Wholesale Electricity Market Rules - Amending Rules (31 March 2006) (WA)

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WESTERN 1371
AUSTRALIAN
GOVERNMENT

ISSN 1448-949X

PERTH, FRIDAY, 31 MARCH 2006 No. 61 SPECIAL
PUBLISHED BY AUTHORITY JOHN A. STRIJK, GOVERNMENT PRINTER AT 5.30 PM
© STATE OF WESTERN AUSTRALIA

ELECTRICITY INDUSTRY ACT 2004
_________

ELECTRICITY INDUSTRY

(WHOLESALE ELECTRICITY
MARKET) REGULATIONS 2004
_________

WHOLESALE ELECTRICITY
MARKET RULES
_________

AMENDING RULES

31 March 2006 GOVERNMENT GAZETTE, WA 1373
ELECTRICITY INDUSTRY ACT 2004

ELECTRICITY INDUSTRY (WHOLESALE ELECTRICITY MARKET) REGULATIONS 2004
WHOLESALE ELECTRICITY MARKET RULES
Amending Rules

I, Francis Logan, Minister for Energy for the State of Western Australia, under regulation 6(2) of the Electricity Industry (Wholesale Electricity Market) Regulations 2004 hereby make the amending rules contained in this document.
These amending rules are to commence in accordance with regulation 6.3 of the Electricity Industry
(Wholesale Electricity Market) Regulations 2004.
Dated at Perth this 24th day of March 2006.

FRANCIS LOGAN, MLA, Minister for Energy.

————
1. Market Rule 1.4 amended
(1) Insert a new clause 1.4.2 as follows—
1.4.2. In these Market Rules, unless the contrary intention appears, any notice or confirmation required to be issued by the IMO may be issued by an automated software system employed by the IMO.
2. Market Rule 2.2 amended
(1) Delete the existing clause 2.2.1 and replace it with the following—
2.2.1. The Electricity Networks Corporation, acting through the segregated business unit known as System Management, has the function of operating the SWIS in a secure and reliable manner for the purposes of regulation 13(1) of the Regulations.
(2) Delete the existing clause 2.2.2(a) and replace it with the following—

(a)

to procure adequate Ancillary Services where the Electricity Generation Corporation cannot meet the Ancillary Service Requirements;

(3) Delete the existing comment box following clause 2.2.3 and replace it with the following—

System Management will be a ring-fenced business unit of the Electricity Networks Corporation and will report to the Electricity Networks Corporation Board with regard to performance against budgets and objectives, including its compliance with the Market Rules. The Board will in turn report to the Shareholding Minister. System Management’s compliance with the rules will be monitored by the IMO and breaches reported to the ERB, and the IMO will report on System Management’s performance to the Minister.
3. Market Rule 2.3 amended
(1) Delete the existing clause 2.3.5 and replace it with the following—

2.3.5. Subject to clause 2.3.13., the Market Advisory Committee must comprise—

(a)

three members representing generators, of whom one must represent the Electricity Generation Corporation;
(b) one member representing Contestable Customers;

(c)

at least one and not more than two members representing Network Operators, of whom one must represent the Electricity Networks Corporation;

(d)

three members representing retailers, of whom one must represent the Electricity Retail Corporation;
(e) one member nominated by the Minister to represent small consumers;
(f) one member representing System Management;
(g) one member representing the IMO; and

(h)

a chairperson of the Market Advisory Committee, who must be a representative of the IMO.
4. Market Rule 2.13 amended
(1) Delete the comment box following clause 2.13.3.
5. Market Rule 2.16 amended
(1) Insert a new clause 2.16.2(hA) and comment box as follows—
(hA) any evidence that a Market Customer has significantly over-stated its consumption as indicated by its Net Contract Position with a regularity that cannot be explained by a reasonable allowance for forecast uncertainty or the impact of Loss Factors.

1374 GOVERNMENT GAZETTE, WA 31 March 2006
The behaviour by a Market Customer described in clause (hA) is prohibited by clause 6.7.4. This behaviour could be a symptom that a non-EGC generator supplying the Market Customer under a bilateral contract has caused the scheduling of additional energy from the Market Generator’s facilities with the result in real-time that the Electricity Generation Corporation supplies less energy than it was contracted to supply under its own Bilateral Submissions (with it being settled at MCAP which may not reflect its actual costs). This feature could also be used to ensure that a non-EGC generator can remain committed overnight during periods of low demand ahead of the Electricity Generation Corporation. However, if the Market Customer addresses this over-supply in the STEM then this is acceptable, because to the extent that the Electricity Generation Corporation is scheduled down in the STEM, it will be compensated at the economic value of that energy (as defined by Electricity Generation Corporation STEM Bids). Note that this clause does not place any restrictions as to how generation levels can change relative to a Bilateral Submission (e.g., in the case of the Electricity Generation Corporation, as a result of its balancing obligations).

(2) Amend clause 2.16.2(j) by deleting the words “Western Power” and replacing them with “the
Electricity Generation Corporation”.
(3) Delete the existing clause 2.16.7 and associated comment box and replace them with the
following—

2.16.7. Without limitation, additional information that can be collected by the Economic

Regulation Authority includes—

(a) cost data for the Electricity Generation Corporation, including actual fuel costs by Trading Interval;
(b) System Management’s operational records, including SCADA records, of the level of utilisation and fuel related data for each of the Electricity Generation Corporation’s Registered Facilities by Trading Interval; and
(c) the terms of Bilateral Contracts entered into by the Electricity Generation Corporation and the Electricity Retail Corporation.
Note that under clauses 2.16.6 and 2.16.14, the ERA can only collect and use this data in carrying out its functions under this clause 2.16—i.e. in the case of the above data, primarily for market power assessment. The Electricity Generation Corporation and the Electricity Retail Corporation are not commercially accountable to the ERA.

6. Market Rule 2.17 amended
(1) In the comment box following clause 2.17.1(o) delete the word “Support” and replace it with
“Control” instead.
7. Market Rule 2.19 amended
(1) Delete the existing comment box following clause 2.19.6 and replace it with the following—
In the case of disputes involving System Management, in some circumstances the CEO of the Electricity Networks Corporation may not be appropriate person, and the general manager of System Management should be used.

8. Market Rule 2.23 amended
(1) Delete the existing clause 2.23.10 and replace it with the following—
2.23.10. The budget proposal must be reflected in the Statement of Corporate Intent for the Electricity Networks Corporation and must be consistent with the segregation of System Management from other business units of the Electricity Networks Corporation.
(2) Delete the existing subclauses 2.23.12(d)(i) and (ii) and replace them with the following—
i.  the reserve availability payment margin applying for Peak Trading Intervals, Margin_Peak, which must take account of—
1.   the margin the Electricity Generation Corporation could reasonably have been expected to earn on energy sales forgone due to the supply of Spinning Reserve during Peak Trading Intervals;
2.  the loss in efficiency of the Electricity Generation Corporation Registered Facilities that System Management has scheduled to provide Spinning Reserve during Peak Trading Intervals that could reasonably be expected due to the scheduling of those reserves;

ii.  the reserve availability payment margin applying for Off-Peak Trading Intervals, Margin_Off-Peak, which must take account of—
1.   the margin the Electricity Generation Corporation could reasonably have been expected to earn on energy sales forgone due to the supply of Spinning Reserve during Off-Peak Trading Intervals;
2.  the loss in efficiency of the Electricity Generation Corporation Registered Facilities that System Management has scheduled to provide Spinning Reserve during Off-Peak Trading Intervals that could reasonably be expected due to the scheduling of those reserves;

9. Market Rule 2.24 amended
(1) Delete the comment box following clause 2.24.3(b)(i).

31 March 2006 GOVERNMENT GAZETTE, WA 1375
10. Market Rule 2.28 amended
(1) In clause 2.28.11 delete the word “Contestable” where it appears before “Customers”.
(2) Delete the comment box following clause 2.28.18.
11. Market Rule 2.34 amended
(1) Delete the comment box prior to clause 2.24.3(c).
(2) Delete the existing clause 2.34.8 and replace it with the following—
2.34.8. Other than Standing Data changed in accordance with the processes set out in clauses 6.2A, 6.3C or 6.5C, the IMO must notify the Rule Participant of its acceptance or rejection of the change in Standing Data as soon as practical, and no later than three Business Days after the later of—
(3) Insert new clauses 2.34.14(a)(iA) and (iB) as follows—
iA. Standing Bilateral Submissions;
iB. Standing Resource Plan Submissions;
12. Market Rule 2.35 amended
(1) Delete the comment box immediately following the heading for clause 2.35.
13. Market Rule 2.37 amended
(1) In clause 2.37.8 delete the word “Support” and replace it with “Control” instead.
14. Market Rule 2.38 amended
(1) In clause 2.38.1 delete the word “Support” and replace it with “Control” instead in the two
instances it appears.
15. Market Rule 3.4 amended
(1) Delete the existing clause 3.4.4 and replace it with the following—
3.4.4. System Management may take any other actions as it considers are required, consistent with good electricity industry practice, to return the SWIS to a Normal Operating State provided it acts with as little disruption to electricity supply and to the implementation of Resource Plans that it has received from the IMO as is reasonably practicable in the circumstances.
16. Market Rule 3.9 amended
(1) Delete the existing clause 3.9.2 and replace it with the following—
3.9.2. Spinning Reserve Service is the service of holding capacity associated with a synchronised Scheduled Generator, Dispatchable Load or Interruptible Load in reserve so that the relevant Facility is able to respond appropriately in any of the following situations—

(a)

to retard frequency drops following the failure of one or more Registered Facilities; and

(b)

in the case of Spinning Reserve Service provided by Scheduled Generators and Dispatchable Loads, to supply electricity if the alternative is to trigger involuntary load curtailment.
(c) [Blank]

17. Market Rule 3.11 amended
(1) Delete the existing clause 3.11.7(a) and replace it with the following—
(a) the Electricity Generation Corporation’s Registered Facilities; and
(2) Insert a new clause 3.11.7A as follows—
3.11.7A. The Electricity Generation Corporation must make its capacity to provide Ancillary Services from its facilities available to System Management to a standard sufficient to enable System Management to meet its obligations in accordance with these Market Rules.
(3) Delete the existing clause 3.11.8 and replace it with the following—
3.11.8. System Management may enter into an Ancillary Service Contract with a Rule
Participant other than the Electricity Generation Corporation where—

(a)

it does not consider that it can meet the Ancillary Service Requirements with the Electricity Generation Corporation’s Registered Facilities; or

(b)

the Ancillary Service Contract provides a less expensive alternative to Ancillary Services provided by the Electricity Generation Corporation’s Registered Facilities.

18. Market Rule 3.12 amended
(1) Delete the existing comment box following clause 3.12.1 and replace it with the following—
Chapter 7 is the dispatch chapter.
Clause 7.6 sets out the dispatch criteria, including a requirement to maintain Ancillary
Services, and puts an obligation on System Management to dispatch the Electricity
Generation Corporation’s plant to meet the criteria. Clause 7.6.6 allows Dispatch Instructions
in connection with Ancillary Services contracts that System Management has with other
Market Participants.

1376 GOVERNMENT GAZETTE, WA 31 March 2006
19. Market Rule 3.21A amended
(1) Delete the existing comment box following clause 3.21A.14 and replace it with the following—
Note that the previous clause is relevant primarily to IPP generation as the Electricity
Generation Corporation is effectively settled at MCAP on what it produces anyway.

20. Market Rule 4.3 amended
(1) Delete the existing comment box following clause 4.3.1(d) and replace it with the following—
The above clause is intended to capture the fact that some Capacity Credits for a Reserve Capacity Cycle may have been certified even before the Expression of Interest. Further the Electricity Generation Corporation is required under Market Power Mitigation strategies to use its own generating capacity to cover the capacity requirements of its peak bilateral energy trades during the previous Hot Season on a bilateral basis. Thus while at the time of the Expression of Interest the formal process for notifying of bilateral trades will not have occurred for that Reserve Capacity Cycle, the party conducting the Expression of Interest will know what actions the Market Power Mitigation strategy require.

21. Market Rule 4.11 amended
(1) Delete the existing clause 4.11.3A(d) and associated comment box and replace them with the
following—

(d) set the Relevant Level as double the sum of the quantities determined in (b) and (c) divided by 52,560.
The Certified Reserve Capacity is calculated as the average output (in MW) during each trading interval over the past three complete years. The result in (d) is doubled to convert an average MWh quantity over a half hour Trading Interval to the equivalent MW value. In the event that the Facility has not been in service for three years, the average is calculated based on the actual output for the period when the Facility was in operation and the estimated output for the period before it entered service.

(2) Delete the existing comment box following clause 4.11.5.
22. Market Rule 4.12 amended
(1) Delete the existing clause 4.12.1(a) and replace it with the following—

(a)

a Market Participant (other than the Electricity Generation Corporation) must ensure that for each Trading Interval—
(2) Delete the existing comment box following clause 4.12.1(a)(iii) and replace it with the following
comment box—
Interruptible Loads and Curtailable Loads are treated as a special case. We cannot require these to be included in STEM Offers because that could result in them being activated more times than they are actually available. Instead, we assume that Market Participants will account for them in their STEM bids (for consumption) like they would any other load, and preclude them from appearing in Resource Plans as a way of meeting the load already scheduled (i.e they are treated just like Non-Dispatchable Load). The obligation on an Interruptible Load or Curtailable Load is defined in terms of dropping consumption below a defined level (the Stipulated Default Load), or producing some amount of energy with an embedded generator, and consequently if Market Participant reduces its consumption to this Stipulated Default Load or runs the embedded generator as a result of STEM prices, or other factors, it will still have satisfied its obligations if called for that Trading Interval. However, the fact that these resources are not required to be accounted for in the STEM does not mean they cannot be called in real-time.
This amounts to ensuring that adequate capacity is offered into the STEM and available in real-time. However, since the Bilateral Position is a net position for Market Participants other than the Electricity Generation Corporation, reflecting supply less demand, we cannot refer to the bilateral position plus the STEM offer. Consider a 1000 MW generator with 1000 MW of own load—its net bilateral position could be zero and its STEM offer could be zero, but it is still meeting its obligations if the 1000 MW of generation is in its Resource Plan.

(3) Delete the existing clauses 4.12.1(b) and (c) and replace them with the following—

(b) the Electricity Generation Corporation must ensure that for each Trading Interval—
i. [Blank]
ii. the MW quantity calculated by doubling the total MWh quantity which the Electricity Generation Corporation is selling to other Market Participants as indicated by the applicable Net Contract Position of the Electricity Generation Corporation, corrected for loss factor adjustments so as to be a sent out quantity; plus
iii. the MW quantity calculated by doubling the total MWh quantity covered by STEM Offers which were not scheduled and the STEM Bids which were scheduled in the relevant STEM Auction determined by the IMO for the Electricity Generation Corporation under clause 6.9 for that Trading Interval, corrected for loss factor adjustments so as to be a sent out quantity,

is not less than the total Reserve Capacity Obligation Quantity for the Electricity Generation Corporation for that Trading Interval, less double the total MWh quantity to be provided as Ancillary Services as specified by the IMO for the Electricity Generation Corporation in accordance with clause 6.3A.2(e)(i).

31 March 2006 GOVERNMENT GAZETTE, WA 1377

(c)

the Market Participant must make the capacity associated with the Capacity Credits provided by a Facility applicable to a Trading Interval, up to the Reserve Capacity Obligation Quantity for the Facility for that Trading Interval, available for dispatch by System Management in accordance with Chapter 7.
23. Market Rule 4.14 amended
(1) Delete the existing clause 4.14.4 and comment box and relace them with the following—
4.14.4. The value specified by the Electricity Generation Corporation in accordance with clause
4.14.1(c) must be not less than—
(a) the lesser of—
i. the total Certified Reserve Capacity held by the Electricity Generation Corporation; and
ii. the Electricity Generation Corporation’s peak load, as determined in accordance with clause 4.14.5 multiplied by an amount equal to—

1. the Reserve Capacity Requirement; divided by

2. the expected peak demand corresponding to the Reserve Capacity Requirement, as determined in accordance with clause 4.6.2; less
(b) the Minimum Frequency Keeping Capacity.
The purpose of this clause is to limit the Electricity Generation Corporation’s participation in the Reserve Capacity auction to capacity not required to cover its current own peak bilateral energy trades. Note that if the Electricity Generation Corporation’s peak bilateral energy trade is actually lower in the year in question, then the Electricity Generation Corporation can still be paid the Reserve Capacity Auction price on its surplus capacity, it just will not have been able to offer that capacity into the auction.
While data in Bilateral Submissions is Loss Factor adjusted while Capacity Credits are not, this discrepancy is not considered significant in this context.

(2) Delete the existing clause 4.14.5 and relace it with the following—
4.14.5. For the purpose of clause 4.14.4, the Electricity Generation Corporation’s peak load is calculated by doubling the average of the Electricity Generation Corporation’s supply quantities (expressed in MWh) specified in the Bilateral Submissions that applied during the 12 peak Trading Intervals, as specified in Appendix 5, of the previous Hot Season. Prior to the completion of the first Hot Season following Energy Market Commencement—

(a)

this value will be determined by the IMO and provided to the Electricity Generation Corporation not less than 20 Business Days prior to the date specified in clause 4.1.14.
(b) [Blank]

24. Market Rule 4.16 amended
(1) Delete the existing clause 4.16.4(c) and replace it with the following—
(c) the level of electricity transmission connection costs, including—
i. the cost of electricity transmission assets required to connect an open cycle gas turbine power station to the SWIS; and
ii. an estimate of the cost of augmenting the shared network to facilitate the connection of the open cycle gas turbine power station,

where the IMO may seek a reasonable estimate of this value from the Electricity Network
Corporation;
25. Market Rule 4.20 amended
(1) Insert a new clause 4.20.6 as follows—
4.20.6. For the purpose of this clause 4.20, Capacity Credits associated with Certified Reserve Capacity issued to Western Power in accordance with clause 4.11.7 are to be associated with the generation portfolio the capacity of which contributes to the Certified Reserve Capacity issued under clause 4.11.7 rather than to the individual Facilities comprising that portfolio.
26. Market Rule 4.22 amended
(1) In clause 4.22.3(b) delete the underline in between the words “quarter” and “ending”.
27. Market Rule 4.23A inserted
(1) Insert a new clause 4.23A as follows—

4.
23A. Capacity Credits and Facility Registration (as applicable) may wish to aggregate generating units. This is allowed under the facility registration rules. Capacity Credits and Reserve Capacity Obligation Quantities are only associated with facilities at the time of registration so any facility aggregation can be allowed for.

1378 GOVERNMENT GAZETTE, WA 31 March 2006
4.23A.1. For the first Reserve Capacity Cycle, as facilities are registered, the IMO must convert the Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities that were associated with Western Power’s generation systems in accordance with clauses 4.11, 4.12, and 4.20 into Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities associated with individual Registered Facilities.
4.23A.2. In performing the allocations described in clause 4.23A.1, the IMO must—

(a) ensure that the total Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities of the Registered Facilities equal, respectively, the Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities that were associated with Western Power’s generation systems in accordance with clauses 4.11, 4.12, and 4.20;
(b) where facilities will not be registered as being Electricity Generation Corporation facilities as at Energy Market Commencement, allocate Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities to the Market Participant to whom those facilities are to registered; and
(c) consult with Western Power or the Electricity Generation Corporation (as applicable) and give consideration to Western Power or the Electricity Generation Corporation (as applicable) preferences as to how clause 4.23A.1 should be implemented.

4.23A.3. If at any time a Market Participant holds Capacity Credits with respect to a facility (the “primary facility”) that must be registered as more than one Registered Facility, either as a result of Facility aggregation not being approved by System Management or being revoked, then the IMO may re-allocate the Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities of the primary facility between the primary facility and the Registered Facilities subject to the conditions that—

(a)

the Registered Facilities were documented in the original application for Certified Reserve Capacity as contributing to the capacity covered by those Capacity Credits;

(b)

the IMO must not allocate more Certified Reserve Capacity, Capacity Credits or Reserve Capacity Obligation Quantity to a Registered Facility than that Registered Facility can provide based on information provided in the original application for Certified Reserve Capacity for the primary facility;

(c)

after the re-allocation the total Certified Reserve Capacity, the total number of Capacity Credits and the total Reserve Capacity Obligation Quantities, respectively, of the primary facility and the Registered Facilities must equal the Certified Reserve Capacity, the number of Capacity Credits, and the Reserve Capacity Obligation Quantity original held by the primary facility; and

(d)

the IMO must consult with the applicable Market Participant and give consideration to its preferences in the re-allocations to the extent allowed by (a), (b) and (c).

28. Market Rule 4.24 amended
(1) Delete the comment box following clause 4.24.17.
29. Market Rule 4.25 amended
(1) In the comment box following clause 4.25.2(a) delete the words “Western Power” and replace them
with “the Electricity Generation Corporation”.
(2) Delete the existing comment box following clause 4.25.11(b) and replace it with the following—
The publication of the above information is a means of making System Management’s actions towards Market Participant facilities transparent.

30. Market Rule 4.26 amended
(1) Delete the existing comment box following clause 4.26.1 and replace it with the following—
These refunds can be thought of as a “buy back” requirement whereby the provider of Reserve Capacity buys it back for the period it is not available under a pricing arrangement specified prior to entering into the arrangement. The rules of this section care based on the aggregate quantities provided by participants, not the individual facilities. This is done to avoid problems stemming from the fact that the Electricity Generation Corporation generators may not be metered.
Note that the section on Reserve Capacity obligations includes a process for converting MWh meter data into equivalent MW quantities counted towards covering the obligations.

(2) Delete the existing clause 4.26.2(b) and replace it with the following—

(b)

subject to paragraph (a), for the case where Market Participant p is not the Electricity Generation Corporation, the sum of—
(3) Delete the existing clause 4.26.2(c) and replace it with the following—

(c)

subject to paragraph (a), for the case where Market Participant p is the Electricity Generation Corporation, the sum of—
(4) Delete the existing clause 4.26.2(c)(ii) and replace it with the following—
ii the MW quantity calculated by doubling the total MWh quantity of the Net Contract Position quantity of that Market Participant for Trading Interval t, corrected for Loss Factor adjustments so as to be a sent out quantity in accordance with clause 4.26.2A; plus

31 March 2006 GOVERNMENT GAZETTE, WA 1379
(5) Insert a new clause 4.26.2(c)(iv) as follows—
iv. double the total MWh quantity to be provided as Ancillary Services as specified by the IMO in accordance with clause 6.3A.2(e)(i) for the Electricity Generation Corporation corrected for Loss Factor adjustments so as to be a sent out quantity in accordance with clause 4.26.2A; plus

(6) In the final comment box following clause 4.26.2(c)(iv) delete the final paragraph within the
existing comment box and replace it with the following—
Note that if the Electricity Generation Corporation generators do not have revenue quality meters then this may need to be applied to an estimate of the Electricity Generation Corporation’s total generation. For this reason, penalties are applied based on the overall performance of each Market Participant, rather than on a facility by facility basis.

31. Market Rule 6 amended
(1) Delete the existing comment box prior to clause 6.1, immediately under the heading ‘Energy
Scheduling Timetable and Process’ and replace it with the following—
The energy scheduling process comprises—
Any time (though with restrictions on the time of day).
Standing Balancing Submissions, Standing STEM Submissions, Standing Resource Plans and Standing Balancing Data (i.e. pay-as-bid balancing prices) submitted.
Between a week ahead and a day ahead
Bilateral Submissions, which contain schedules of bilateral contracts, submitted by generators. Standing Bilateral Submissions are used if this data is not provided.
A day ahead
STEM Submissions, from which the IMO determines STEM Bids and STEM Offers given each Market Participant’s Net Bilateral Position. Standing STEM Submissions are used if this data is not provided.
A STEM auction run by the IMO, using STEM Bids and STEM Offers. increases and decreases in energy output stemming from Dispatch Instructions. Standing Balancing Data is used if this data is not provided. Note that Standing Balancing Data is stored with the registration data provided with a facility and is changed through updating the registered value (rather than via changes through the trading system).
Resource Plan Submissions, which detail how the participant will use their generation
facilities to meet their net contract position. Standing Resource Plan Submissions will be
used if this data is not available—however, since these will be validated against the Net
Contract Position on the day, this feature can only realistically be used by Market
Participants with the same schedules every day.

32. Market Rule 6.2 amended
(1) Delete the existing clause 6.2 and replace it with the following—
6.2. Bilateral Submission Timetable and Process

6.2.1. A Market Generator may submit Bilateral Submission data for a Trading Day to the IMO
between—

(a) 8:00 AM of the day seven days prior to the start of the Scheduling Day for the Trading Day; and
(b) 8:50 AM on the Scheduling Day for the Trading Day.
6.2.2. Where the IMO holds a Standing Bilateral Submission for a Market Generator as at the time specified in clause 6.2.1(a), where that Standing Bilateral Submission is applicable to the Trading Day to which clause 6.2.1 relates and where that Standing Bilateral Submission conforms to the requirements of clause 6.7 at that time, the IMO must make it the Bilateral Submission with respect to the Trading Day as at the time specified in clause 6.2.1(a).
6.2.2A. When the IMO receives Bilateral Submission data from a Market Generator during the time interval described in clause 6.2.1, it must as soon as practical communicate to that Market Generator whether or not the IMO accepts the data as conforming to the requirements of clause 6.7. Where the IMO accepts the data then the IMO must revise the Bilateral Submission to reflect that data.
6.2.3. By 8:30 AM on each Scheduling Day the IMO must communicate to each Market Participant a list of the Bilateral Submission quantities associated with that Market Participant for each Trading Interval on the Trading Day, including the party supplying, or being supplied by, the Market Participant., where this information must be based on Bilateral Submissions held by the IMO at a time not earlier than 8:20 AM on the Scheduling Day.
6.2.4. [Blank]
6.2.4A. [Blank]
6.2.4B. A Market Generator may cancel Bilateral Submission data held by the IMO for any
Trading Interval of the Trading Day during the time interval specified in clause 6.2.1.

1380 GOVERNMENT GAZETTE, WA 31 March 2006
6.2.4C. The IMO must confirm to the Market Generator any cancellation of Bilateral Submission data made in accordance with clause 6.2.4B. Where such cancellation is made then the IMO must remove the relevant data from the Bilateral Submission.
6.2.5. [Blank]
6.2.6. [Blank]
6.2.7. By making or revising a Bilateral Submission a Market Participant acknowledges that it
is acting with the permission of all affected Market Participants.
There will be no process for re-submitting information in the event of an error. Instead the submitting Market Participant will have to address any errors under its contract with the other Market Participant(s) involved in its submission.
6.2.8. By 9:00 AM on each Scheduling Day the IMO must communicate to each Market Participant a list of the Bilateral Submission quantities associated with that Market Participant for each Trading Interval on the Trading Day, including the party supplying, or being supplied by, the Market Participant.

33. Market Rule 6.2A inserted
(1) Insert a new clause 6.2A as follows—
6.2A. Standing Bilateral Submission Timetable and Process
6.2A.1. A Market Generator may submit Standing Bilateral Submission data to the IMO on any
day between the times of—
(a) 1:00 PM; and
(b) 3:50 PM,
where if accepted by the IMO the data will apply from the commencement of the
subsequent Scheduling Day.
The window for normal bilateral submissions is open for a week. Since this data becomes active from the opening of the normal bilateral submission, this means that standing bilateral submission data submitted on Monday afternoon will first become available for use as a bilateral submission on the Scheduling Day beginning on Tuesday, but since the window that opens on that day for bilateral submissions relates to the Scheduling Day on Tuesday the following week for the Trading Day on Wednesday of that following Week.

6.2A.2. When the IMO receives Standing Bilateral Submission data from a Market Generator during the time interval described in clause 6.2A.1 it must as soon as practical communicate to that Market Generator whether or not the IMO accepts the data as conforming to the requirements of clause 6.7. Where the IMO accepts the data then the IMO must revise the Standing Bilateral Submission to reflect that data.
6.2A.3. Standing Bilateral Submission data must be associated with a day of the week and when used as Bilateral Submission data will only apply to Trading Days commencing on that day of the week.
6.2A.4. A Market Generator may cancel Standing Bilateral Submission data held by the IMO for any Trading Interval of the Trading Day during the time interval specified in clause 6.2A.1.
6.2A.5. The IMO must confirm to the Market Generator any cancellation of Standing Bilateral Submission data made in accordance with clause 6.2A.4. Where such cancellation is made then the IMO must remove the relevant data from the Standing Bilateral Submission.
34. Market Rule 6.3A amended
(1) Delete the comment box following clause 6.3A.2 and replace it with the following—
The Maximum Supply Capability and Maximum Consumption Capability define the maximum quantity that can be supplied or consumed via Bilateral Contracts and STEM Submissions. The reason for determining the available capacity for each generator in (c) and (d) is so that Market Participants can confirm the factors they must respect when forming their STEM Submissions. Note that if for any reason System Management has not notified the IMO of an outage, then the IMO is just restating Standing Data values.
A Market Participant must not exceed its Maximum Supply Capability or Maximum Consumption Capability in forming STEM Submissions for a Trading Interval. The amount of generation it can offer at the Alternative Maximum STEM Price will be the sum of all the energy from generators described in (c) and the sum of the energy from those generators described in (d) for which the Market Participant makes a Fuel Declaration stating that the facility will be running on Liquid Fuel for the Trading Interval.

35. Market Rule 6.3B amended
(1) Delete the existing clause 6.3B and replace it with the following—
6.3B. STEM Submissions Timetable and Process
STEM Submissions are for the Trading Day that commences at 8:00 AM on the following day.

6.3B.1. A Market Participant may submit STEM Submission data for a Trading Day to the IMO

between—
(a) 9:00 AM on the Scheduling Day; and
(b) 9:50 AM on the Scheduling Day.

31 March 2006 GOVERNMENT GAZETTE, WA 1381
A Market Participant holding Capacity Credits must make daily STEM Submissions (or have a Standing STEM Submission) that covers the obligations of its Capacity Credits.

6.3B.1A. Where the IMO holds a Standing STEM Submission for a Market Participant as at the time specified in clause 6.3B.1(a), where that Standing STEM Submission is applicable to the Trading Day to which clause 6.3B.1 relates and where that Standing STEM Submission conforms to the requirements of clause 6.6 at that time, the IMO must make it the STEM Submission with respect to the Trading Day as at the time specified in clause 6.3B.1(a).
6.3B.2. For the purposes of clauses 6.3B.3(c) the IMO must assess received STEM Submission data against the Reserve Capacity Obligations of the Market Participant that apply at 41°C.
6.3B.3. When the IMO receives STEM Submission data from a Market Participant during the time interval described in clause 6.3B.1 it must as soon as practical communicate to that Market Participant—
(a) [Blank]

(b)

whether or not the IMO accepts the received STEM Submission data as conforming to the requirements of clause 6.6; and

(c)

the extent to which the IMO considers that received STEM Submission data is consistent with the Market Participant’s Reserve Capacity Obligations assessed under clause 6.3B.2;
where, if the IMO accepts the data, the STEM Submission held by the IMO must be
revised to reflect that data.

6.3B.4. [Blank]
6.3B.5. [Blank]
6.3B.6. [Blank]
6.3B.7. [Blank]
6.3B.7A. A Market Participant may cancel STEM Submission data held by the IMO for any
Trading Interval of the Trading Day during the time interval specified in clause 6.3B.1.

6.3B.7B. The IMO must confirm to the Market Participant any cancellation of STEM Submission data made in accordance with clause 6.3B.7A. Where such cancellation is made then the IMO must remove the relevant data from the STEM Submission.
6.3B.8. Where the IMO does not receive a STEM Submission from a Market Participant by the time specified in clause 6.3B.1(b) on the Scheduling Day, which is accepted in accordance with clause 6.3B.3(b) then the IMO must record that no STEM Submission has been made.
36. Market Rule 6.3C amended
(1) Delete the existing clause 6.3C and replace it with the following—

6.
3C. Standing STEM Submission Timetable and Process Scheduling Day (for the Trading Day) that commences at 8:00 AM on the day following the day on which the Standing STEM Submission is accepted by the IMO.
6.3C.1. A Market Participant may submit Standing STEM Submission data to the IMO on any
day between the times of—
(a) 1:00 PM; and
(b) 3:50 PM,
where if accepted by the IMO the data will apply from the commencement of the
subsequent Scheduling Day.

6.3C.2. For the purposes of clauses 6.3C.3(c) the IMO must assess received Standing STEM Submission data against the Reserve Capacity Obligations of the Market Participant that apply at 41°C.
6.3C.3. When the IMO receives Standing STEM Submission data from a Market Participant during the time interval described in clause 6.3C.1 it must as soon as practical communicate to that Market Participant—

(a)

whether or not the IMO accepts received Standing STEM Submission data as conforming to the requirements of clause 6.6; and

(b)

the extent to which the IMO considers that received Standing STEM Submission data is consistent with the Markets Participant’s Reserve Capacity Obligations assessed under clause 6.3C.2 in each Trading Interval of the next seven Trading Days;
where, if the IMO accepts the data, the IMO must revise the Standing STEM Submission
to reflect that data.
A Standing STEM Submission includes seven Trading Days worth of data (where each applies for a different day of the week). Given that a Market Participant’s Reserve Capacity Obligations could be changing over time (due to Planned Outages etc) then the test in (b) is rather crude, but there is little more that can be done. Note that failure to cover Reserve Capacity Obligations will not cause the IMO to reject Standing STEM Submission data. The information provided to Market Participants in (b) is simply to warn them that they may be exposed to Reserve Capacity Refunds.

1382 GOVERNMENT GAZETTE, WA 31 March 2006
6.3C.4. [Blank]
6.3C.5. [Blank]
6.3C.6. [Blank]
6.3C.6A. Standing STEM Submission data must be associated with a day of the week and when used as STEM Submission data will only apply to Trading Days commencing on that day of the week.
6.3C.6B. A Market Participant may cancel Standing STEM Submission data held by the IMO for any Trading Interval of the Trading Day during the time interval specified in clause 6.3C.1.
6.3C.6C. The IMO must confirm to the Market Participant any cancellation of Standing STEM
Submission data made in accordance with clause 6.3C.6B. Where such cancellation is
made then the IMO must remove the relevant data from the Standing STEM Submission.
6.3C.7. [Blank]
6.3C.8. [Blank]

6.3C.9.

If a Market Participant’s ability to consume or supply energy in any Trading Interval of a Trading Day is less than the maximum level of its STEM supply or consumption as indicated by its current Standing STEM Submission then that Market Participant must either—

(a)

submit to the IMO Standing STEM Submission data so as to revise its Standing STEM Submission to comply with this clause 6.3C.9; or

(b)

for each Trading Interval for which the current Standing STEM Submission over- states the Market Participants supply or consumption capabilities, submit valid STEM Submission data to the IMO on the Scheduling Day immediately prior to that Trading Day.
37. Market Rule 6.5 amended
(1) Delete the existing clause 6.5.1 and replace it with the following—
6.5.1. Market Participants other than the Electricity Generation Corporation may submit
Resource Plan Submission data for a Trading Day to the IMO between—
(a) 11:00 AM on the Scheduling Day; and
(b) 12:50 PM on the Scheduling Day.

(2) Insert new clauses 6.5.1A and 6.5.1B as follows—
6.5.1A. Market Participants that are Market Generators or that are Market Customers with Dispatchable Load must provide the IMO with a Resource Plan Submission, either via submitting Resource Plan Submissions or in accordance with clause 6.5.1B.
6.5.1B. Where the IMO holds a Standing Resource Plan Submission for a Market Participant as at the time specified in clause 6.5.1(a) where that Standing Resource Plan Submission is applicable to the Trading Day to which clause 6.5.1 relates then, provided that Standing Resource Plan Submission data is accepted by the IMO in accordance with clause 6.5.2, it becomes the Resource Plan Submission with respect to the Trading Day as at the time specified in clause 6.5.1(a).
(3) Delete the existing clause 6.5.2 and replace it with the following—
6.5.2. When the IMO receives Balancing Data Submission data from a Market Participant during the time interval described in clause 6.5.1 it must as soon as practical communicate to that Market Participant whether or not the IMO accepts the data as conforming to the requirements of clause 6.11A.2. Where the IMO accepts the data then the IMO must revise the Balancing Data Submission to reflect that data.
(a) [Blank]
(b) [Blank]

(4) Delete the existing clause 6.5.3 and replace it with “[Blank]” instead.
(5) Delete the existing clause 6.5.3A and replace it with “[Blank]” instead.
(6) Delete the main paragraph of the existing clause 6.5.4 and comment box and replace them with
the following clause—
6.5.4. If the IMO has not accepted a Resource Plan Submission for a Trading Day by 1 PM on the relevant Scheduling Day from a Market Participant that is required to make a Resource Plan Submission, then it must prepare a default Resource Plan for that Market Participant which must include, for each Trading Interval on the Trading Day—

(7) Delete the existing clause 6.5.5 and replace it with “[Blank]” instead.
38. Market Rule 6.5A amended
(1) Delete the existing clauses 6.5A to 6.5A.5 and replace them with the following—
6.5A. Balancing Data Submission Timetable and Process
A Balancing Data Submission contains pay-as-bid price data to be used in balancing. If no submission is provided then Standing Data will be used. Note that commitment costs are not included in Balancing Data as Appendix 1 requires that supporting evidence be provided for changes to that data. The timelines and processes parallel those for Resource Plan Submissions. Note that the only “Standing Balancing Data” will be the data stored with a Facilities Registration Data—this data will be changed in the same way that a Market Participant would change a ramp rate, rather than being a change made through the trading systems.

31 March 2006 GOVERNMENT GAZETTE, WA 1383
6.5A.1. Market Participants other than the Electricity Generation Corporation that are Market Generators or that are Market Customers with Dispatchable Loads or Curtailable Loads may submit Balancing Data Submission data for a Trading Day to the IMO between—
(a) 11:00 AM on the Scheduling Day; and
(b) 12:50 PM on the Scheduling Day.

6.5A.1A. Where the IMO holds Standing Balancing Data for a Market Participant as at the time specified in clause 6.5A.1(a), where that Standing Balancing Data is applicable to the Trading Day to which clause 6.5A.1 relates and where that Standing Balancing Data conforms to the requirements of clause 6.11A.2, the IMO must make it the Balancing Data Submission with respect to the Trading Day as at the time specified in clause 6.5A.1(a).
6.5A.2. When the IMO receives Balancing Data Submission data from a Market Participant during the time interval described in clause 6.5A.1, or a Balancing Data Submission is derived from Standing Balancing Data in accordance with clause 6.5A.1A, it must as soon as practical communicate to that Market Participant whether or not the IMO accepts the data as conforming to the requirements of clause 6.11A.2. Where the IMO accepts the data then the IMO must revise the Balancing Data Submission to reflect that data.
(a) [Blank]
(b) [Blank]

6.5A.3. [Blank]
6.5A.4. [Blank]
6.5A.5. [Blank]
39. Market Rule 6.5B amended
(1) Delete the existing clause 6.5B and replace it with “[Blank]” instead.
40. Market Rule 6.5C inserted
(1) Insert a new clause 6.5C as follows—

6.
5C. Standing Resource Plan Submission Timetable and Process the Scheduling Day (for the Trading Day) that commences at 8:00 AM on the day following the day on which the Standing Resource Plan Submission is accepted by the IMO.
6.5C.1. A Market Participant may submit Standing Resource Plan Submission data on any day
between the times of—
(a) 1:00 PM; and
(b) 3:50 PM;
where if accepted by the IMO the data will apply from the commencement of the
subsequent Scheduling Day.

6.5C.2. When the IMO receives Standing STEM Resource Plan data from a Market Participant during the time interval described in clause 6.5C.1 it must as soon as practical communicate to that Market Participant whether or not the IMO accepts the received data as conforming to the requirements of clause 6.11.2; and where the IMO accepts the data then the IMO must revise the Standing Resource Plan Submission to reflect that data.
6.5C.3. Standing Resource Plan Submission data must be associated with a day of the week and when used as a Resource Plan Submission will only apply to Trading Days commencing on that day of the week.
6.5C.4. A Market Participant may cancel Standing Resource Plan Submission data held by the IMO for any Trading Interval of the Trading Day during the time interval specified in clause 6.5C.1.
6.5C.5. The IMO must confirm to the Market Participant any cancellation of Standing Resource Plan Submission data made in accordance with clause 6.5C.4. Where such cancellation is made then the IMO must remove the relevant data from the Resource Plan Submission.

6.5C.6. If a Market Participant’s ability to consume or supply energy in any Trading Interval of a Trading Day is less than the maximum level of its supply or consumption as indicated by its Standing Resource Plan Submission then that Market Participant must either—

(a) submit to the IMO Standing Resource Plan Submission data so as to revise its Standing Resource Plan Submission to comply with this clause 6.5C.6; or
(b) for each Trading Interval for which the Standing Resource Plan Submission over- states the Market Participants supply or consumption capabilities, submit valid Resource Plan Submission data to the IMO on the Scheduling Day immediately prior to that Trading Day.
6.5C.7. If on a Scheduling Day at the time described in clause 6.5.1(a), a Market Participant’s Standing Resource Plan Submission applicable to any Trading Interval of the corresponding Trading Day is inconsistent with its Net Contract Position for that Trading Interval then that Market Participant must submit valid Resource Plan Submission data to the IMO for that Trading Interval in accordance with clause 6.5.1.

1384 GOVERNMENT GAZETTE, WA 31 March 2006
41. Market Rule 6.6 amended
(1) Delete the existing clause 6.6.1 and associated comment boxes and replace it with the following—
6.6.1. A Market Participant submitting STEM Submission data or a Standing STEM
Submission data must include in the submission—
(a) the identity of the Market Participant making the submission;
(b) [Blank]

(c) for STEM Submission data, for each Trading Interval included in the submission—
i. a Fuel Declaration;
ii. an Availability Declaration;
iii. if the Market Participant is a provider of Ancillary Services, an Ancillary Service Declaration;
iv a Portfolio Supply Curve; and
v. a Portfolio Demand Curve;

(d) for Standing STEM Submission data, the day of the week to which the submission relates, where data provided for a day of the week relates to the Trading Day commencing on that day, and for each Trading Interval included in the submission—
A Standing STEM Submission can be made for Monday through to Sunday, where data for the Trading Day commencing Tuesday will be used for Trading Days commencing on Tuesdays.
i. a Fuel Declaration;
ii. an Availability Declaration;
iii. if the Market Participant is a provider of Ancillary Services, an Ancillary Service Declaration;
iv. a Portfolio Supply Curve; and
v. a Portfolio Demand Curve.

For a Standing STEM Submission the Availability Declaration and Ancillary Service Declarations still need to be provided, even though this may be prior to outage data being finalised and prior to Ancillary Service requirements being specified. Thus we might expect such values to be conservative (or the Market Participant will have to correct any discrepancies by submitting data on the Scheduling Day).

42. Market Rule 6.7 amended
(1) Delete the existing clause 6.7 and replace it with the following—

6.
Because the energy provided by a generator may be the sum of its own generation plus energy
it purchases under bilateral contract there will be NO process to verify that the quantity
supplied by a party matches its physical capabilities. Instead, the IMO will just test that each
submission balances.
7. Format of Bilateral Submission Data responsibility for this, and the issue must be resolved between the contracting parties.
6.7.1. A Market Generator submitting Bilateral Submission data or Standing Bilateral
Submission data must include in the submission—

(a) the identity of the Market Generator making the submission;
(b) in the case of—
(i) Bilateral Submission data, the Trading Day to which the submission relates; and
(ii) Standing Bilateral Submission data, the day of the week to which the submission relates, where data provided for a day of the week relates to the Trading Day commencing on that day;

A Standing Bilateral Submission can be made for Monday through to Sunday, where data for the Trading Day commencing Tuesday will be used for Trading Days commencing on Tuesdays.
(c) for each Trading Interval included in the submission—
i.   the net quantity of energy to be sold by the submitting Market Generator;
ii.  the identity of each Market Participant purchasing the energy covered by the Bilateral Submission;
iii.   the net quantity of energy sold to each Market Participant identified in (ii); and
iv.   the sum of the quantities in (i) and (iii) must be zero.

(d) [Blank]
In the next clause we define positive numbers to be supply and negative numbers to be consumption. The submission contains quantities for the submitting Market Generator and the other participants it is selling to (or buying from). If Generator A is selling 20 MWh to Retailer B, this will be submitted as Generator A 20 MWh, Retailer B –20 MWh.

31 March 2006 GOVERNMENT GAZETTE, WA 1385

6.7.2. All quantities specified in a Bilateral Submission or a Standing Bilateral Submission—
(a) must be in units of MWh;

(b) must equal or exceed 0 MWh for net supply (that is, sold) by the relevant Market Participant;
(c) must be less than 0 MWh for net consumption (that is, purchased) from relevant Market Participant;
(d) must be expressed to a precision of 0.001 MWh; and
(e) must be Loss Factor adjusted.
The following two clauses do not affect the validation of data provided during the course of submitting Bilateral Submission data. Clause 6.7.4 is included to discourage behaviour whereby a Market Generator over-estimates the load that it is supplying under a bilateral contract so as to displace supply by the Electricity Generation Corporation. See the comment following clause 2.16.2(hA) for further detail.

6.7.3. A Market Generator must not specify quantities in a Bilateral Submission or a Standing Bilateral Submission which exceed the quantity of energy that the Market Generator is contracted to supply to the relevant Market Customer.
6.7.4. A Market Customer must not significantly over-state its consumption as indicated by its Net Contract Position with a regularity that cannot be explained by a reasonable allowance for forecast uncertainty or the impact of Loss Factors.
43. Market Rule 6.11 amended
(1) Delete the existing clause 6.11 and replace it with the following—
6.11. Format of Resource Plans
6.11.1. A Market Participant submitting Resource Plan Submission data or Standing Resource
Plan Submission data must include in the submission—

(a) the identity of the Market Participant making the submission;
(aA) in the case of—
(i) Resource Plan Submission data, the Trading Day to which the submission relates; and
(ii) Standing Resource Plan Submission data, the day of the week to which the submission relates, where data provided for a day of the week relates to the Trading Day commencing on that day;

A Standing Resource Plan Submission can be made for Monday through to Sunday, where data for the Trading Day commencing Tuesday will be used for Trading Days commencing on Tuesdays.

(b)

for each Scheduled Generator and Dispatchable Load registered by the Market Participant—
i. the name of the Facility;
ii. for a Scheduled Generator, the intended times of synchronisation and de- synchronisation, expressed to the nearest minute, during the Trading Day;
iii. the energy to be sent-out or consumed during each Trading Interval of the Trading Day included in the submission, where this amount—

1. must be expressed in units of MWh;

2.   must be expressed to a precision of 0.001 MWh;
3.  must be zero if the Facility is expected not to operate during the Trading Interval; and
4.  must not exceed the expected capability of the Facility at that time, allowing for de-ratings and outages; and

iv. the target megawatt output of each Facility at the end of each Trading Interval included in the submission;
These targets will provide System Management with a basis for issuing Dispatch
Instructions.

(c) for each Non-Scheduled Generator registered by the Market Participant—
i. the name of the Facility;
ii. the expected energy to be sent-out during each Trading Interval of the Trading Day included in the submission, where this amount—

1. must be expressed in units of MWh;

2. must be expressed to a precision of 0.001 MWh; and
3. must not exceed the expected capability of the Facility at that time, allowing for de-ratings and outages;

(d)

the total Loss Factor adjusted demand to be consumed by that Market Participant for each Trading Interval including demand associated with any Curtailable Load or Interruptible Load, but excluding demand associated with any Dispatchable Load; and

1386 GOVERNMENT GAZETTE, WA 31 March 2006
All other data required by the IMO and System Management, such as facility capacities and ramp rates, will be specified in standing data.

(e) any shortfall for each Trading Interval between the net energy scheduled in the Resource Plan Submission and the Net Contract Position of the Market Participant.
Clause (e) is included to allow Market Participants to specify a Resource Plan that covers the required quantity even when they cannot physically do so. This allows the Resource Plan to be accepted and informs the IMO and System Management that a supply limitation exists. However, it does not excuse the submitter from the settlement obligations of the shortage.

6.11.2. For Resource Plan Submission data or Standing Resource Plan Submission data to be

valid—

(a) it must conform to the format specified in clause 6.11.1;

(aA) 48 Trading Intervals of data must be submitted for each Trading Day;
(aB) no energy must be scheduled from a Facility that is a Scheduled Generator for any Trading Interval in which the Facility is not synchronised as indicated by the times specified in clause 6.11.1(b)(ii);

(b) it must only include Facilities registered by the submitting Market Participant;
(bA) it must not include a Scheduled Generator for any Trading Interval if that Scheduled Generator is under going a Commissioning Test during that Trading Interval;

(c) it must not include Interruptible Loads or Curtailable Loads; and
Clause (c) has been added for clarity. To make the determination of Reserve Capacity Obligation compliance simpler, demand side options are automatically counted towards contributing to the Reserve Capacity Obligations without requiring them to be offered into the STEM. Consequently they cannot be individually identified in Resource Plans. However, this does not stop the operator from self-scheduling them as part of their general STEM demand bid. Further, the use of the Stipulated Default Load for measuring compliance of DSM sources (ie, when called demand must drop below some number of MWhs), means that self scheduling the resources does count as meeting the Reserve Capacity Obligations.

(d) the net energy scheduled in the Resource Plan Submission data (or Resource Plan Submission data derived from Standing Resource Plan Submission data), after Loss Factor adjusting the Scheduled Generator, Non-Scheduled Generator, and Dispatchable Load energy, and taking into account shortfalls indicated in accordance with clause 6.11.1(e), for each Trading Interval included in the submission must equal the Net Contract Position of the Market Participant for that Trading Interval.
The test described in (d) is not applied to Standing Resource Plan Submissions at the time they are submitted.

44. Market Rule 6.11A amended
(1) Delete the existing comment box prior to clause 6.11A.1 and replace it with the following—
The Balancing Data allows a market participant to specify different pay-as-bid balancing prices for a day (for changes in energy schedules). Commitment cost data and compensation for decreasing the output of non-scheduled generators are not included in Balancing Data (but can be changed via the normal standing data change process).

(2) Delete the opening sentence for the existing clause 6.11A.1 and replace it with the following—

6.11A.1. A Market Participant submitting Balancing Data Submission data must include in the

submission—

(3) Delete the existing clause 6.11A.2 and replace it with the following—
6.11A.2. For Balancing Data Submission data to be valid—

(a) it must conform to the format specified in clause 6.11A.1; and
(b) it must only include Facilities registered by the submitting Market Participant.

45. Market Rule 6.12 amended
(1) In the comment box under 6.12 and prior to clause 6.12.1 delete the words “Western Power” and
replace them with “the Electricity Generation Corporation”.
(2) In clause 6.12.1(a) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(3) In clause 6.12.1(b)(i) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(4) In clause 6.12.1(c)(i) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(5) In clause 6.12.1(d)(i) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(6) In clause 6.12.1(e)(i) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(7) In clause 6.12.1(f)(i) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(8) In clause 6.12.1(g)(i) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.

31 March 2006 GOVERNMENT GAZETTE, WA 1387
46. Market Rule 6.14 amended
(1) Delete the existing clauses 6.14.4(c) and (d) and replace them with the following—

(c) the “Scheduled System Load” for a Trading Interval is the sum of—
i.  the sum over all Resource Plans for that Trading Interval of the total Loss Factor adjusted generation scheduled in each Resource Plan;
ii.  the sum over all Resource Plans of the shortfall quantity for that Trading Interval as described in clause 6.11.1(e); and
iii.  the Net Contract Position of the Electricity Generation Corporation for that Trading Interval.

(d) the “Relevant Quantity” equals—
i.   the Operational System Load Estimate for the Trading Interval; plus
ii.  IMO’s estimate of the total MWh demand curtailed during that Trading Interval (if any); plus
iii.  the IMO’s estimate of the amount by which energy provided by Market Generators other than the Electricity Generation Corporation falls short of the relevant Resource Plan quantities.

47. Market Rule 6.15 amended
(1) In clause 6.15.1 delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(2) In clause 6.15.2(e) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(3) In clause 6.15.2(f) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
48. Market Rule 6.17 amended
(1) Delete the comment box prior to clause 6.17.1.
(2) In the comment box following clause 6.17.1(e) delete the words “Western Power” in the final
paragraph and replace them with “the Electricity Generation Corporation”.
(3) Delete the existing clause 6.17.2 and associated comment box and replace them with the
following—
6.17.2. The Authorised Deviation Quantity, ADQ(p,d,t), for Market Participant p and Trading
Interval t of Trading Day d equals—

(a) the net sum of all the Dispatch Schedules for Trading Interval t for the Registered Facilities registered by Market Participant p and Non-Dispatchable Loads associated with Market Participant p as indicated in Standing Data,
(b) less, the Net Contract Position of Market Participant p in Trading Interval t;
(c) less, the sum over all of Market Participant p’s Facilities of the Balancing Support Contract energy dispatched from them in Trading Interval t as specified by System Management in accordance with clause 7.13(dA);
This describes the deviation of a Market Participant’s energy position from its net bilateral contract position assuming it followed all dispatch instructions. Energy dispatched under Balancing Support Contracts will appear in the Dispatch Schedules in (a) so must be subtracted in (c) to ensure that no additional payment is made for this energy than that allowed under the Balancing Support Contract. The quantity calculated in 6.17.2 is settled at MCAP, although additional payments are also made in clause 6.17.6 where a Market Participant other than the Electricity Generation Corporation has received Dispatch Instructions which have the effect of making the Dispatch Instructions “pay as bid”.

(4) In the comment box following clause 6.17.3 delete the words “Western Power” and replace them
with “the Electricity Generation Corporation”.
(5) In the comment box following clause 6.17.4 delete the words “Western Power” and replace them
with “the Electricity Generation Corporation”.
(6) In clause 6.17.5(a) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(7) In clause 6.17.6(a)(i) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(8) Delete the existing clauses 6.17.6(b)(i) and (ii) and replace them with the following—
i.  if the Dispatch Schedule for the Registered Facility is equal to the quantity indicated in the applicable Resource Plan for the Registered Facility for Trading Interval t and the Balancing Support Contract energy dispatched from the Facility in Trading Interval t as specified by System Management in accordance with clause 7.13(dA) is zero, the amount for the Registered Facility is zero;
ii.   if paragraph (i) does not apply, the amount for the Registered Facility is the product of—
1.  the qualifying quantity for Trading Interval t as calculated in accordance with clause 6.17.8, less the sum of the quantity indicated in the applicable Resource Plan for the Registered Facility for Trading Interval t and the Balancing Support Contract energy

1388 GOVERNMENT GAZETTE, WA 31 March 2006
dispatched from the Facility in Trading Interval t as specified by System Management
in accordance with clause 7.13(dA); and
2. the applicable price as defined by clause 6.17.7 less MCAP for Trading Interval t.

(9) Delete the existing clause 6.17.7(a) and replace it with the following—
6.17.7. For the purpose of clause 6.17.6—

(a)

if the Dispatch Schedule for a Registered Facility for Trading Interval t is greater than the sum of the Resource Plan schedule for the Registered Facility for Trading Interval t and the Balancing Support Contract energy dispatched from the Facility in Trading Interval t as specified by System Management in accordance with clause 7.13(dA), then the applicable price is the Balancing Data price or the price defined in Appendix 1(e)(v) (depending on the context) that was current at the time of Trading Interval t for the Registered Facility, based on Fuel Declarations as modified by data provided by System Management in accordance with clause 7.13.1(eA), for an increase in generation or decrease in consumption, accounting for—

49. Market Rule 6.18 amended
(1) In clause 6.18.1 delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(2) In clause 6.18.3(a) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
50. Market Rule 7 amended
(1) Delete the existing comment box following Chapter 7 heading and replace it with the following—
A summary of the dispatch obligations— to enter into Balancing Support Contracts with non-Electricity Generation Corporation generators to assist the Electricity Generation Corporation’s plant to provide the balancing service, and System Management can call on these facilities as if they were part of the Electricity Generation Corporation’s portfolio of plant. Also System Management can call on other Market Participant’s generation facilities if it would otherwise have to use Liquid Fuelled plant.
Market Participants other than the Electricity Generation Corporation must follow their
accepted Resource Plans unless they are superseded by Dispatch Instructions issued by
System Management. If Dispatch Instructions are issued, these Market Participants must
follow the Dispatch Instructions.
System Management must schedule the Registered Facilities of the Electricity Generation
Corporation to accommodate the accepted Resource Plans of the other Market Participants,
subject to the Reliability and Security criteria set out in clause 7.7.1.
Where System Management cannot schedule the Registered Facilities of the Electricity
Generation Corporation to accommodate the accepted Resource Plans of the other Market
Participants it must issue Dispatch Instructions to those Market Participants, using the
Dispatch Merit Orders provided by the IMO and relevant information on response times of
generators etc.

51. Market Rule 7.5 amended
(1) In clause 7.5.3 delete the word “Week” and replace it with “Day”.
(2) In clause 7.5.4 delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
52. Market Rule 7.6 amended
(1) Delete the main paragraphs of the existing clauses 7.6.1 and 7.6.2 and the associated comment box
and replace them with the following—
7.6.1. When scheduling and dispatching the Registered Facilities of the Electricity Generation Corporation and issuing Dispatch Instructions to other Market Participants, System Management must seek to meet the following criteria, in descending order of priority—
7.6.2. Subject to clauses 7.6.1, 7.6.2A, 7.6.3, 7.6.4, 7.6.6, System Management must schedule and dispatch the Registered Facilities of the Electricity Generation Corporation and Registered Facilities covered by any Balancing Support Contract or Ancillary Service Contract in such a way as to allow the implementation of the Resource Plans that it has received from the IMO for Market Participants other than the Electricity Generation Corporation.
Hence System Management must dispatch the Electricity Generation Corporation facilities must operate their Registered Facilities in accordance with their Resource Plans unless and until these are superseded by Dispatch Instructions issued by System Management.
around the IPPs’ schedules, meeting any residual load.

(2) Insert a new clause 7.6.2A as follows—
7.6.2A. Where the Dispatch Criteria requires System Management to alter the Dispatch Plan of
the Electricity Generation Corporation, subject to the limitations imposed by this clause
7.6, System Management must employ reasonable endeavours to minimise the change in

31 March 2006 GOVERNMENT GAZETTE, WA 1389
the Dispatch Plan and to have regard for the merit order of Electricity Generation
Corporation Facilities.

(3) Delete the existing clause 7.6.3 and the comment box following and replace them with the
following—
7.6.3. Where meeting the criteria in clause 7.6.1 would otherwise require the use of Liquid Fuelled Registered Facilities of the Electricity Generation Corporation or Liquid Fuelled Registered Facilities covered by any Balancing Support Contract, or Ancillary Service Contract, then System Management may issue Dispatch Instructions to Market Participants other than the Electricity Generation Corporation that, if followed, will allow it to meet the criteria in clause 7.6.1, provided that in issuing such Dispatch Instructions System Management does not issue Dispatch Instructions with respect to a Facility that would result in that Facility using Liquid Fuel.
So the order is Electricity Generation Corporation non-liquid, then IPP non-liquid, then
Electricity Generation Corporation liquid…

(4) Delete the existing clause 7.6.4 and replace it with the following—
7.6.4. Where System Management cannot meet the criteria in clause 7.6.1 by scheduling and dispatching the Registered Facilities of the Electricity Generation Corporation and Registered Facilities covered by any Balancing Support Contract, or Ancillary Service Contract in such a way as to allow the implementation of the Resource Plans that it has received from the IMO for Market Participants other than the Electricity Generation Corporation, System Management must issue Dispatch Instructions to Market Participants other than the Electricity Generation Corporation that will allow it to meet the criteria in clause 7.6.1.

(5) Delete the existing clause 7.6.6 and comment box and replace them with the following—

7.6.6. System Management may issue Dispatch Instructions to Market Participants other than
the Electricity Generation Corporation—
(a) in accordance with any Ancillary Service Contract;
(b) in accordance with any Balancing Support Contract;
(c) in accordance with any Network Control Service Contract;

(d) in connection with any test of equipment allowed under these Market Rules; or
(e) under clause 7.6.3 or clause 7.6.4.
Ancillary Services contracts between System Management and an IPP might specify rules by which the contracted IPP schedules their facilities appropriately at the time of submission of Resource Plans. Alternatively, System Management can issue a Dispatch Instruction in real- time to achieve the same result. However, the Dispatch Instruction will be settled like any other Dispatch Instruction in the market, so this will need to be recognised in the Ancillary Services contract, which may specify additional payments between the System Management and the IPP, outside of the market

(6) Delete the existing clause 7.6.7 and replace it with the following—
7.6.7. System Management and the Electricity Generation Corporation may each enter into
Balancing Support Contracts with Market Participants other than the Electricity
Generation Corporation to assist them in meeting their obligations under this Chapter 7.
(7) Delete the existing clause 7.6.12 and its associated comment box and replace them with the
following—
7.6.12. System Management may give a direction to a Market Participant (other than the Electricity Generation Corporation) in respect of a Scheduled Generator or Non- Scheduled Generator registered by the Market Participant with regard to the reactive power output of that Facility in accordance with any power factor required under the Technical Rules applying to the relevant Network.
System Management can already issue such instructions to the Electricity Generation
Corporation facilities under clause 7.6.2.

(8) Delete the existing clause 7.6.13 and replace it with the following—
7.6.13. System Management must document in the Power System Operation Procedure the procedure to be followed, and must follow that documented Market Procedure, when scheduling and dispatching Registered Facilities covered by any Balancing Support Contract or Ancillary Service Contract in a form sufficient for audits and investigations under these Market Rules.
53. Market Rule 7.6A inserted
(1) Insert a new heading and new clause 7.6A as follows—
7.6A. Scheduling and Dispatch of the Electricity Generation Corporation
7.6A.1. This clause 7.6A describes the rules governing the relationship between System Management and the Electricity Generation Corporation for the purpose of scheduling and dispatching the Registered Facilities of the Electricity Generation Corporation.

1390 GOVERNMENT GAZETTE, WA 31 March 2006

7.6A.2. With respect to the scheduling of the Electricity Generation Corporation Facilities

(a) At least once every month, the Electricity Generation Corporation must provide to System Management the following information in regard to the subsequent month—
i.  A plant schedule describing the merit order in which the Facilities are to be called upon and any restrictions on the operations of such Facilities;
ii.  A plan for which fuels will be used in each Facility and guidance as to how that plan might be varied depending on circumstance; and
iii.   A description as to how Ancillary Services are to be provided;

where the format and time resolution of this data is to be described in a procedure.

(b) System Management must provide to the Electricity Generation Corporation by 8:30 AM on the Scheduling Day associated with a Trading Day a forecast of total system demand for the Trading Day where the format and time resolution of this data is to be described in a procedure.
(c) System Management must provide to the Electricity Generation Corporation by 12:30 PM on the Scheduling Day associated with a Trading Day—
i.  a forecast of the requirements for the Electricity Generation Corporation energy, being a forecast of the whole of system energy requirement less the aggregate Net Contract Positions of other Market Participants, for the Trading Day;
ii.   the Dispatch Plan for each Facility for the Trading Day;
iii.   a forecast of the detailed Ancillary Services required from each Facility;
where the format and time resolution of this data is to be described in a procedure.

(d)

System Management must consult with the Electricity Generation Corporation in developing the information described in (c) and the Electricity Generation Corporation must provide System Management with any information required by System Management in accordance with a procedure to support the preparation of the information in (c). In the event of any failure by the Electricity Generation Corporation to provide information required by System Management in a timely fashion then System Management may use its reasonable judgement to substitute its own information.

(e)

By 2:30 PM on the Scheduling Day associated with a Trading Day System Management must either confirm the Dispatch Plan specified in (c) with the Electricity Generation Corporation or notify the Electricity Generation Corporation of changes to the Dispatch Plan and forecast fuel requirement to reflect any changes required to accommodate Resource Plans or any changes in conditions.

(f)

If after 2:30 PM on the Scheduling Day but prior to the start of a Trading Interval on the corresponding Trading Day, System Management becomes aware of a change in conditions which will require a significant change in the Dispatch Plan it may make such change but must notify the Electricity Generation Corporation of such change.

(g)

The Electricity Generation Corporation must notify System Management as soon as practicable if it becomes aware that is unable to comply with a Dispatch Plan, providing reasons as to why it cannot comply.

7.6A.3. With respect to the dispatch of Electricity Generation Corporation Facilities during a

Trading Day—

(a)

System Management may instruct Facilities to deviate from the Dispatch Plan, or to change their commitment or output, in accordance with the Dispatch Criteria or in response to System Management’s powers under a High Risk Operating State or an Emergency Operating State; and

(b)

System Management must provide adequate notice to the Electricity Generation Corporation, based on Standing Data, before a Facility is required to respond to an instruction given under (a).

(c)

The Electricity Generation Corporation must notify System Management as soon as practicable if it becomes aware that is unable to comply with an instruction given under (a).

7.6A.4. With respect to the dispatch compliance of the Electricity Generation Corporation—

(a)

System Management may deem the Electricity Generation Corporation to be in non- compliance for a Trading Interval if the Electricity Generation Corporation fails to comply with the Dispatch Plan, its obligations to provide Ancillary Services, or an instruction given under clause 7.6A.3(a), to an extent that could endanger Power System Security;

(b)

In determining whether or not to deem the Electricity Generation Corporation to be in non-compliance, System Management must give due regard to any reasonable mitigating circumstances of which the Electricity Generation Corporation has notified it in accordance with clause 7.6A.3(c);

(c)

In determining whether or not to deem the Electricity Generation Corporation to be in non-compliance, System Management may only consider a deviation by an individual Electricity Generation Corporation facility from an output level specified in any instruction from System Management to be non-compliance if the deviation at any time exceeds 10 MW; and

31 March 2006 GOVERNMENT GAZETTE, WA 1391

(d)

In the event that System Management deems the Electricity Generation Corporation to be in non-compliance for a Trading Interval then System Management must determine a single MWh quantity describing the total non-compliance of the Electricity Generation Corporation for that Trading Interval.

7.6A.5. With respect to administration and reporting—

(a) Representatives of System Management and the Electricity Generation Corporation must meet at least once per month to review the procedures operating under this clause 7.6A. The minutes of these meetings must be recorded by System Management;
(b) At the meetings described in (a), System Management and the Electricity Generation Corporation must use best endeavours to address any issues arising from the application of the procedures operating under this clause 7.6A. Where agreement cannot be reached either party may seek arbitration by the IMO.
(c) System Management must report to the IMO any instance where it believes that the Electricity Generation Corporation has failed to meet is obligations under this clause 7.6A.
(d) The Electricity Generation Corporation may report to the IMO any instance where it believes that System Management has failed to meet is obligations under this clause 7.6A.
(e) Upon request by the IMO, the Electricity Generation Corporation and System Management must make available to the IMO records created because of the operation of this clause 7.6A and procedures required by this clause 7.6A.

7.6A.6. The Electricity Generation Corporation and System Management must retain all records, including meeting minutes, created because of the operation of this clause 7.6A and procedures required by this clause 7.6A.
7.6A.7. Subject to clause 7.6A.8, System Management must document the procedures System Management and the Electricity Generation Corporation must follow to comply with this clause 7.6A, including the process to follow in developing the confidential procedure described in clause 7.6A.8, in the Power System Operation Procedure, and System Management and the Electricity Generation Corporation must follow that documented Market Procedure.
7.6A.8. Any procedure created or data exchanged in accordance with this clause 7.6A which is commercially sensitive information of the Electricity Generation Corporation must not be included in the Power System Operation Procedure. Instead, such information must be included in a confidential procedure developed by System Management in consultation with the Electricity Generation Corporation.
7.6A.9. System Management must obtain the approval of the IMO prior to the confidential procedure described in clause 7.6A.8, or any amendments to that private procedure, being enacted.
7.6A.10. The IMO may only decline to approve the confidential procedure, or an amendment to that procedure, if that document is inconsistent with the Market Rules or the market objectives or if it contains material which, in the reasonable view of the IMO, should be in the Power System Operation Procedure.
Clause 10.8.2 defines almost all Electricity Generation Corporation data in this section to be Rule Participant Dispatch Restricted Information which means it can only be seen by the Electricity Generation Corporation, System Management, the IMO, and regulatory/government agencies. The only exception is declarations by the Electricity Generation Corporation that it cannot comply with schedules/instructions (which cannot be confidential if the market is to have some degree of transparency in understanding events on the power system).
Note that there are no provisions for the Rule Participant Dispatch Restricted Information of this section to ever become public. However, Dispatch Schedules, which are currently Rule Participant Restricted, are eventually made public.

54. Market Rule 7.7 amended
(1) In clause 7.7.1 delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(2) In the comment box following clause 7.7.2 delete the words “Western Power” and replace them
with “the Electricity Generation Corporation”.
55. Market Rule 7.9 amended
(1) In clause 7.9.1 delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(2) In clause 7.9.5 delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
56. Market Rule 7.10 amended
(1) In clause 7.10.1 delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(2) In clause 7.10.5(b) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.

1392 GOVERNMENT GAZETTE, WA 31 March 2006
(3) In clause 7.10.7(b)(iii) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(4) In the comment box following clause 7.10.7(b)(iv) delete the words “Western Power” and replace
them with “the Electricity Generation Corporation”.
57. Market Rule 7.13 amended
(1) Insert a new clause 7.13.1(cC) as follows—

(cC) the MWh quantity of non-compliance by the Electricity Generation Corporation by Trading

Interval;

(2) Delete the existing clause 7.13.1(d)(v) and replace it with the following—
v. any failure of an Electricity Generation Corporation Facility to follow the scheduling and dispatch procedures relating to clause 7.6A;

(3) Insert a new clause 7.13.1(dA) and comment box as follows—
(dA) The MWh energy dispatched under a Balancing Support Contract for each Trading Interval in the Trading Day by Facility;
This must be an amount of energy dispatched by System Management. It does not include energy that was called under a Balancing Support Contract but which was scheduled via a Resource Plan. The distinction is that the information in (dA) is used in the calculation of balancing payments to ensure that no payment is made for this energy since it is funded under a contract. No such adjustment is required for energy included in a Resource Plan because that is not exposed to balancing payments.

58. Market Rule 8 amended
(1) In the comment box following Chapter 8 heading delete the words “Western Power” and replace
them with “the Electricity Network Corporation” in the two instances they appear.
(2) In clause 8.1.4 delete the words “Network business unit of Western Power” and replace them with
“the Electricity Network Corporation” in the two instances they appear.
59. Market Rule 9.3 amended
(1) In clause 9.3.4A delete the words “Retail business unit of Western Power” and replace them with
“the Electricity Retail Corporation”.
60. Market Rule 9.9 amended
(1) Delete the existing clause 9.9.1 and associated comment box and replace them with the following—
9.9.1. The Ancillary Service settlement amount for Market Participant p for Trading Month m
is—

ASSA(p,m) = Electricity Generation Corporation AS Provider Payment(p,m)
+ d(p,i) × ASP_Payment(i,m)
– Load_Following_Share(p,m)
× (Capacity_LF(m) + Availability_Cost_LF(m))
– Reserve_Cost_Share(p,m)
– Consumption_Share(p,m) × Cost_LRD(m)
Where
the Electricity Generation Corporation AS Provider Payment(p,m) =
0 if Market Participant p is not the Electricity Generation Corporation
and
(Availability_Cost_R(m) + Availability_Cost_LF(m) + Cost_LRD(m))
– Sum(i∈I, ASP_Payment(i,m)) otherwise.

The payment for Ancillary Services to the Electricity Generation Corporation does not include the capacity components of the Ancillary Service costs, since the Reserve Capacity payment has already covered these costs. Note that users of the Load Following service pay the full cost, including capacity costs. Market Customers paying for Reserve Capacity receive a rebate on their Reserve Capacity payments equal to the amount paid by the users of the Load Following service. This means that the IMO does not collect the money twice. Users of Spinning Reserve only pay the Availability Cost for these services, with Market Customers fully funding the capacity costs of these services.
The total payment to the Electricity Generation Corporation for the provision of Ancillary Services is just the total costs of the relevant services, less the payments made by System Management under Ancillary Service Contracts.

(2) Delete the existing comment box following clause 9.9.2 and replace it with the following—
The Availability Cost is an estimate of the opportunity cost of holding capacity out of the schedule to supply Spinning Reserve and Load Following capability. It is based on the capacity required to be procured from the Electricity Generation Corporation. For a peak Trading Interval this is the system requirement, Capacity_R_Peak less the Trading Interval quantity of capacity provided under Ancillary Service Contracts. Similar terms apply for off- peak Trading Intervals. The Margin_Peak and Margin_Off-Peak terms are applied to give a return on the capacity provided by the Electricity Generation Corporation. The factor of 0.5 is required to convert MW quantities to equivalent Trading Interval MWh quantities.

31 March 2006 GOVERNMENT GAZETTE, WA 1393
61. Market Rule 9.10A inserted
(1) Insert a new clause 9.10A titled “Non-Compliance Charge” as follows—
9.10A. Non-Compliance Charge
9.10A.1. The Non-Compliance Charge settlement amount for Market Participant p for Trading
Interval t of Trading Day d is—
If Market Participant p is the Electricity Generation Corporation
NCC(p,m) = – Sum(d∈ D, t ∈ T, CP(d,t) × ABS[NCQ(p,d,t)]
Otherwise
NCC(p,m) = 0
Where
CP(d,t), is the non-compliance cost applicable in Trading Interval t of Trading Day refer to a member of that set.
d as specified in clause 9.10A.2;
NCQ(p,d,t) is the MWh quantity of non-compliance for Market Participant p for
Trading Interval t of Trading Day d as specified by System Management in
accordance with clause 7.13.1(cC);
ABS[NCQ(p,d,t)] means the mathematical absolute value of NCQ(p,d,t);
D denotes the set of Trading Days within Trading Month m, where “d” is used to
refer to a member of that set.

9.10A.2. The value of the non-compliance cost is to equal the Alternative Maximum STEM Price.
62. Market Rule 9.11 amended
(1) Delete the existing clause 9.11.1 and replace it with the following—

9.11.1. The Reconciliation Settlement amount for Market Participant p for Trading Month m is—
RSA(p,m) = (-1) × Consumption_Share(p,m) × Sum(q∈P,d∈D,t∈T,BSA(q,d,t) +
NCC(q,d,t))
Where
Consumption_Share(p,m) is the proportion of consumption associated with Market Participant p for Trading Month m determined by the IMO in accordance with clause 9.3.7;
BSA(q,d,t) is the Balancing Settlement Amount for Market Participant q for of that set.
Trading Day d and Trading Interval t;
NCC(q,d,t) is the Non-Compliance Charge settlement amount for Market
Participant q for Trading Day d and Trading Interval t;
P is the set of all Market Participants, where “p” and “q” are both used to refer to a
member of that set;
D is the set of all Trading Days in Trading Month m, where “d” is used to refer to a
member of that set; and

63. Market Rule 9.16 amended
(1) Delete the clause 9.16.2(g) and insert “[Blank]” instead.
64. Market Rule 9.17 amended
(1) In clause 9.17.2(a) delete the word “Week” and replace it with “Day” instead.
(2) In clause 9.17.2(c) delete the word “Week” and replace it with “Day” instead.
(3) In clause 9.17.2(d) delete the word “Week” and replace it with “Day” instead.
(4) In clause 9.17.2(g) insert the word “and” after the semi colon at the end of the clause.
(5) Delete the existing clause 9.17.2(h) and insert “[Blank]” instead.
65. Market Rule 9.18 amended
(1) Insert a new clause 9.18.3(c)(iiA) as follows—

ii(A). the MWh quantity of energy scheduled from each of the Market Participants Facilities;
(2) In clause 9.18.3(c)(vi) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation” in the two instances they appear.
(3) In the comment box following clause 9.18.3(c)(vii) delete the words “Retail business unit of
Western Power” and replace them with “the Electricity Retail Corporation”.
(4) Insert a new clause 9.18.3(c)(viiiA) as follows—
viii(A). in the case of the Electricity Generation Corporation the MWh quantity of non-
compliance;

(5) Insert a new clause 9.18.3(c)(ix)(4A) as follows—
4A. Non-Compliance Cost settlement;

1394 GOVERNMENT GAZETTE, WA 31 March 2006
66. Market Rule 9.23 amended
(1) Delete the existing comment box following clause 9.23.4(b) and replace it with the following—
Drawing upon Credit Support will reduce the ability of the Market Participant to trade in the market. The intention is that the Electricity Retail Corporation will be the retailer of last resort.

67. Market Rule 10.5 amended
(1) Delete the existing clause 10.5.1 and replace it with the following—
10.5.1. The IMO must set the class of confidentiality status for the following information under clause 10.2.1, as Public and the IMO must make each item of information available from the Market Web-Site after that item of information becomes available to the IMO—
(2) In clause 10.5.1(h)(i) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(3) In clause 10.5.1(h)(ii) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(4) In clause 10.5.1(h)(iii) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(5) In the comment box following clause 10.5.1(v)(iv) delete the words “Western Power” and replace
them with “the Electricity Generation Corporation”.
(6) Insert new clauses 10.5.1(vA) to (vC) as follows—
(vA) the non-compliance cost described in clause 9.10A.2;
(vB) reports providing the MWh of non-compliance of the Electricity Generation Corporation by Trading Interval, as specified by System Management in accordance with clause 7.13.1(cC), for each Trading Month which has been settled;
(vC) reports providing the MWh quantities of energy dispatched under Balancing Support Contracts by Facility and Trading Interval, as specified by System Management in accordance with clause 7.13.1(dA), for each Trading Month which has been settled;
68. Market Rule 10.8 amended
(1) Insert a new clause 10.8.2 and comment box as follows—
10.8.2. The IMO must set the class of confidentiality status for all Electricity Generation Corporation information specified in clauses 7.6A as Rule Participant Dispatch Restricted Information with the exception of information specified by the Electricity Generation Corporation under clauses 7.6A.2(g) and 7.6A.3(c).
Clauses 7.6A.2(g) and 7.6A.3(c) relate to declarations by the Electricity Generation Corporation that it cannot comply with its schedules. This information should not be required by the rules to be confidential, though the rules leave the IMO the ability to set the confidentiality status.

69. Glossary definitions amended
(1) Delete the existing definitions for the terms below from the glossary—
Balancing Support Contract: A contract between System Management and a Market Participant (other than Western Power), entered into pursuant to clause 7.6.7, that allows System Management to call upon the Facilities registered by the relevant Market Participant to assist System Management in meeting its obligations under clause 7.6.2.
Current Access Threshold: From time to time, the quantity of electricity specified in respect of the relevant circumstances by the Minister under clause 93(1) of the Electricity Corporation Act.
Non-Contestable Customer: A person purchasing electrical energy that is not a Contestable
Customer.

Non-Interval Meter Deadline: Has the meaning in clause 9.16.2(g)
(2) Delete the existing definitions for the terms below and insert new definitions as follows—
Authorised Deviation Quantity (ADQ(p,d,t)): For a Market Participant p for a given Trading Interval t, is as calculated under clause 6.17.2
Balancing Data Submission: A submission of Balancing Data to the IMO made in accordance with clause 6.5A.
Balancing Support Contract: A contract between either the Electricity Generation Corporation or System Management and a Market Participant (other than the Electricity Generation Corporation), entered into pursuant to clause 7.6.7, that allows System Management to call upon the Facilities registered by the relevant Market Participant to assist System Management and the Electricity Generation Corporation in meeting their obligations under Chapter 7.
Bilateral Submission: A submission by a Market Generator to the IMO made in accordance with clause 6.2.
Chief Executive Officer: In respect of a Rule Participant other than System Management, the chief executive officer of the relevant Rule Participant, or if that Rule Participant has no chief executive officer, then the individual nominated by the Rule Participant and holding a similar position to that of chief executive officer of the Rule Participant. With respect to System

31 March 2006 GOVERNMENT GAZETTE, WA 1395
Management, the most senior of the persons designated by the Board of the Electricity
Network Corporation as having responsibility for the management of System Management.

Contestable Customer: A person that may purchase electrical energy from any retailer, including the Electricity Retail Corporation.
Dispatch Merit Order: An ordered list of Scheduled Generators and Dispatchable Loads registered by Market Participants, other than the Electricity Generation Corporation, determined by the IMO in accordance with clause 6.12.1, indicating the order in which those Scheduled Generators and Dispatchable Loads should receive Dispatch Instructions from System Management in the circumstances to which the relevant Dispatch Order applies.
Electricity Corporations Act: Electricity Corporations Act 2005 (WA).
Facility Dispatch Tolerance: The quantity by which the Metered Schedule of a Scheduled
Generator registered by a Market Participant other than the Electricity Generation Corporation can deviate from the Dispatch Schedule for that Scheduled Generator before the Upward Deviation Administrative Price (UDAP) or the Downward Deviation Administrative Price (DDAP) will be applied to that deviation in settlement as determined under clause 6.17.9.

Maximum Shutdown Price: The maximum per MW price, determined under clause 6.20.5, that can be used in setting the level of compensation a Market Participant other than the Electricity Generation Corporation requires in response to being requested by System Management to shutdown a Scheduled Generator.
Notional Wholesale Meter: A notional interval meter quantity associated with a Market Customer’s aggregate consumption not metered by Trading Interval. This value will be an estimate produced by the IMO.
Resources Plan Submission: A submission by a Market Participant to the IMO made in accordance with clause 6.5.
Standing Balancing Data: Balancing Data stored by the IMO reflecting the information described in Appendix 1 provided to the IMO in accordance with clause 2.33.3(c)(x) or clause 2.34.
Statement of Corporate Intent: The statement of corporate intent as agreed by the Minister or otherwise deemed to apply by Division 2 of Part 5 of the Electricity Corporations Act.
STEM Settlement Date: The date determined in accordance with clause 9.16.1(b) for settling transactions covered by STEM Settlement Statements.
STEM Submission: A submission by a Market Participant to the IMO made in accordance with
clause 6.3B containing the information set out in, and in the format prescribed by, clause 6.6.
Standing STEM Submission: A submission by a Market Participant to the IMO made in

accordance with clause 6.3C.

Western Power: The body corporate established under the Electricity Corporation Act (1994) as Western Power Corporation.

(3) Insert new definitions as follows in their appropriate alphabetical order as follows—

Customer: Means a person to whom electricity is sold for the purpose of consumption.
Electricity Generation Corporation: Means the body established by section 4(1)(a) of the
Electricity Corporations Act.

Electricity Networks Corporation: Means the body established by section 4(1)(b) of the Electricity Corporations Act.
Electricity Retail Corporation: Means the body established by section 4(1)(c) of the Electricity Corporations Act.
Dispatch Plan: Means the schedule of energy and Ancillary Services to be provided, or to be available to be provided on request, by the Registered Facilities of the Electricity Generation Corporation during a Trading Day, where this schedule may be revised by System Management during the course of the corresponding Scheduling Day and the Trading Day.
Standing Bilateral Submission: A submission by a Market Generator to the IMO made in accordance with clause 6.2A.
Standing Resource Plan: A submission related in Resource Plans by a Market Generator to the IMO made in accordance with clause 6.5C.
70. Appendix 1 amended
(1) Delete the existing comment box following clause 1(b)(x)(4) and replace it with the following—
While the Electricity Generation Corporation and (via Ancillary Service Contracts) System Management are expected to provide all Ancillary Services, data on plant capability may still be required for emergency situations.

(2) In the clause 1(c) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(3) Delete the existing clauses 1(c)(v) and (vi) and replace them with the following—
v.  Standing Balancing Data for Scheduled Generators registered as being capable of running on Non-Liquid Fuel comprising—
1.   a Non-Liquid Supply Increase Price for Peak Trading Intervals;
2.   a Non-Liquid Supply Increase Price for Off-Peak Trading Intervals;

1396 GOVERNMENT GAZETTE, WA 31 March 2006
3. a Non-Liquid Supply Decrease Price for Peak Trading Intervals;
4. a Non-Liquid Supply Decrease Price for Off-Peak Trading Intervals;

where these prices must be not less than the Minimum STEM Price, not more than the Maximum STEM Price, and must be expressed in units of $/MWh to a precision of $0.01/MWh; and
vi. Standing Balancing Data for Scheduled Generators registered as being capable of running on Liquid Fuel comprising—
1. a Liquid Supply Increase Price for Peak Trading Intervals;
2. a Liquid Supply Increase Price for Off-Peak Trading Intervals;

3. a Liquid Supply Decrease Price for Peak Trading Intervals;
4. a Liquid Supply Decrease Price for Off-Peak Trading Intervals;

where these prices must be not less than the Minimum STEM Price, not more than the Alternative Maximum STEM Price, and must be expressed in units of $/MWh to a precision of $0.01/MWh;

(4) In the clause 1(e)(v) delete the words “Western Power” and replace them with “the Electricity
Generation Corporation”.
(5) Delete the existing clause 1(f)(i) and replace it with the following—
i. the connection points at which electricity is delivered to the Market Customer including for supply to Customers;

(6) Delete the existing clause 1(h)(vi) and replace it with the following—
vi. for a facility that is registered to a Market Participant other than the Electricity Generation Corporation, Standing Balancing Data comprising—
1. a Consumption Decrease Price for Peak Trading Intervals; and
2. a Consumption Decrease Price for Off-Peak Trading Intervals;
where these prices must be not less than the Minimum STEM Price, not more than the Alternative Maximum STEM Price, and must be expressed in units of $/MWh to a precision of $0.01/MWh;

(7) Delete the existing clause 1(i)(xA) and replace it with the following—
xA. for a facility that is registered to a Market Participant other than the Electricity Generation Corporation, Standing Balancing Data comprising—
1. a Consumption Increase Price for Peak Trading Intervals;
2. a Consumption Increase Price for Off-Peak Trading Intervals;
3. a Consumption Decrease Price for Peak Trading Intervals; and
4. a Consumption Decrease Price for Off-Peak Trading Intervals;
where these prices must be not less than the Minimum STEM Price, not more than the Alternative Maximum STEM Price, and must be expressed in units of $/MWh to a precision of $0.01/MWh;

71. Appendix 2 amended
(1) Delete the fourth paragraph together with the following bullet points after the comment box under
the title for Appendix 2 and replace it with the following—
For the purpose of determining the Reserve_Share(p,t) values, each applicable facility f has an applicable capacity associated with it for Trading Interval t.

•

If facility f is an Intermittent Generator with an interval meter then this is double the MWh average interval meter reading for the Trading Month containing Trading Interval t.

•

If facility f is a Scheduled Generator with an interval meter then this is double the MWh interval meter reading for Trading Interval t.

•

If facility f is an Electricity Generation Corporation Intermittent Generator without an interval meter then this is double the average monthly MWh sent out generation of that facility based on SCADA data over the Trading Month containing Trading Interval t.

•

If facility f is an Electricity Generation Corporation Scheduled Generator without an interval meter or an unmetered generation system serving Intermittent Load then this is double the MWh sent out generation of that facility based on SCADA data for Trading Interval t.

72. Appendix 3 amended
(1) Delete the existing second paragraph and associated table in Appendix 3 and replace them with
the following—
Appendix 3
The parameter “a” denotes the active Availability Class where “a” can have a value of {1, 2, 3, 4}.
For the purpose of identifying which capacity can be applied to satisfying capacity requirements
the minimum availability of each Availability Class is set to the maximum availability of the next
Availability Class. However the algorithms in this appendix allow capacity from an Availability
Class with high availability to be used in place of capacity from an Availability Class with lower

31 March 2006 GOVERNMENT GAZETTE, WA 1397
availability. The following table indicates the required availability of capacity offered for each
Availability Class—

Availability Class (i.e. Minimum Hours of Maximum Hours of

value of “a”) Availability Per Year Availability Per Year

1 96 All
2 72 96
3 48 72
4 24 48

73. Appendix 4 amended
(1) Amend Appendix 4 by deleting the existing value of CAPCOST[t] (located after the first comment
box) and replacing it with the following—
CAPCOST[t] = (PC[t] × (1 + M) × CAP × (1 + 1.5 D + 0.5×D2))+TC[t]+FFC[t]
74. Appendix 5 amended
(1) Delete the existing comment box following Step 9 in Appendix 5 and replace it with the following—
The first three terms in X(i) reflect the IRCR for Market Customer i associated with meters and intermittent loads . The last two terms are the contribution of new meters.

75. Appendix 7 amended
(1) In the paragraph immediately under the heading for “Appendix 7: Dispatch Schedule Calculation”,
delete the words “Western Power” and replace them with “the Electricity Generation Corporation”.
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1398 GOVERNMENT GAZETTE, WA 31 March 2006
!200600061GG!

(a)	cost data for the Electricity Generation Corporation, including actual fuel costs by Trading Interval;
(b)	System Management’s operational records, including SCADA records, of the level of utilisation and fuel related data for each of the Electricity Generation Corporation’s Registered Facilities by Trading Interval; and
(c)	the terms of Bilateral Contracts entered into by the Electricity Generation Corporation and the Electricity Retail Corporation.

(a)	to retard frequency drops following the failure of one or more Registered Facilities; and
(b)	in the case of Spinning Reserve Service provided by Scheduled Generators and Dispatchable Loads, to supply electricity if the alternative is to trigger involuntary load curtailment.

(a)	it does not consider that it can meet the Ancillary Service Requirements with the Electricity Generation Corporation’s Registered Facilities; or
(b)	the Ancillary Service Contract provides a less expensive alternative to Ancillary Services provided by the Electricity Generation Corporation’s Registered Facilities.

(a)	ensure that the total Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities of the Registered Facilities equal, respectively, the Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities that were associated with Western Power’s generation systems in accordance with clauses 4.11, 4.12, and 4.20;
(b)	where facilities will not be registered as being Electricity Generation Corporation facilities as at Energy Market Commencement, allocate Certified Reserve Capacity, Capacity Credits and Reserve Capacity Obligation Quantities to the Market Participant to whom those facilities are to registered; and
(c)	consult with Western Power or the Electricity Generation Corporation (as applicable) and give consideration to Western Power or the Electricity Generation Corporation (as applicable) preferences as to how clause 4.23A.1 should be implemented.

(a)	the Registered Facilities were documented in the original application for Certified Reserve Capacity as contributing to the capacity covered by those Capacity Credits;
(b)	the IMO must not allocate more Certified Reserve Capacity, Capacity Credits or Reserve Capacity Obligation Quantity to a Registered Facility than that Registered Facility can provide based on information provided in the original application for Certified Reserve Capacity for the primary facility;
(c)	after the re-allocation the total Certified Reserve Capacity, the total number of Capacity Credits and the total Reserve Capacity Obligation Quantities, respectively, of the primary facility and the Registered Facilities must equal the Certified Reserve Capacity, the number of Capacity Credits, and the Reserve Capacity Obligation Quantity original held by the primary facility; and
(d)	the IMO must consult with the applicable Market Participant and give consideration to its preferences in the re-allocations to the extent allowed by (a), (b) and (c).

(b)	whether or not the IMO accepts the received STEM Submission data as conforming to the requirements of clause 6.6; and
(c)	the extent to which the IMO considers that received STEM Submission data is consistent with the Market Participant’s Reserve Capacity Obligations assessed under clause 6.3B.2;

(a)	whether or not the IMO accepts received Standing STEM Submission data as conforming to the requirements of clause 6.6; and
(b)	the extent to which the IMO considers that received Standing STEM Submission data is consistent with the Markets Participant’s Reserve Capacity Obligations assessed under clause 6.3C.2 in each Trading Interval of the next seven Trading Days;

(a)	it must conform to the format specified in clause 6.11.1;
(aA)	48 Trading Intervals of data must be submitted for each Trading Day;

(a)	it must conform to the format specified in clause 6.11A.1; and
(b)	it must only include Facilities registered by the submitting Market Participant.

(a)	the net sum of all the Dispatch Schedules for Trading Interval t for the Registered Facilities registered by Market Participant p and Non-Dispatchable Loads associated with Market Participant p as indicated in Standing Data,
(b)	less, the Net Contract Position of Market Participant p in Trading Interval t;
(c)	less, the sum over all of Market Participant p’s Facilities of the Balancing Support Contract energy dispatched from them in Trading Interval t as specified by System Management in accordance with clause 7.13(dA);

(b)	System Management must provide to the Electricity Generation Corporation by 8:30 AM on the Scheduling Day associated with a Trading Day a forecast of total system demand for the Trading Day where the format and time resolution of this data is to be described in a procedure.
(c)	System Management must provide to the Electricity Generation Corporation by 12:30 PM on the Scheduling Day associated with a Trading Day—

(d)	System Management must consult with the Electricity Generation Corporation in developing the information described in (c) and the Electricity Generation Corporation must provide System Management with any information required by System Management in accordance with a procedure to support the preparation of the information in (c). In the event of any failure by the Electricity Generation Corporation to provide information required by System Management in a timely fashion then System Management may use its reasonable judgement to substitute its own information.
(e)	By 2:30 PM on the Scheduling Day associated with a Trading Day System Management must either confirm the Dispatch Plan specified in (c) with the Electricity Generation Corporation or notify the Electricity Generation Corporation of changes to the Dispatch Plan and forecast fuel requirement to reflect any changes required to accommodate Resource Plans or any changes in conditions.
(f)	If after 2:30 PM on the Scheduling Day but prior to the start of a Trading Interval on the corresponding Trading Day, System Management becomes aware of a change in conditions which will require a significant change in the Dispatch Plan it may make such change but must notify the Electricity Generation Corporation of such change.
(g)	The Electricity Generation Corporation must notify System Management as soon as practicable if it becomes aware that is unable to comply with a Dispatch Plan, providing reasons as to why it cannot comply.

(a)	System Management may instruct Facilities to deviate from the Dispatch Plan, or to change their commitment or output, in accordance with the Dispatch Criteria or in response to System Management’s powers under a High Risk Operating State or an Emergency Operating State; and
(b)	System Management must provide adequate notice to the Electricity Generation Corporation, based on Standing Data, before a Facility is required to respond to an instruction given under (a).
(c)	The Electricity Generation Corporation must notify System Management as soon as practicable if it becomes aware that is unable to comply with an instruction given under (a).
7.6A.4.	With respect to the dispatch compliance of the Electricity Generation Corporation—
(a)	System Management may deem the Electricity Generation Corporation to be in non- compliance for a Trading Interval if the Electricity Generation Corporation fails to comply with the Dispatch Plan, its obligations to provide Ancillary Services, or an instruction given under clause 7.6A.3(a), to an extent that could endanger Power System Security;
(b)	In determining whether or not to deem the Electricity Generation Corporation to be in non-compliance, System Management must give due regard to any reasonable mitigating circumstances of which the Electricity Generation Corporation has notified it in accordance with clause 7.6A.3(c);
(c)	In determining whether or not to deem the Electricity Generation Corporation to be in non-compliance, System Management may only consider a deviation by an individual Electricity Generation Corporation facility from an output level specified in any instruction from System Management to be non-compliance if the deviation at any time exceeds 10 MW; and

(a)	Representatives of System Management and the Electricity Generation Corporation must meet at least once per month to review the procedures operating under this clause 7.6A. The minutes of these meetings must be recorded by System Management;
(b)	At the meetings described in (a), System Management and the Electricity Generation Corporation must use best endeavours to address any issues arising from the application of the procedures operating under this clause 7.6A. Where agreement cannot be reached either party may seek arbitration by the IMO.
(c)	System Management must report to the IMO any instance where it believes that the Electricity Generation Corporation has failed to meet is obligations under this clause 7.6A.
(d)	The Electricity Generation Corporation may report to the IMO any instance where it believes that System Management has failed to meet is obligations under this clause 7.6A.
(e)	Upon request by the IMO, the Electricity Generation Corporation and System Management must make available to the IMO records created because of the operation of this clause 7.6A and procedures required by this clause 7.6A.

ASSA(p,m) =	Electricity Generation Corporation AS Provider Payment(p,m) + d(p,i) × ASP_Payment(i,m) – Load_Following_Share(p,m) × (Capacity_LF(m) + Availability_Cost_LF(m)) – Reserve_Cost_Share(p,m) – Consumption_Share(p,m) × Cost_LRD(m)
Where
the Electricity Generation Corporation AS Provider Payment(p,m) = 0 if Market Participant p is not the Electricity Generation Corporation and (Availability_Cost_R(m) + Availability_Cost_LF(m) + Cost_LRD(m))
– Sum(i∈I, ASP_Payment(i,m)) otherwise.

•	If facility f is an Intermittent Generator with an interval meter then this is double the MWh average interval meter reading for the Trading Month containing Trading Interval t.
•	If facility f is a Scheduled Generator with an interval meter then this is double the MWh interval meter reading for Trading Interval t.
•	If facility f is an Electricity Generation Corporation Intermittent Generator without an interval meter then this is double the average monthly MWh sent out generation of that facility based on SCADA data over the Trading Month containing Trading Interval t.
•	If facility f is an Electricity Generation Corporation Scheduled Generator without an interval meter or an unmetered generation system serving Intermittent Load then this is double the MWh sent out generation of that facility based on SCADA data for Trading Interval t.

value of “a”)	Availability Per Year	Availability Per Year
1	96	All
2	72	96
3	48	72
4	24	48