Queensland Gas Scheme
Electricity Act 1994
Section 135AM
Power Station Accreditation
Application Form
Power Station
Applicant
Important Note
This form must be read in tandem with the guide to completing the
form provided at Appendix A.
Under the Electronic Transactions (Queensland) Act 2001, the
Queensland Gas Scheme Regulatory Team will accept electronic
submission of this document, and will accept the use of electronic
signatures
Form No. 5A - 01
Department of Employment, Economic Development and Innovation
Level 7, 61 Mary Street, Brisbane QLD 4000
PO Box 15216, City East QLD 4002
Telephone +61 7 3227 7048
Facsimile +61 7 3222 2410
Website www.queenslandgasscheme.qld.gov.au
Version 1.4, February 2010
IMPORTANT INFORMATION FOR APPLICANTS
1. This Form is for the use of persons seeking accreditation of a power station or proposed
power station for the purpose of creating Gas Electricity Certificates (GECs) under the
Queensland Gas Scheme (the Scheme).
2. Applicants should read relevant provisions of the Electricity Act 1994 (Chapter 5A, Part 2,
Division 1), subordinate legislation and applicable guidelines and policies on the Department
of Employment, Economic development and Innovation‘s (the Department) Queensland Gas
Scheme website (www.queenslandgasscheme.qld.gov.au). A guide to completing this form is
also provided herein, at Appendix A.
3. In the event of any inconsistency between the text in this form (including the guideline) and the
relevant provisions of the Electricity Act 1994 (the Act) and the Electricity Regulation 2006 (the
Regulation), the Act and Regulation will prevail to the extent of the inconsistency.
Many of the terms used in this Application Form have meanings as defined in the Act.
The guideline at Appendix A indicates terms with a legal meaning by showing the first
use of the term in bold and italics, with the exception of heading styles.
Throughout this form a ‗Distribution‘ network is often referred to, as this is the common term
used within industry to describe supply networks (as defined in the Act) used by licensed
distribution entities to supply electricity.
4. All relevant sections of the Application Form should be completed. Additional pages (including
all supporting material and documentation) should be attached, as necessary. Incomplete
forms will be returned to the applicant.
Supporting data may be provided electronically by either including a disk or CD with your
application or by emailing electronic files to queenslandgasscheme@qld.gov.au. Applicants
should advise in a covering letter if this option is being taken. Electronic files should be
compatible with Microsoft Office products and spreadsheets should be Excel compatible.
The Department reserves the right to request additional information or documentation in
relation to an application for power station accreditation. Processing of an application may
also involve an inspection of the power station or any other premises relating to the application
by Departmental officials or their authorised agents.
5. Any queries regarding the application, should be directed to the Queensland Gas Scheme
Regulatory Team at the Department on (07) 3227 7048.
6. Payment of the prescribed application fee must accompany the application. See Appendix
B for current fees and payment options.
7. Completed applications should be forwarded to:
The Queensland Gas Scheme Regulatory Team
Department of Employment, Economic Development and Innovation
By post: PO Box 15216, City East QLD 4002
In person: Level 7, 61 Mary Street, Brisbane QLD 4000
By email: queenslandgasscheme@qld.gov.au
8. The Department is committed to the ethical management of information collected in the
application and in response to requirements under the relevant legislation. The information
gathered in this process is in accordance with the provisions of the Act and subordinate
legislation and may be used by the Regulator in carrying out its role under the Act. Subject to
the provisions of the Act and other legal requirements, personal information will not be
disclosed to third parties outside the Department, other than those carrying out functions
under the Act, without your consent.
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9. Applicants should be aware that under the Act their name, accreditation code, name of the
accredited power station and its accreditation code and the name of the economic operator of
the power station will be included in the accredited generator register and made available on
the publicly accessible part of the Gas Electricity Certificate (GEC) Registry.
10. While the Department encourages suppliers of information to clearly identify any information
they consider to be confidential, it is important to note that all information collected through the
application and in response to requirements under the Act is subject to the Freedom of
Information Act 1992 and will be retained as required by the Public Records Act 2002 and
other relevant Acts and regulations.
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1. Applicant and Economic Operator
What is the relationship of the applicant to the power station?
Economic operator
Entity / person nominated by the economic operator(s)
Please attach supporting evidence.
1.1. Applicant
Applicant Details
Company Name
ABN
Business Address
Town/Suburb
State Postcode
Telephone
Facsimile
Applicant Contact
Name
Title
Email address
Telephone Direct Mobile
Facsimile
Technical Contact
Name
Title
Email address
Telephone Direct Mobile
Facsimile
GEC Registry - Key User Details
Name
Title
Email address
Telephone Direct Mobile
Facsimile
Physical Location:
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1.2. Economic Operator
Economic Operator Details (if different from, or additional to, Applicant)
Company Name
ABN
Business Address
Town/Suburb
State Postcode
Telephone
Facsimile
Economic Operator Contact
Name
Title
Email address
Telephone Direct Mobile
Facsimile
Physical Location:
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2. Power Station
2.1 Power Station Name
2.2 Power Station Physical Address
GIS Location (if known)
2.3 Accreditation under other schemes
Is the power station accredited or planning to apply for accreditation under any other
emissions/greenhouse schemes in Australia?
Yes Please specify.
No
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2.4 Power Station Owner Details
Is the power station Owner(s):
the Applicant
the Economic Operator
Other Please provide details.
Please provide the following details for each owner of the power station.
Company % Ownership Contact Telehpone Email
Name Name Number Address
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2.5 Power Station Physical Operator Details
Is the power station Physical Operator(s):
the Applicant
the Economic Operator
the Owner
Other Please provide details.
Please provide the following details for each physical operator of the power station (if
not provided previously).
Physical Operator Details
Company Name
ABN
Business Address
Town/Suburb
State Postcode
Telephone
Facsimile
Physical Operator Contact
Name
Title
Email address
Telephone Direct Mobile
Facsimile
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2.6 Power Station Description
Attach a plant layout diagram for the power station identifying its components.
The following information should also be provided in relation to the power station.
(Section 135AB of the Act defines a power station and this definition is provided in the
Guideline.)
1. Description and number of components – both inside and outside the power
station site boundary.
2. Technical details of generating units – eg. Manufacturer, model, nameplate
capacity in MW, year of commissioning and fuel(s) capability.
2.7 Power Station Connection Point and Transmission Zone
(a) Is the power station directly connected to:
a registered transmission network
a registered distribution network
an Isolated Grid
Other Please provide details.
Attach a single line diagram identifying relevant transmission, distribution and other
network connection point(s).
(b) If the power station is connected to the NEM, what is its NEM connection point ID
(as provided by the Australian Energy Market Operator (AEMO))?
Baseline year (1999/2000)
As at date of application
(c) Please indicate the transmission zone that is believed to be applicable to the power
station (if known). Refer to diagram at Section 2.7 of the Guideline.
FN Far North
ROSS Ross
NQ North
CW Central West
GLAD Gladstone
WB Wide Bay
SW South West
MTN Moreton
BULLI Bulli
GCT Gold Coast – Tweed
NNSW Northern NSW
None of the above
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2.8 Power Station Operating Arrangements
(a) Please provide a broad description of how the power station operates.
Please attach any information relevant to answering the questions below.
(b) Is the power station a scheduled generator (as defined in the National Electricity Rules)?
Yes No
(c) Please provide details of power station typical operation.
Peak
Intermediate
Baseload
2-shift
Other Please provide details.
(d) Does the power station operate in co-generation mode?
Yes No
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2.9 Power Station Fuel(s)
Please complete the following table for each generating unit of the power station.
List all fuels used or to be used by the power station and attach fuel specifications.
Generating Nameplate Fuel Date commercial Average % Is the fuel
Unit capacity operation (of the contribution of claimed to be
(MW) fuel) commenced fuel to annual eligible?
or to be generation (yes/no)
commenced
1 a.
b.
2 a.
b.
Note that relevant supporting evidence will be requested by the Regulator
when assessing the Application Form.
As part of the process of accreditation the regulator will determine the
percentage eligible fuel to be applied in calculating eligible gas-fired electricity.
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3. Ancillary and Other Matters
3.1 Measurement Points
Attach a single line diagram identifying all measurement points for import and
export of electricity by the power station, connection point(s) to grids and electricity
delivered to baseline customers.
All connection points relevant to calculation of eligible gas-fired electricity should be
identified, including any relevant internal loads.
The regulator may request information regarding additional measurement points
when processing this application if, for example, there is a need to identify process
use.
(a) Metered electricity.
(i) Please provide meter details.
Diagram Meter ID Manufacturer Model Meter class or
reference (NEM or other) standard
number (i.e. % error)
(ii) Please provide details of meter standard and service providers.
Diagram Meter ID Meter standard Calibration or Meter Data Agent
reference (NEM or other) (NEM, Jurisdiction, Other service date
number as specified)
(iii) Please indicate the meter‘s measurement purpose – tick the relevant box(es).
Diagram Meter ID Export Export Auxiliary Import SO Gen ED for
reference (NEM or other) to to load for Direct Direct
number NEM grid other grid Supply Supply
Customer Customer
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(b) Unmetered electricity.
Please indicate ‗measurement point‘ purpose – tick the relevant box(es) – and attach
proposed measurement methodology/formulas.
Diagram Export Export Auxiliary Import SO Gen ED for Proposed
reference to to load for Direct Direct measurement
number NEM grid other grid Supply Supply methodology
Customer Customer attached?
Yes No
Yes No
Yes No
3.2 Loss Factors
Please provide transmission loss factors ie. marginal loss factors (MLF) or
distribution loss factors (DLF), as relevant, which have been issued by AEMO or a
Network Service Provider for the power station.
Financial Year MLF Issuing DLF Issuing
Authority Authority
Baseline year 1999/2000
Current year
3.3 Baseline Customer Details
Please complete the following table for each baseline customer of the power station.
Customer Customer Address Supply Arrangement Date of commencement of
Name Type supply arrangement
Note that Supply Arrangement (Type A, B or C) is described in the Guideline. Please also
attach relevant single line diagrams for all supplies to customers, if not already provided.
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3.4 Nomination of Methodology for calculating GECs
Eligible gas-fired electricity is to be calculated separately for each baseline customer
of the power station.
(a) Power station with a nameplate capacity greater than 500 kW
The following table should be completed for each baseline customer of the power
station, according to the applicant‘s preferred method for calculating the eligible
gas-fired electricity for the baseline customer.
You may apply to use a direct method only if the customer is supplied under a
direct supply arrangement. Relevant supporting evidence should be attached if
direct methods are nominated. For example, relevant metering points should be
marked on the diagrams provided in response to Section 3.1 or a methodology be
suggested for measuring electricity delivered to the customer(s).
Baseline Customer Name Nominated method
Note that details of available methods (general method, direct method A or direct
method B) are provided in the Guideline.
Note that any baseline for the baseline customer (if not zero) will be calculated using
the same method as that chosen above, although in the case of the baseline formula
the data will relate to the baseline year.
Note that Direct Methods are subject to approval by the Regulator.
(b) Power station with nameplate capacity 500 kW or less
Please provide details of any proposed philosophies/methodologies/formulas,
together with supporting evidence, to calculate eligible gas-fired electricity.
Note that any methodology will be subject to approval by the Regulator.
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(c) Is the information provided in (b) derived from actual data or from
modelling/methodology?
Actual data
Modelling/methodology required
Please provide details of an appropriate contact person should any clarification be
required relating to modelling/methodology.
Business Details
Company Name
ABN
Business Address
Town/Suburb
State Postcode
Telephone
Facsimile
Business Contact
Name
Title
Email address
Telephone Direct Mobile
Facsimile
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3.5 Determining the Baseline for Baseline Customers
The baseline year is subject to approval by the Regulator.
(a) Key Dates
Please complete the following table and provide details of commissioning dates for
the units of the power station.
See definition of ―commissioned‖ in the guideline.
If the power station, or any of the generating units, first started to generate electricity
using eligible fuels during the 1999/2000 financial year please indicate the date of
commercial operation of the power station or unit using eligible fuels.
Power station Commissioned date Commercial Operation date
unit number (using eligible fuels)
(b) Electricity Data – Existing Baseline Customers
The following tables (or you may attach tables in this format) should be completed for
each existing baseline customer of the power station for each calendar year from
1998 to 2001 inclusive, where available. As shown below, the electricity data should
be broken up into monthly sent out/delivered amounts.
Applicants should also provide graphs charting the relevant output. Electricity data
provided in response to this section should be accompanied by written explanations
of drivers behind any clearly identifiable peaks or troughs in the electricity data.
Sent out/delivered electricity should be broken up into peak and off-peak proportions
for at least the 1999-2000 financial year. If a different baseline year is determined to
be appropriate the regulator will subsequently ask the applicant to provide peak and
off-peak data for that year. Refer to the guideline for relevant definitions.
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Notes :
SO Gen and ED are as defined in the Act and are duplicated in the guideline
to this form.
Peak hours = 7am to 10pm on Brisbane working weekdays.
Off-peak hours = all other hours
Energy figures should be net of imports and auxiliary loads.
General Method
Baseline Customer
Year
Month SO Gen % of SO Gen from eligible fuels
(MWh per annum)
All hours Peak Off- All hours Peak Off-
hours peak hours peak
hours hours
January
February
March
April
May
June
July
August
September
October
November
December
Direct Methods
Baseline Customer
Year
Month ED % of ED from eligible fuels
(MWh per annum)
All hours Peak Off- All hours Peak Off-
hours peak hours peak
hours hours
January
February
March
April
May
June
July
August
September
October
November
December
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(c) Is the information provided in (b) derived from actual data or from
modelling/methodology? Note, that metered quantities are preferred.
Actual data
Modelling/methodology required
Please provide details of an appropriate contact person should any clarification be
required relating to modelling/methodology.
Business Details
Company Name
ABN
Business Address
Town/Suburb
State Postcode
Telephone
Facsimile
Business Contact
Name
Title
Email address
Telephone Direct Mobile
Facsimile
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4. Attachments to Application
(Each attachment should be marked clearly with the section to which it relates).
4.1 Applicant and Economic Operator
Proof of the economic operator(s) status; and (question 1)
Where relevant, proof of the nomination by the economic operator(s) of the power
station of another party to be the accredited generator. (question 1).
4.2 Power Station
Plant layout diagram for power station plan (question 2.6);
Single line diagram identifying relevant connection points (question 2.7 (a));
Fuel specifications (question 2.9);
4.3 Ancillary and Other Matters
Single line diagram identifying relevant measurement points (question 3.1);
Proposed philosophy/methodology/formulas for unmetered measurement points
(question 3.1(b));
Supporting evidence of MLFs and DLFs issued by industry authorities (question 3.2);
Supporting evidence of date of commencement of supply arrangement for all
baseline customers (question 3.3);
Supporting evidence of direct supply arrangements and that electricity delivered can
be appropriately measured for nomination of direct methods for baseline customers –
if power station nameplate capacity is greater than 500 kW (question 3.4(a));
Proposed philosophy/methodology/formulas for a proposed methodology to work out
eligible gas-fired electricity – if power station nameplate capacity is less than 500 kW
(question 3.4(b));
Supporting evidence of commissioning/commercial operation dates (question 3.5(a));
Supporting data for SO Gen and ED for existing baseline customers
(question 3.5(b));
Prescribed fee.
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5. Declaration
Before completing this section, please ensure that all relevant sections of the
Application Form are completed and all supporting information is attached as per the
checklist above.
I,
(Applicant‘s Authorised representative)
declare that the information provided in this application is correct to the best of my
knowledge.
I am aware of the requirements under the Electricity Act 1994, including the Regulations
made under that Act, applying to accredited generators and applicants.
I am aware that the applicant‘s company name and accreditation code, the power station
name and accreditation code, and the name of economic operator(s) of the power station as
provided in this application, will be placed in public registers.
I authorise the regulator and the regulator‘s delegates to access meter data to assist with the
accreditation of the power station as provided in this application and for subsequent
validation of any Gas Electricity Certificates created by this power station.
I also acknowledge that there may be penalties applied for providing false or misleading
information in this form and that I am authorised to make this application on behalf of the
power station named on this form.
Name(Applicant) Signature Date
Name(Witness) Signature Date
If the applicant is not the economic operator of the power station, or there is more
than one economic operator, all economic operator(s) must sign this form below as
evidence of their agreement to the applicant candidature and that information
provided in this form is correct to the best of their knowledge.
Name(Economic Operator) Signature Date
Name(Economic Operator) Signature Date
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Appendix A
GUIDELINE FOR APPLICATION FOR POWER STATION ACCREDITATION
(see Section 135AM(1) of the Electricity Act 1994 (the Act) which states the general requirements for
accreditation applications)
1. Applicant and Economic Operator
Refer to Sections 135AC and 135AL of the Act --- “Who is the economic operator of a power
station” and “Who may apply for accreditation”.
1.1 Applicant
Only one person or entity can apply to become the accredited generator for a power station. This
person will be eligible to create Gas Electricity Certificates (GECs) and receive the accreditation
code for that power station. The applicant must be either the economic operator of the power
station or a person nominated by the economic operator. If there is more than one economic
operator, the application must be signed by them jointly.
The economic operator of a power station is:
(a) the person who, under the National Electricity Rules, is registered as the generator for the
power station; or
(b) if no one is registered, or required to be registered, under the Rules as the generator for the
power station—the person who has the physical control of the power station.
Item (b) above, is targeting the party who on a day to day basis runs the power station. Note that (b)
only applies if there is no National Electricity Market (NEM) generator.
Evidence must be provided of the applicant‘s status as an economic operator for the power station. If
the applicant is not an economic operator for the power station, evidence must be provided of
their nomination by the economic operator(s).
Examples of relevant evidence include:
relevant letters/documentation from the Australian Energy Market Operator (AEMO) confirming
the party‘s current registration as the NEM generator for the power station.
relevant letters/extracts from contracts confirming the party‘s existing appointment as operator of
the power station.
a letter to the regulator signed by all economic operators authorising a nominated party (where
applicable) to apply to be the accredited generator for a power station.
This application may also be used for gaining provisional accreditation (see Section 135AP of the Act)
for a proposed power station. In this case, application must be made either by the proposed
economic operator or a person nominated by the proposed economic operator. For simplicity, any
reference to power station or economic operator in this application shall also mean proposed power
station or proposed economic operator.
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GEC Registry – Key User Details
The key user of the Scheme‘s internet based Registry will be able to give user rights to other
individuals in the company and will be the main contact for the Regulator on GEC Registry related
issues.
1.2 Economic Operator
If the applicant is not the economic operator of the power station or there is more than one economic
operator, please provide details for all economic operators of the power station. If necessary, add
tables of similar format. If the applicant at 1.1 is the only economic operator or is one of the economic
operators of the power station (i.e. nominated Economic Operator), the applicant need not re-enter
their details.
2. Power Station
A separate application must be lodged for each power station for which accreditation is sought under
the Scheme. However, the same person/entity may hold more than one (1) accreditation.
2.1 Power Station Name
The name provided should be that used to identify the power station by NEM and/or other
jurisdictional electricity regulators.
2.2 Power Station Physical Address
The power station‘s physical address is requested for identifying the power station and confirming its
existence. The physical address may also include reference to the nearest town or landmark
identifiable on a map of the area, for example, X km SE of Y.
If the power station is embedded in an industrial complex or industrial site please state whether it is
located on a separable portion (eg. lease site) of land.
The GIS (Geographical Information Systems) location will assist to uniquely identify each power
station, particularly those in remote areas connected to small or isolated grids.
2.3 Accreditation under other schemes
In accordance with Section 135DF of the Act, a GEC can not be created for eligible gas-fired
electricity if any certificates have been created under:
the Electricity Supply Act 1995 (NSW) (Part 8) (NSW Greenhouse Gas Abatement Scheme);
a law of the Commonwealth or another State the purposes of which include the promotion of
the reduction of greenhouse gases.
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For this reason, the regulator needs to know about the power station‘s participation or proposed
participation in other schemes.
Other schemes under which the power station may be accredited or seek accreditation include:
(i) the NSW Greenhouse Gas Abatement Scheme;
(ii) any other legislated emission/greenhouse scheme which may be introduced during the life of
the Queensland Gas Scheme, as existing at the time of submission of application for
accreditation.
2.4 Power Station Owner Details
Details should be provided for all owners with controlling interests in the power station. This is for
information purposes only.
2.5 Power Station Physical Operator Details
Details should be provided for all physical operators of the power station, unless provided in previous
sections of the application for accreditation. The ‗physical‘ operator is the party/entity that runs the
power station on a day to day basis.
2.6 Power Station Description
Section 135AB of the Act defines a power station.
Constituent parts may include buildings, components, equipment and infrastructure directly related to
the operation or electricity production as broadly described in Section 135AB(2) of the Act and re-
stated below.
(1) A power station is an electricity generating plant or system.
(2) Power station also includes all buildings, components, equipment and infrastructure of the
plant or system directly related to its operation or to its electricity production, including, for
example, a thing needed:
(a) to store, retrieve, measure, distribute or prepare the fuel or energy source for the plant or
system; or
(b) to combust, convert or otherwise use the fuel or energy source for the plant or system to
generate electricity directly or to energise an intermediate medium; or
Example of an intermediate medium—
steam, produced from the burning of fuel in a boiler, that is used to drive a steam turbine to generate electricity
(c) to convert the energy in an intermediate medium into electricity; or
(d) to control, switch or transform the electricity generated; or
(e) to control the processes involved in the main and auxiliary processes associated with the
electricity generation; or
(f) to control emissions to ensure compliance with a relevant environmental authority under
the Environmental Protection Act 1994 if the thing is directly related to the electricity
generation; or
(g) to do any of the following for a matter or process mentioned in paragraphs (a) to (f):
(i) cooling;
(ii) heating;
(iii) preparing or distributing a fluid or gas to use in, or to control, the matter or process;
(iv) distributing or controlling electricity used;
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(v) metering, recording or transmitting relevant parameters;
(vi) waste disposal or removal; or
(h) to comply with the Workplace Health and Safety Act 1995 or a requirement or standard
under any other Act relating to safety if the thing is directly related to the electricity
generation.
(3) However, a thing mentioned in subsection (2) is not part of the power station if it:
(a) is located more than 1 km from the boundary of the plant or system; or
(b) is only used to:
(i) extract or mine a fuel source for the plant or system; or
(ii) separate or process wastes only part of which form a fuel source for the power
station.
(4) A power station‘s nameplate capacity is the capacity of its main generating unit or units, as
stated by its manufacturer.
Note that sub-section (3) shown above, identifies certain things that will not be considered part of the
power station.
2.7 Power Station Connection Point and Transmission Zone
The location and connection point of a power station will determine the power station‘s Transmission
Zone for the purposes of fixing Queensland Usage Factors (QUFs) (see section 135CO of the Act).
QUFs will apply in calculating baselines and eligible gas-fired electricity and essentially estimate the
proportion of a power station‘s energy output used to support electricity load in Queensland. The
QUFs applied in calculating the baseline will relate to the baseline year. Hence, baseline year and
current year NEM connection point IDs are requested.
(a) A single line diagram should be attached providing details of the grid and power station
connection point(s).
(b) The relevant Transmission Zone for the power station should be indicated where known.
Section 134 of the Electricity Regulation 2006 prescribes Transmission Zones for the purposes of
fixing QUFs. It does this for Queensland by adopting the zones used by Powerlink Queensland from
time to time in its Annual Planning Report. The following transmission zones are current as at
1 January 2005.
The Northern New South Wales zone is prescribed under Section 127A(b) of the
Electricity Regulation 2006 and is described as ―the area of the national electricity market north of the
Hunter Valley at Liddell and Newcastle on the coast through to the border between New South Wales
and Queensland‖.
Where necessary, power stations without a prescribed Transmission Zone may have a zone
prescribed for the purposes of fixing QUFs.
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Barron Gorge FN Far North
FN Kareeya
Koombooloomba ROSS Ross
NQ North
Stanwell ROSS Townsville CW Central West
Barcaldine Mt Stuart
Callide A Invicta GLAD Gladstone
Callide B WB Wide Bay
Callide PP NQ Collinsville
Mackay SW South West
MTN Moreton
Gladstone
CW GLAD
BULLI Bulli
GCT Gold Coast – Tweed
Tarong North NNSW Northern NSW
Tarong SW WB
Roma
Oakey
MTN Wivenhoe
Swanbank B
Swanbank D
Swanbank E
Braemar
Braemar 2
BULLI
Kogan Creek
Darling Downs
Millmerran GCT
QNI
QLD Directlink
NSW NNSW
2.8 Power Station Operating Arrangements
A broad, high-level description of the generation operation is requested.
Examples include:
peak, intermediate or baseload generation operation;
network support;
annual capacity factor;
typical hours of operation;
remote or on-site control/operation;
market/pool or other drivers of generation operation.
2.9 Power Station Fuels
Refer to Section 135AM of the Act – “Requirements for Application”.
Section 135AD of the Act provides the following definition.
(1) An eligible fuel is:
(a) natural gas formed naturally in the earth; or
Examples:
• liquefied natural gas or ‗LNG‘
• compressed natural gas or ‗CNG‘
• gas (commonly called ‗coal seam gas‘) occurring naturally in association with coal and produced as a
resource in its own right
• gas (commonly called ‗waste mine gas‘) occurring naturally in association with coal and—
(a) released during the process of coal mining, either directly or indirectly by disturbance of gas-bearing
strata; or
(b) released before mining for the purpose of safety; or
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(c) drained from underground areas previously mined for coal.
(b) a substance that is:
(i) a by-product of processes carried out at a petroleum refinery; and
(ii) a gas at an absolute pressure of 101.325 kPa and at a temperature of 15ºC; or
(c) a gas not formed naturally in the earth that consists predominately of methane and:
(i) is of the composition, characteristics and quality prescribed, under the Gas (Residual
Provisions) Act 1965, for natural gas as defined under that Act (whether or not the
gas is natural gas as defined under that Act); or
(ii) is of another quality approved under that Act; or
(iii) is of a quality prescribed under a regulation; or
(d) liquefied petroleum gas.
(2) However, eligible fuel does not include an eligible renewable energy source under the
Renewable Energy (Electricity) Act 2000 (Cwlth).
(3) In this section—
petroleum refinery means an organised and coordinated arrangement of manufacturing
processes the primary purpose of which is to separate and purify crude oil for the production
and sale of liquid fuel products.
Note, as per sub-section (2) above, eligible fuels do not include eligible renewable energy sources
under the Commonwealth Government‘s Mandatory Renewable Energy Target scheme.
3. Ancillary and Other Matters
Introduction
In accordance with Section 135AN(1)(g) of the Act, the regulator must decide the ancillary matters
for the power station. In general terms, the ancillary matters include the power station‘s -
a) baseline customers and the baseline for each baseline customer;
b) the annual and baseline loss factor(s);
c) the approved measurement points;
d) the methodology to estimate generation or use where an amount is unmetered.
The approval of measurement points may also be done as part of a measurement method, which
the regulator may approve under Section 135JA of the Act. This section allows the regulator to
approve not only the measurement points, but also measurement arrangements for the meter such as
the tolerance for error or intervals of testing. An approved measurement method may include
approved methodologies to estimate an amount that is unmetered. A measurement method may also
relate to incidental amounts.
It is also necessary to determine the method/formula(s) that will be used to calculate eligible gas-fired
electricity (for GECs) and by association any baseline amounts. This issue is also addressed later in
this section.
3.1 Measurement Points
Attach a line diagram of the metering system with reference to the meters listed in the table.
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Applicants should indicate what meter standard applies to each relevant meter. NEM standard
metering will automatically be accepted for the purposes of approving a measurement method. Other
meter standards will be considered on a case by case basis, however the intent will be to lever off
existing arrangements such as jurisdictional standards etc.
If metering is not installed, suggested methods for calculation of relevant quantities should be
provided for consideration by the Regulator. This may include:
a) a detailed philosophy;
b) a high-level methodology to implement the philosophy;
c) detailed formulas and equations;
Applicants should attempt to provide information to satisfy both (a) and (b) with this application.
The regulator may request information regarding additional measurement points when processing this
application if, for example, there is a need to identify process use.
3.2 Loss Factors
The general intent is that GECs will be created for electricity that supports Queensland load, and not
for electricity that is ‗lost in transit‘. Accordingly, the regulator is required to fix annual and baseline
loss factors for each accredited power station. The annual loss factor is fixed for each financial
year, while the baseline loss factor relates to the baseline year and is used in calculating the
baseline (where this is not zero).
The Act specifically allows the adoption of relevant NEM loss factors and this will be the general
policy. Where NEM loss factors are not available, the regulator will also consider the appropriateness
of adopting loss factors fixed by other industry bodies, such as those fixed by network service
providers. If loss factors do not exist or those existing are not considered appropriate, the regulator
may request relevant data to enable calculation of appropriate loss factors. The regulator may also
request details of additional loss factors or details relevant to their calculation such as those relevant
to the calculation of incidental amounts or private electricity lines.
The Act provides that the loss factor may consist of different components for each grid or network that
the power station supplies electricity through. That is, in general terms, different loss factors will apply
to transmission grids and supply/distribution networks.
Loss factors will be applied to the sent out electricity of an accredited power station.
The most common loss factors applied will include:
• the NEM MLF (Marginal Loss Factor) for the power station. The MLF reflects how a power
station‘s output impacts on the total transmission losses in the State. Power stations can have
the effect of either reducing or increasing the total transmission losses in the State depending on
their location. An MLF of greater than one reflects that a power station is considered to be
reducing transmission losses in the State. An MLF of less than one reflects that a power station
is considered to be increasing transmission losses in the State;
• for embedded power stations, the Network Service Provider issued Distribution Loss Factor
(DLF). The DLF reflects the average network losses at the distribution network connection points
(referenced back to the relevant transmission connection point) where the power station is
located; and
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• a Distribution Network Loss Factor (DNLF). The DNLF reflects the average losses experienced
during transfer of electricity through a main distribution network. Along with other annual Loss
Factors, this will be recalculated for each financial year.
3.3 Baseline Customer Details
Eligible gas-fired electricity will need to be calculated separately against each of the power station‘s
baseline customers, unless all of the baselines for the power station‘s baseline customers are zero.
As alluded to above, a power station‘s baseline will essentially be broken up into one or more
baselines and allocated against the power station‘s identified baseline customers.
(a) Baseline Customers Details
Sections 135AJ and 135AH of the Act define a baseline customer and a direct supply arrangement
respectively. The effect of these sections is that there are essentially three types of arrangements
that would be considered to be baseline customers. These are:
A a customer supplied via a direct supply arrangement (via dedicated line or gas-fired grid)
B AEMO
C a retailer supplying electricity via a direct supply arrangement. This applies if the power
station supplying the retailer is not connected to the national grid and is connected to a gas
fired grid.
In addition, there are two types of baseline customers -
1. Existing Customers to whom the power station supplies electricity generated from
eligible fuels under an arrangement that was in force on 24 May 2000.
Existing baseline customers will have a baseline greater than zero.
2. New Customers who were not a baseline customer of the power station on
24 May 2000.
New baseline customers will have a baseline equal to zero.
Applicants should attach evidence of the commencement date of supply arrangements for all baseline
customers. This will be used in establishing whether a baseline customer is NEW or EXISTING as
detailed above.
3.4. Nomination of Methodology for calculating GECs
Eligible gas-fired electricity is to be calculated separately for each baseline customer of the power
station. It is necessary for the applicant to nominate the methodology that they wish to use to
calculate their eligible gas-fired electricity.
Note that use of a Direct Method (as detailed below) will be subject to regulator approval and
is mandatory once approved.
Also note that in choosing a Direct Method you are agreeing to also use the relevant Direct
Method to calculate the relevant baseline for that baseline customer (see 135CZ of the Act).
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Note that a GEC can be created for each whole megawatt hour of eligible gas-fired electricity that is
not auxiliary load, so sent out and delivered amounts will need to be net of any auxiliary loads that
may be captured in the relevant measurement point.
(a) Power station with a nameplate capacity greater than 500 kW
There are two methods for calculating eligible gas-fired electricity. In summary, the General Method,
as detailed below, is the default method and uses the electricity sent out from the power station. The
Alternate Method, as detailed below, uses the amount of electricity delivered.
The Act refers to the following terms -
SO Gen is the electricity sent out from the power station, less electricity imported into the power
station, measured in MWh.
ED means the electricity delivered to the customer, less electricity imported into the power station
multiplied by any relevant annual loss factor decided by the regulator, measured in MWh.
a) General Method (Section 135CC)
This method generally applies to electricity supplied to baseline customers that are not direct
supply customers.
EE = (SO Gen x % EF x QUF x LF) - BL
When selecting the general method for existing baseline customers, the corresponding
electricity data (at question 3.5 (b)) provided for those customers must represent the amount
of electricity sent out from the power station.
Typically, electricity sent out from the power station will be measured at the point where
exports to the grid are measured for settlement purposes, less any pro-rated imports to the
power station as per the definition of SO Gen.
b) Alternate methods for direct supply arrangement (Section 135CD)
These methods are subject to approval by the Regulator. They may only be applied when
electricity is supplied via a direct supply arrangement.
When selecting the ‗direct methods‘ for existing baseline customers, the corresponding
electricity data (provided at 3.5(b)) provided for those customers must represent the amount
of electricity delivered to the customer.
Typically, electricity delivered would be measured at the delivery meter upon which electricity
consumed by the customer is measured for billing purposes (the ‗billing meter‘), less any pro-
rated imports to the power station as per the definition of ED.
1) direct method A --- if the Regulator does not fix a loss factor for the power station:
EE = (ED x % EF x QUF) - BL
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2) direct method B --- if the Regulator fixes a loss factor for the power station:
EE = (ED x % EF x QUF x LF) - BL
Please attach supporting evidence that electricity delivered to the customer(s) can be
appropriately measured (description of relevant metering points/types, diagrams showing
relevant metering points, or a suggested methodology).
For the purposes of the formulas above:
EE is the eligible gas-fired electricity, measured in MWh.
SO Gen is electricity sent out from the power station, less electricity imported into the power
station, measured in MWh.
ED means the electricity delivered to the person mentioned in subsection (1), less electricity
imported into the power station multiplied by any relevant annual loss factor decided by the
regulator, measured in MWh.
% EF is the proportion of electricity generated from an eligible fuel.
QUF is the power station‘s annual QUF.
LF is the power station‘s annual loss factor.
BL is the baseline for the baseline customer of the power station.
On-site Generation
For sites where electricity is generated and used on-site the distance between the sent out point and
the delivery is likely to be nil. In such cases the single point may be considered a delivery meter for
the purposes of nominating a method. If the site does not clearly fit this description, applicants should
contact the Department to seek clarification of the likely measurement point.
(b) Power station with nameplate capacity less than 500 kW
If the power station‘s nameplate capacity is 500 kW or less, the applicant may propose a method to
work out the eligible gas-fired electricity. The proposed method may involve the use of averages or
estimates or the application of annual or baseline loss factors or QUFs for the power station.
A proposed method may include:
a) a detailed philosophy;
b) a high-level methodology to implement the philosophy;
c) detailed formulas and equations;
Applicants should attempt to provide information to satisfy both (a) and (b) with this application.
Any proposed method is subject to approval by the Regulator.
If any proposed method is not approved, the eligible gas-fired electricity will be calculated as if the
power station‘s capacity is more than 500 kW. That is, either the general method or direct method will
apply.
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3.5 Determining the baseline for baseline customers
(a) Key Dates
In broad terms, a power station‘s baseline represents the annual amount of electricity, generated from
eligible fuels and delivered to its baseline customers as at 24 May 2000. Only new or additional
gas-fired electricity generation above an identified baseline will be eligible for the creation of GECs.
If the power station was commissioned after 24 May 2000, all customers will be NEW baseline
customers and have baselines equal to zero.
As mentioned below, the relevant ‗baseline year‘ for determination of the baseline is generally
1999-2000. However, if a power station was commissioned or first started to generate electricity from
eligible fuels during, the 1999-2000 financial year, the relevant ‗baseline year‘ for determination of
baselines will be the first 12 months of commercial operation. For this reason, commissioning dates
and commercial operation dates are requested.
In accordance with Section 135CY of the Act, a power station was commissioned:
(a) when, under the relevant contract to build the power station, it reached a stage by which the
building of the station was, in a practical sense, complete; or
(b) if there was no stage as mentioned in paragraph (a)—4 months after the power station first
sent out electricity.
(b) Electricity Data – ‘Existing’ Baseline Customers
As mentioned previously, a power station‘s baseline will essentially be broken up into one or more
baselines and allocated against the power station‘s identified baseline customers as identified at 3.3.
As provided for by the Act -
Existing baseline customers are customers to whom the power station supplies electricity
generated from eligible fuels under an arrangement that was in force on 24 May 2000. Existing
baseline customers will have a baseline greater than zero.
New baseline customers are customers who were not a baseline customer of the power station on
24 May 2000. New baseline customers will have a baseline equal to zero
Applicants will need to provide evidence that a baseline customer is NEW for the purposes of the
baseline determination by providing supporting evidence of the commencement date of the supply
arrangement as per question 3.3.
If the baseline customer is existing, the electricity sent out/delivered electricity in the financial year
1999-2000 (multiplied by the appropriate QUF and LF and adjusted by auxiliary and imported
electricity as per the provisions of the Act) will generally be taken as the baseline for each existing
baseline customer unless the power station was commissioned or first started to generate with eligible
fuels during that year - then it will be the first 12 months of commercial operation.
Data for ‗existing‘ baseline customers for the calendar years 1998 to 2001 is requested to allow the
regulator to assess whether the 1999-2000 or the first 12 month‘s data is representative of the power
station‘s typical annual generation for the baseline customer as at 24 May 2000.
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If the Direct Method has been nominated for a baseline customer at 3.4(a), data should be provided in
the Direct Methods table (quoting delivered amounts). Similarly, if the General Method has been
nominated at 3.4(a), the General Method table (quoting sent out amounts) should be completed.
For the purposes of filling in the tables provided at 3.5(b), sent out and delivered electricity is defined
as follows as per the baseline formulas in 135CY and 135CZ of the Act.
SO Gen is the electricity sent out from the power station, less electricity imported into the power
station, measured in MWh, in the baseline year.
ED means the electricity delivered to the customer, less electricity imported into the power station
multiplied by any relevant baseline loss factor decided by the regulator, measured in MWh, in the
baseline year.
The applicant should calculate the proportion of sent out/delivered electricity generated by eligible
fuels for the power station and provide information to substantiate the proportion used. (Refer to the
administrative policy titled Eligible Fuel).
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Appendix B
Power Station Accreditation Fees
Generator Nameplate Capacity Application Fee Annual Fee
1MW or less $286.80 $286.80
1MW to < 10MW $1,147.00 $573.00
10 MW to < 30MW $2,294.00 $1,147.00
30MW to < 100MW $3,441.00 $1,720.00
100MW or more $4,589.00 $2,294.00
[see Schedule 7 of the Electricity Regulation 2006]
[All fees are GST exempt]
Annual fees are shown for information purposes only. Power Station Accreditation applications
should be accompanied by payment of the relevant application fee.
Payment Options
Cheques
Made payable to the Department of Employment, Economic Development and Innovation, should be
attached to the relevant paperwork and forwarded to
Mailing Address: Street Address:
Queensland Gas Scheme Regulatory Team Queensland Gas Scheme Regulatory Team
Department of Employment, Economic Development Department of Employment, Economic
and Innovation Development and Innovation
th
PO Box 15216 7 Floor, 61 Mary Street
CITY EAST QLD 4002 BRISBANE QLD 4000
Electronic Funds Transfer
EFT payments can be made to the following account:
Bank Name: Commonwealth Bank of Australia
BSB: 064 013
Account No. 10029770
Name: Department of Mines and Energy
Administered Account
ABN No. 98 628 485 885
Copies of the remittance advice should be forwarded to both:
Shared Services Agency (SSA): Queensland Gas Scheme Regulatory Team:
Fax No 07 3006 2658 Fax No. 07 3222 2410
Email CPLReceipting@ssa.qld.gov.au Email
queenslandgasscheme@qld.gov.au
SSA are contactable on 07 3225 1960 The Queensland Gas Scheme Regulatory
Team is contactable on 07 3227 7048
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Credit Cards
Credit Card payments can be made by mail or by facsimile.
Parties paying amounts by Credit Card must ensure they advise the Department of Employment,
Economic Development and Innovation of the deposit and its associated details.
Credit/Corporate Card Payments to the Department of Employment, Economic Development and
Innovation can be lodged with SSA:
Fax: 07 3006 2658 (preferred option) L17 160 Mary Street
BRISBANE QLD 4000
Details required:
Name of Payee/Organisation Card Number (16 digits)
Amount being paid Expiry date (4 digits)
Description or purpose of payment Cardholders name as it appears on card
Type of Credit Card Cardholders signature (if by fax)
o VISA / MASTERCARD / AMEX only Cardholder‘s contact phone number
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