arc flows	X	X	X	X	X	X
26	expected near-group-constraint arc flows	X	X	X	X	X	X
27	group constraint formulas relating to the expected near-group-constraint arc flows	X	X	X	X	X	X
28	scheduled deficit quantities for energy, fast instantaneous reserve, and sustained instantaneous reserve (if any)	X	X	X	X	X	X
29	whether the HVDC link is out of service	X	X	X	X	X	X
30	quantity of demand for which price and quantity values have been assigned by the system operator under clause 13.58AA(1)(a)	X
31	quantity of demand for which price and quantity values have been assigned by the system operator under clause 13.58AA(1)(b)		X
32	quantity of demand for which price and quantity values have been assigned by the system operator under clause 13.69AA(1)(a)			X
33	quantities for each bid scheduled to be supplied	X
34	expected non-dispatch-capable load at each conforming GXP		X
35	expected demand for each nominated bid		X
36	quantities for each nominated dispatch bid scheduled to be supplied			X
37	in the case of an unsupplied demand situation, the demand (in MW) unable to be supplied at each grid exit point	X	X	X	X	X	X
38	aggregate supply curve at each reference point incorporating all offers from generators with offer prices adjusted for forecast marginal location factors, and adjusted so that, for each intermittent generating station, the total offered quantity is no greater than the forecast of generation potential for that intermittent generating station, being the forecast of generation potential used as an input into the price-responsive schedule or the non-response schedule (whichever applies)				X	X
39	aggregate supply curve at each reference point incorporating all offers from generators with offer prices adjusted for dispatch marginal location factors						X
40	grid injection points and grid exit points that are electrically disconnected in the modelling system				X	X	X
41	aggregate demand curve at each reference point incorporating the forecast prepared under clause 13.7A(1), and all bids from purchasers with bid prices adjusted for forecast marginal location factors				X
42	aggregate demand curve at each reference point incorporating the expected profile of demand, and all nominated dispatch bids with bid prices adjusted for dispatch marginal location factors						X
43	number of transmission lines or transformers that have a MW arc flow equal to the maximum flow limit (in MW) on that transmission line or transformer set by the grid owner in accordance with clauses 13.29 to 13.32						X
44	number of groups of transmission lines or transformers, or both, that have a total MW arc flow equal to the relevant maximum flow limit (in MW) as set by the system operator in accordance with Schedule 13.3						X
45	aggregate of the following: (i) the number of occurrences at which energy (in MW) for a generator at a set of grid injection points is equal to the minimum and/or maximum generation (in MW) for that set of grid injection points set by the system operator in accordance with Schedule 13.3: (ii) the number of occurrences at which energy (in MW) and reserves (in MW) for a generator at a set of grid injection points is equal to the maximum generation (in MW) for that set of grid injection points set by the system operator in accordance with Schedule 13.3: (iii) the number of occurrences at which reserve (in MW) for a participant at a set of grid exit points is equal to the maximum reserve (in MW) for that set of grid exit points as determined under Schedule 13.3						X
46	number of occurrences at which the ramp up rate is equal to the maximum ramp up rate specified in the relevant offer						X
47	number of occurrences at which the ramp down rate is equal to the maximum ramp down rate specified in the relevant offer						X

Schedule 13.4

cl 13.3

Approval as type A or type B industrial co-generating station

Heading: amended, on 27 May 2015, by clause 18 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

1 Generators to apply to Authority for approval

A generator may apply to the Authority to have 1 or more generating units approved as—
- (a) a type A industrial co-generating station; or
- (b) a type B industrial co-generating station.

Compare: Electricity Governance Rules 2003 clause 1 schedule G9 part G

Clause 1: substituted, on 27 May 2015, by clause 19 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

2 Application requirements

(1) An application must—
- (a) be in writing; and
- (b) specify each generating unit that the applicant wants to have approved; and
- (c) include information related to any seasonal operation of each generating unit; and
- (d) specify whether the applicant wants each generating unit to be approved as a—
  - (i) type A industrial co-generating station; or
  - (ii) type B industrial co-generating station.
(2) An applicant may include any supporting information that the applicant considers may assist the Authority with the application.

Compare: Electricity Governance Rules 2003 clause 2 schedule G9 part G

Clause 2: substituted, on 27 May 2015, by clause 20 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

3 Authority must publish each application for approval

On receipt of an application, the Authority must—
- (a) publish the application; and
- (b) provide a copy of the application to the system operator.

Compare: Electricity Governance Rules 2003 clause 3 schedule G9 part G

Clause 3 Heading: amended, on 5 October 2017, by clause 488(1) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 3(a): amended, on 5 October 2017, by clause 488(2) of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

4 Factors that Authority must consider

Before the Authority approves an application, it must take into account—
- (a) the system operator’s views as to the effect an approval would have on the system operator’s ability to meet the PPOs; and
- (b) the cumulative effects, if the approval were granted, of all approvals granted under this Schedule on the system operator’s ability to meet the PPOs; and
- (c) any views that may be made known to the Authority within the time specified by the Authority when it published the application in accordance with clause 3(a); and
- (d) whether each generating unit that is the subject of the application is as described in paragraphs (b) and (c) of the definition of industrial co-generating station set out in Part 1; and
- (da) the implications of each generating unit that is the subject of the application being approved in accordance with the applicant's preference specified under clause 2(1)(d), having regard to the obligations of type A co-generators and type B co-generators; and
- (e) the Authority’s main objective in section 15 of the Act.

Compare: Electricity Governance Rules 2003 clause 4 schedule G9 part G

Clause 4: amended, on 27 May 2015, by clause 21(1) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 4(c): amended, on 5 October 2017, by clause 489 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 4(d): substituted, on 27 May 2015, by clause 21(2) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 4(da): inserted, on 27 May 2015, by clause 21(2) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 4(e): amended, on 1 March 2024, by clause 89 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2024.

5 Authority may require extra information

The Authority may require the provision of additional information at any stage during the application process and, if the Authority’s requirements are reasonable, the applicant must provide that information to the Authority.

Compare: Electricity Governance Rules 2003 clause 5 schedule G9 part G

6 Authority may seek independent expert advice

In considering an application for approval, the Authority may seek technical advice from an independent person who is familiar with co-generation.

Compare: Electricity Governance Rules 2003 clause 6 schedule G9 part G

7 Applicant may withdraw or amend application at any time

(1) The applicant may, at any time, withdraw or amend an application being considered by the Authority.
(2) An amendment or withdrawal—
- (a) must be made in writing; and
- (b) must be submitted to the Authority; and
- (c) takes effect from the date of receipt by the Authority.

Compare: Electricity Governance Rules 2003 clause 7 schedule G9 part G

Clause 7(1): amended, on 27 May 2015, by clause 22(1) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 7(2): inserted, on 27 May 2015, by clause 22(2) of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

8 Authority's decision

(1) The Authority must, no later than 6 months after receiving an application,—
- (a) approve each generating unit that is the subject of the application as either—
  - (i) a type A industrial co-generating station; or
  - (ii) a type B industrial co-generating station; or
- (b) decline to approve the application.
(2) The Authority must consult with an applicant before making a decision if the Authority—
- (a) proposes to approve an application for a type of industrial co-generating station other than the applicant's preference specified under clause 2(1)(d); or
- (b) proposes to decline the application.
(3) The Authority must, as soon as practicable after making a decision,—
- (a) advise the applicant, the system operator, the grid owner, and the clearing manager in writing; and
- (b) publish its decision, including—
  - (i) the reasons for the decision; and
  - (ii) in the case of an application that has been approved, any conditions that have been imposed.

Compare: Electricity Governance Rules 2003 clause 8 schedule G9 part G

Clause 8: substituted, on 27 May 2015, by clause 23 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 8(3)(b): amended, on 5 October 2017, by clause 490 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

9 Decision must be recorded

(1) The Authority must keep a register of all current approvals granted under this Schedule available for public inspection free of charge during normal office hours at the offices of the Authority and on the Authority’s website at all reasonable times.
(2) The register must state, for each approval on the register,—
- (a) whether the applicant's generating units have been approved as a type A co-generating station or a type B co-generating station; and
- (b) the name of the type A co-generator or the type B co-generator; and
- (c) the name of the type A industrial co-generating station or the type B industrial co-generating station; and
- (d) the date of the approval; and
- (e) the duration of the approval; and
- (f) whether the approval includes any conditions and if so, a description of the conditions.

Compare: Electricity Governance Rules 2003 clause 9 schedule G9 part G

Clause 9(2): substituted, on 27 May 2015, by clause 24 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

10 Effect of approval

Approval of 1 or more generating units as a type A industrial co-generating station or a type B industrial co-generating station takes effect from the date specified in the approval, which may be no earlier than 10 business days after the date of the notice of decision published by the Authority under clause 8(3).

Compare: Electricity Governance Rules 2003 clause 10 schedule G9 part G

Clause 10: substituted, on 27 May 2015, by clause 25 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Clause 10: amended, on 5 October 2017, by clause 491 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

11 Authority may impose conditions

The Authority may impose conditions on any approval it grants. Such conditions may include 1 or more of the following:
- (a) requirements to assist the system operator in meeting the PPOs:
- (b) requirements as to seasonal co-generation, including limitations on when the approval applies:
- (c) requirements that a type A co-generator or type B co-generator comply with specific instructions from the system operator during a grid emergency or during a system constraint that directly affects the type A co-generator or type B co-generator.

Compare: Electricity Governance Rules 2003 clause 11 schedule G9 part G

Clause 11(b) and (c): substituted, on 27 May 2015, by clause 26 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

12 [Revoked]

Compare: Electricity Governance Rules 2003 clause 12 schedule G9 part G

Clause 12: revoked, on 27 May 2015, by clause 27 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

13 Authority may rescind or amend approval

(1) If the Authority considers a change of circumstance has led to a situation in which the continuation of an approval would significantly adversely impact on the system operator’s ability to meet the PPOs, it may amend or rescind the approval.
(2) The Authority may, at the request of a type A co-generator or a type B co-generator, amend an approval to change a type A industrial co-generating station to a type B co-generating station, or vice-versa.
(3) The Authority must consult with the system operator before amending an approval under subclause (2).

Compare: Electricity Governance Rules 2003 clause 13 schedule G9 part G

Clause 13(2) and (3): inserted, on 27 May 2015, by clause 28 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

14 Notice and reasons for rescinding or amending approval

If the Authority amends or rescinds an approval, it must—
- (a) give the type A co-generator or type B co-generator 3 months' notice before rescinding or amending the approval; and
- (b) advise the type A co-generator or type B co-generator of the reasons for rescinding or amending the approval.

Compare: Electricity Governance Rules 2003 clause 14 schedule G9 part G

Clause 14(a) and (b): substituted, on 27 May 2015, by clause 29 of the Electricity Industry Participation Code Amendment (Industrial Co-generation Dispatch Arrangements) 2015.

Schedule 13.5

cl 13.238

Requirements for FTR allocation plan

Schedule 13.5: inserted, on 1 October 2011, by clause 9 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

1 Purpose

The purpose of this Schedule is to set out the requirements for the FTR allocation plan prepared by the FTR manager under subpart 6 of Part 13.

2 Requirements for design of FTRs

(1) FTRs must be allocated by auction.
(2) At a minimum, the FTRs allocated under the FTR allocation plan must be FTRs between a hub in the South Island and a hub in the North Island that would provide a reasonable match with the trading points for exchange–traded futures products or the equivalent electricity futures products, and which would enable the volumes of FTRs available to reflect inter-island grid capacity.
(3) The FTR manager must offer option FTRs and obligation FTRs.
(4) The FTRs offered must include FTRs for which the FTR period is 1 month.
(5) Subclause (4) does not prevent the FTR manager from offering FTRs relating to a shorter FTR period in addition to FTRs for which the FTR period is 1 month.

3 Requirements for FTR auction design

(1) The number and nature of the FTRs allocated under the FTR allocation plan and available for auction must be—
- (a) supported by a reasonable estimate of the capacity of the grid for the relevant period; and
- (b) set so as to achieve a reasonable balance between the following:
  - (i) ensuring that there is revenue available that is sufficient to settle the FTRs:
  - (ii) ensuring that sufficient FTRs are available so that participants who wish to purchase FTRs are able to obtain them.
(2) The FTR auction must be designed to—
- (a) maximise the value of trade in the auction as determined by the bids made in the auction; and
- (b) maximise competition in the auction; and
- (c) minimise costs of participation in the auction.
(3) The FTR allocation plan must include FTR auction procedures.
(4) The initial FTR allocation plan must specify a plan that seeks to—
- (a) ensure that, no later than 1 year after the first FTR auction, FTRs are available in each FTR auction relating to an initial month and to at least each of the 11 months following the initial month; and
- (b) ensure that the availability of FTRs is progressively increased so that, no later than 3 years after the first FTR auction, FTRs are available in each FTR auction relating to an initial month and to at least the 23 months following the initial month.

Clause 3(3): amended, on 5 October 2017, by clause 492 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

4 Requirements for FTR grid design

The FTR grid must—
- (a) be based on each grid owner's forecast of the configuration and capacity of its grid for the FTR period; and
- (b) make allowance for relevant planned and unplanned outages in accordance with reasonable transmission operating practice.

Schedule 13.6

cl 13.248

Assignment of FTR

Schedule 13.6: inserted, on 1 October 2011, by clause 9 of the Electricity Industry Participation (Financial Transmission Rights) Code Amendment 2011.

Schedule 13.6: amended, on 1 June 2012, by clause 7 of the Electricity Industry Participation (Removal of Quantity Limit for Financial Transmission Rights) Code Amendment 2012.

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Schedule 13.7

cls 13.27C, 13.27E, 13.27G, and 13.27K

Methodology for Determining Conforming and Non-Conforming GXPs

Schedule 13.7: inserted, on 28 March 2012, by clause 67 of the Electricity Industry Participation (Demand-side Bidding and Forecasting) Code Amendment 2011.

1 Methodology for determining whether GXP is conforming GXP or non-conforming GXP

In making a determination under clause 13.27A or clause 13.27B(4), the Authority must use the following method:
(a) use the input data described in clause 2 to determine the adjusted reconciled half hour demand data (in MW) for the GXP for each trading period during the most recent 12 consecutive months for which data is available; and
(b) using the results from paragraph (a), determine the mean demand (in MW) for the GXP over the most recent 12 consecutive months for which data is available; and
(c) determine the unpredictability measure for the GXP in accordance with clause 3; and
(d) apply the results from paragraphs (b) and (c) to the table below, to determine whether the GXP is either a conforming GXP or a non-conforming GXP.

Table 1: Determining whether GXP is conforming or non conforming

Category for mean demand (in MW) for a GXP over relevant 12 months (clause 1(b)) *(d)*	Category for unpredictability measure (clause 1(c)) *(p)*	Resulting classification of the GXP
Where d < 10MW	For all p	Conforming GXP
Where 10MW ≤ d < 20MW	For p < 0.15	Conforming GXP
Where 10MW ≤ d < 20MW	For p ≥ 0.15	Non-conforming GXP
Where 20MW ≤ d < 250 MW	For p < 0.10	Conforming GXP
Where 20MW ≤ d < 250 MW	For p ≥ 0.10	Non-conforming GXP
Where d ≥ 250 MW	For all p	Non-conforming GXP

2 Input data

(1) For the purpose of determining the adjusted reconciled half hour demand data for a GXP under clause 1(a), the Authority must use the following data from the most recent 12 consecutive months for which data is available:
- (a) reconciled half hour demand data for the GXP representing purchases of electricity at the GXP aggregated across all purchasers at the GXP, and with each half hour figure in MWh converted to an average demand in MW over that half hour; and
- (b) information about the impact of demand switching on the GXP; and
- (c) information from distributors, purchasers and the system operator about any one-off events that have affected demand but which would not be expected to affect demand in the future.
(2) If the Authority identifies, under subclause (1)(b), that 2 or more adjacent GXPs are significantly affected by demand switching, the Authority must—
- (a) combine the GXPs’ reconciled half hour demand data as described in subclause (1)(a) and follow the method set out in clause 1 for the combined GXPs as if they were a single GXP; or
- (b) follow such other method of addressing the impact of demand switching as the Authority may determine is appropriate in the circumstances.
(3) In applying the methodology under clause 1, the Authority must remove one-off events identified under this clause from the input data.
(4) A one-off event includes, but is not limited to, the following:
- (a) a transmission outage that has caused a GXP to be unable to be supplied with electricity:
- (b) a consumer ceasing to consume at a GXP, if over the proportion of the relevant 12 month period for which the consumer was consuming electricity, the reconciled demand attributed to the consumer (in MW) was on average at least 40% of the total demand (in MW) at the GXP.

3 Calculate unpredictability measures

(1) For the purpose of determining the unpredictability measure of a GXP under clause 1(c), the Authority must use the following method:
- (a) the Authority must fit an appropriate statistical predictive model as described in subclause (2), to the adjusted reconciled half hour demand data (in MW) which is produced in accordance with clause 1(a); and
- (b) the Authority must calculate the residuals (in MW for each half hour) of the statistical predictive model (representing the simulated predictive errors of such a model); and
- (c) the Authority must calculate the unpredictability measure as the ratio of the standard deviation of the residuals calculated under paragraph (b) to the mean demand at the GXP (calculated under clause 1(b)).
(2) The statistical predictive model under subclause (1)(a) must achieve the approximate level of predictive accuracy that should be able to be achieved by the system operator when preparing the forecast under clause 13.7A several hours in advance in the absence of forecast information from purchasers and electricity users.
(3) To avoid doubt, the statistical predictive model may include a variable representing weather forecast information.

Clause 3(2): amended, on 15 May 2014, by clause 80 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

4 Data for most recent 12 months unavailable

(1) If the data required under clauses 1 to 3 is not available for the most recent 12 consecutive months, the Authority must use reasonable endeavours to make a determination in accordance with the methodology set out in this Schedule using the data it has available.
(2) If the available data is insufficient to enable the Authority to make a determination in accordance with subclause (1), the Authority must make a determination by—
- (a) using all available data; and
- (b) using its own reasonable expectations of the future activities at the GXP; and
- (c) taking into account, to the extent practicable, the methodology set out in clauses 1 to 3.

Schedule 13.8

cl 1.1, 13.3A, 13.3B and 13.3E

Approval of dispatch-capable load station

Schedule 13.8: inserted, on 15 May 2014, by clause 81 of the Electricity Industry Participation (Modified Dispatchable Demand) Code Amendment 2013.

Heading: amended, on 1 November 2022, by clause 178 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

1 Applications for approval

Each application for approval for a dispatch-capable load station must—
- (a) be in writing; and
- (b) list the device, devices or group(s) of devices that the applicant wishes to have approved as a dispatch-capable load station; and
- (ba) specify whether the applicant intends to operate the device, devices or group(s) of devices as a dispatch notification purchaser; and
- (c) include information to enable the system operator to determine the application.

Clause 1(ba): inserted, on 1 November 2022, by clause 179 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 1(b): amended, on 1 March 2024, by clause 10(1) of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

Clause 1(ba): amended, on 1 March 2024, by clause 10(2) of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

1A

Change to purchaser type

A dispatchable load purchaser may, with the approval of the system operator provided in accordance with the application process specified in this Schedule, change from operating a dispatch-capable load station as a dispatchable load purchaser (that is not a dispatch notification purchaser) to operating the dispatch-capable load station as a dispatch notification purchaser, or vice versa.

Clause 1A: inserted, on 1 November 2022, by clause 180 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

2 System operator to provide application to Authority and advise others of application

On receipt of an application, the system operator must—
(a) provide a copy of the application to the Authority; and
(b) advise the following participants that it has received the application:
- (i) the relevant grid owner:
- (ii) each distributor that has a network from which a device that comprises or forms part of the proposed dispatch-capable load station draws electricity:
- (iii) [Revoked]
- (iv) the clearing manager:
- (v) the reconciliation manager:
- (vi) the WITS manager.

Clause 2(b)(ii) substituted, on 1 February 2016, by clause 90 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2015.

Clause 2(b)(vi): amended, on 5 October 2017, by clause 493 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 2B(iii): revoked, on 1 November 2022, by clause 181 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

3 Factors that system operator must consider

(1) Before the system operator approves a device or a group of devices to be a dispatch-capable load station, it must consider—
- (aa) where the application is for a dispatch-capable load station consisting of devices or a group of devices located at more than one GXP, the most appropriate GXPs at which nominated bids for the dispatch-capable load station would be submitted; and
- (a) the effect an approval would have on the system operator’s ability to comply with the PPOs; and
- (b) whether the applicant—
  - (i) is able to provide real time indications and measurements to the satisfaction of the system operator; and
  - (ii) has in place communication systems that meet the system operator’s requirements; and
  - (iii) is able to receive dispatch instructions or dispatch notifications (as the case may be); and
- (c) whether there is a substantial risk that a dispatch instruction or dispatch notification (as the case may be) that changes the level of load of the device or group of devices that is the subject of the application may be offset by changes in demand in the same trading period from other load controlled by the applicant; and
- (d) whether the device or group of devices is technically capable of complying with a dispatch instruction or dispatch notification (as the case may be) so that it does not adversely affect the system operator’s ability to comply with the PPOs; and
- (e) any other matter the system operator reasonably considers relevant.
(2) When considering the matters under subclause (1), the system operator must—
- (a) ask the Authority for the Authority’s view; and
- (b) consider the Authority’s view.

Clause 3(1)(aa): inserted, on 1 March 2024, by clause 11 of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

Clause 3(1)(b)(iii): amended, on 1 November 2022, by clause 182(1) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 3(1)(c): amended, on 1 November 2022, by clause 182(2) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 3(1)(d): amended, on 1 November 2022, by clause 182(3) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

Clause 3(2): amended, on 1 November 2022, by clause 182(4) of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

4 System operator may request additional information

(1) Subclauses (2) and (3) apply to—
- (a) a participant that has applied to the system operator to have a device or a group of devices approved as a dispatch-capable load station; and
- (b) a purchaser that has a dispatch-capable load station that has been approved.
(2) The system operator may request a participant to which this clause applies to provide additional information.
(3) The participant must provide the requested information to the system operator.
(4) As soon as practicable after receiving the requested information, the system operator must provide a copy of the information to the Authority.

5 Applicant may withdraw or amend application at any time

(1) An applicant may, at any time, amend or withdraw an application.
(2) An applicant must make an amendment or withdrawal—
- (a) in writing; and
- (b) by submitting it to the system operator.
(3) An amendment or a withdrawal takes effect from the date of receipt by the system operator.
(4) As soon as practicable after receiving an amendment or a withdrawal, the system operator must—
- (a) provide the amendment or withdrawal to the Authority; and
- (b) advise all participants listed in clause 2(b) of the amendment or withdrawal.

6 System operator’s decision

(1) The system operator must decide whether to—
- (a) approve an application; or
- (b) decline an application.
(1A) Where the system operator decides to approve an application under subclause (1) and the dispatch-capable load station consists of devices or a group of devices located at more than one GXP, the system operator must—
- (a) assign a primary GXP at which nominated bids are to be submitted for that dispatch-capable load station; and
- (b) specify one or more alternative GXPs at which, following the system operator giving reasonable notice under clause 13.7(4)(b), nominated bids are to be submitted for that dispatch-capable load station.
(2) If the system operator decides to approve an application, the system operator must assign a dispatch-capable load station identifier to each approved dispatch-capable load station and, if subclause (1A) applies, must assign separate dispatch-capable load station identifiers for the primary and alternative GXPs at which nominated bids are to be submitted.
(3) The system operator must, as soon as practicable after making a decision, advise the parties listed in subclause (4) in writing of—
- (a) the decision; and
- (b) if the decision is to approve the application, any conditions that apply to the approval; and
- (c) the system operator’s reasons for the decision.
(4) For the purpose of subclause (3), the system operator must advise the following parties:
- (a) the applicant:
- (b) the Authority:
- (c) all participants listed in clause 2(b).

Clause 6(1A): inserted, on 1 March 2024, by clause 12(1) of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

Clause 6(2): amended, on 1 March 2024, by clause 12(2) of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

7 System operator may impose conditions

(1) The system operator may impose conditions on any approval it grants under this Schedule.
(2) Conditions may include, but are not limited to, 1 or more of the following:
- (a) a requirement that the applicant has in place real time indications and measurements to the satisfaction of the system operator:
- (b) a requirement that the applicant has in place a system for communicating with the system operator to the satisfaction of the system operator:
- (c) a requirement that the applicant performs tests of load controlling systems on a regular basis.

8 Timeframe for decision

(1) The system operator must make a decision under clause 6(1)—
- (a) within 20 business days after—
  - (i) the date on which the system operator receives the application; or
  - (ii) if the application is amended under clause 5, the date on which the system operator receives the amendment; or
- (b) within any other period of time that has been agreed by the applicant and the system operator.
(2) Despite subclause (1), if the system operator requests additional information from the applicant under clause 4, the timeframes in subclause (1) are extended by the number of days the applicant takes to provide the additional information.

9 Effect of approval

(1) When approving an application for a dispatch-capable load station, the system operator must specify a date from which the approval takes effect.
(2) The system operator must not set a date from which an approval takes effect that is earlier than 10 business days after the date on which the approval was granted.
(3) An approval of a dispatch-capable load station takes effect from the date specified in the approval.

10 System operator may amend, revoke, or suspend approval

(1) The system operator may, at its own discretion or on the request of the Authority or a dispatchable load purchaser,—
- (a) amend an approval; or
- (b) revoke an approval; or
- (c) suspend an approval.
(2) An amendment takes effect from—
- (a) the date it is made; or
- (b) a later date specified by the system operator.
(3) A revocation takes effect from—
- (a) the date it is made; or
- (b) a later date specified by the system operator.
(4) A suspension—
- (a) takes effect from—
  - (i) the date it is made; or
  - (ii) a later date specified by the system operator; and
- (b) remains in effect until a date specified by the system operator.

11 System operator to give reasons for amending, revoking, or suspending approval

As soon as practicable after the system operator amends, revokes, or suspends an approval under this Schedule, the system operator must advise the purchaser, the Authority, and all participants listed in clause 2(b) of—
- (a) the revocation, suspension, or amendment; and
- (b) the reasons for the revocation, suspension, or amendment.

Clause 11: amended, on 1 November 2022, by clause 183 of the Electricity Industry Participation Code Amendment (Real Time Pricing) 2022.

12 Authority to keep register of all current approvals

(1) The Authority must keep a register of all current approvals—
- (a) granted under this Schedule; and
- (b) of which the system operator has advised the Authority.
(2) The Authority must keep the register available for public inspection free of charge—
- (a) at its offices, during normal office hours; and
- (b) on its website, at all reasonable times.
(3) The register must state, for each approval granted,—
- (a) the name of the applicant; and
- (b) the name of the dispatch-capable load station; and
- (c) the dispatch-capable load station identifier(s); and
- (d) the date from which the approval takes effect; and
- (e) any conditions.

Clause 12(1)(b): replaced, on 5 October 2017, by clause 494 of the Electricity Industry Participation Code Amendment (Code Review Programme) 2017.

Clause 12(3)(c): amended, on 1 March 2024, by clause 13 of the Electricity Industry Participation Code Amendment (Dispatch Notification Enhancement and Clarifications) 2024.

Electricity Industry Participation Code 2010