Northern Territory Consolidated Regulations Northern Territory Consolidated RegulationsSchedule 7A.1 Metering register
The metering register forms part of the metering database and holds static metering information associated with metering installations defined by the Rules that determine the validity and accuracy of metering data .
Metering information to be contained in the metering register must include, but is not limited to, the following:
(a) serial numbers;
(b) the metering installation identification name; and
(c) the information required to assign loss factors.
(a) NTESMO must develop, maintain and publish a communication guideline in accordance with the Rules consultation procedures .
(b) A communication guideline must be in place at all times.
(c) The communication guideline is intended to set out specific details as to how metering and energy data and other information exchange processes will be implemented.
(d) The communication guideline must:
(1) specify, or incorporate by reference, detailed technical specifications (including file formats, protocols and timeframes) as to how data and information communication is to be processed, and how the necessary information systems are to be designed and developed; and
(2) be sufficient to enable a Registered Participant to design and commission the information systems necessary for it to engage in communications with NTESMO for the purposes of the Rules .
(e) The communication guideline may include types of metering information that must be included in the metering register .
Note
The detail of this schedule will be considered as part of the phased implementation of the Rules in this jurisdiction.
Note
The detail of this schedule will be considered as part of the phased implementation of the Rules in this jurisdiction.
This schedule sets out the minimum requirements for metering installations .
Table S7A.4.2.1 Overall accuracy requirements of metering installation components
|
Type |
Volume limit per annum per connection point |
Maximum allowable overall error (±%) at full load (Item 6) |
Minimum acceptable class or standard of components |
Metering installation clock error (seconds) in reference to ACST | |
|---|---|---|---|---|---|
|
active |
reactive | ||||
|
1 |
greater than 1 000GWh |
0.5 |
1.0 |
0.2CT/VT/ meter Wh 0.5 meter varh |
±5 |
|
2 |
100 to 1 000GWh |
1.0 |
2.0 |
0.5CT/VT/ meter Wh 1.0 meter varh |
±7 |
|
3 |
0.75 to less than 100 GWh |
1.5 |
3.0 |
0.5CT/VT 1.0 meter Wh 2.0 meter varh (Item 1) |
±10 |
|
4 |
less than 750 MWh (Item 2) |
1.5 |
n/a |
Either 0.5 CT and 1.0 meter Wh; or whole current general purpose meter Wh meets requirements of clause 7A.6.2(a)(9) and 7A.8.9(a) (Item 1) |
±20 |
|
4A |
less than x MWh (Item 3) |
1.5 |
3.0 |
Either 0.5 CT and 1.0 meter Wh; or whole current general purpose meter Wh meets requirements of clause 7A.6.2(a)(10) and 7A.8.9(b) |
±20 |
|
5 |
less than x MWh (Item 3) |
1.5 |
n/a |
Either 0.5 CT and 1.0 meter Wh; or whole current connected general purpose meter Wh meets requirements of clause 7A.6.2(a)(10) and 7A.8.9(b). (Item 1) |
‘±/-20' |
|
6 |
less than y MWh (Item 4) |
2.0 |
n/a |
CT or whole current general purpose meter Wh recording accumulated energy data only. Processes used to convert the accumulated metering data into recording interval metering data and estimated metering data where necessary are included in schedule 7A.7. | |
|
7 |
volume limit not specified (Item 5) |
(Item 6) |
n/a |
No meter . The metering data is calculated metering data determined in accordance with schedule 7A.7. |
n/a |
|
Item 1: |
(a) For a type 3, 4, 4A, 5 and 6 metering installation , whole current meters may be used if the meters meet the requirements of the relevant Australian Standards and International Standards identified in schedule 7A.7. (b) The metering installation types referred to in paragraph (a) must comply with any applicable specifications or guidelines (including any transitional arrangements) specified by the National Measurement Institute under the National Measurement Act . |
|
Item 2: |
High voltage customers that require a voltage transformer and whose annual consumption is below 750 MWh, must meet the relevant accuracy requirements of Type 3 metering for active energy only. |
|
Item 3: |
In relation to a type 4A and type 5 metering installation , the value of ‘x' in this jurisdiction is 0 MWh per annum. |
|
Item 4: |
The following requirements apply in relation to a type 6 metering installation
: (2) devices within the metering installation may record accumulated energy data in predetermined daily time periods where such time periods are specified in schedule 7A.7. |
|
Item 5: |
(a) A type 7 metering installation classification applies where a metering installation does not require a meter to measure the flow of electricity in a power conductor and accordingly there is a requirement to determine by other means the metering data that is deemed to correspond to the flow of electricity in the power conductor. (b) The condition referred to in paragraph (a) will only be allowed for a connection point if: (1) the operation of an unmetered device at the connection point results in a type of unmetered load that is authorised under the terms of a local instrument ; and (2) NTESMO in consultation with Metering Coordinator determines: (i) that the load pattern is predictable; (ii) that, for the purposes of settlements , the load pattern can be reasonably calculated by a relevant method set out in schedule S7A.7; and (iii) that it would not be cost effective to meter the connection point taking into account: (A) the small magnitude of the load ; (B) the connection arrangements; and (C) the geographical and physical location. Note The effect of paragraph (b) is that if a type of unmetered load is authorised under a local instrument, a connection point with that type of unmetered load may be used for the purposes of settlements, and be eligible for a type 7 metering installation, if NTESMO makes a determination under (b)(2) in relation to that connection point. The National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016 are an example of a local instrument. (c) A connection point that meets the condition for classification as a type 7 metering installation does not prevent that connection point from being subject to metering in the future. |
|
Item 6: |
The maximum allowable overall error (±%) at different loads and power factors is set out in Tables S7A.4.2.2 to S7A.4.2.6. |
Table S7A.4.2.2 Type 1 installation – Annual energy throughput greater than 1 000GWh
|
% Rated Load |
Power Factor | |||||
|
Unity |
0.866 lagging |
0.5 lagging |
Zero | |||
|
Active |
Active |
Reactive |
Active |
Reactive |
Reactive | |
|
10 |
1.0% |
1.0% |
2.0% |
n/a |
n/a |
1.4% |
|
50 |
0.5% |
0.5% |
1.0% |
0.7% |
1.4% |
1.0% |
|
100 |
0.5% |
0.5% |
1.0% |
n/a |
n/a |
1.0% |
Table S7A.4.2.3 Type 2 installation – Annual energy throughput between 100 and 1 000GWh
|
% Rated Load |
Power Factor | |||||
|
Unity |
0.866 lagging |
0.5 lagging |
Zero | |||
|
Active |
Active |
Reactive |
Active |
Reactive |
Reactive | |
|
10 |
2.0% |
2.0% |
4.0% |
n/a |
n/a |
2.8% |
|
50 |
1.0% |
1.0% |
2.0% |
1.5% |
3.0% |
2.0% |
|
100 |
1.0% |
1.0% |
2.0% |
n/a |
n/a |
2.0% |
Table S7A.4.2.4 Type 3 installation – Annual energy throughput from 0.75 GWh to less than 100 GWh and Type 4A installation – annual energy throughput less than 0.75 GWh
|
% Rated Load |
Power Factor | |||||
|
Unity |
0.866 lagging |
0.5 lagging |
Zero | |||
|
Active |
Active |
Reactive |
Active |
Reactive |
Reactive | |
|
10 |
2.5% |
2.5% |
5.0% |
n/a |
n/a |
4.0% |
|
50 |
1.5% |
1.5% |
3.0% |
2.5% |
5.0% |
3.0% |
|
100 |
1.5% |
1.5% |
3.0% |
n/a |
n/a |
3.0% |
Table S7A.4.2.5 Type 4 or 5 installation – annual energy throughput less than 0.75GWh
|
% Rated Load |
Power Factor | ||
|
Unity |
0.866 lagging |
0.5 lagging | |
|
Active |
Active |
Active | |
|
10 |
2.5% |
2.5% |
n/a |
|
50 |
1.5% |
1.5% |
2.5% |
|
100 |
1.5% |
1.5% |
n/a |
Table S7A.4.2.6 Type 6 installation – annual energy throughput less than 0.75 GWh
|
% Rated Load |
Power Factor | ||
|
Unity |
0.866 lagging |
0.5 lagging | |
|
Active |
Active |
Active | |
|
10 |
3.0% |
n/a |
n/a |
|
50 |
2.0% |
n/a |
3.0% |
|
100 |
2.0% |
n/a |
n/a |
Notes to Tables S7A4.2.2 to S7A4.2.6
All measurements in Tables S7A4.2.2 to S7A4.2.6 are to be referred to 24 degrees Celsius.
(a) The method for calculating the overall error is the vector sum of the errors of each component part (that is, a + b + c) where:
a = the error of the voltage transformer and wiring;
b = the error of the current transformer and wiring; and
c = the error of the meter.
(b) If compensation is carried out then the resultant metering data error must be as close as practicable to zero.
(a) Where a check metering installation is in place, it is to be applied in accordance with the following Table:
|
Metering Installation Type in accordance with Table S7A.4.2.1 |
Check Metering Requirements |
|---|---|
|
1 |
Check metering installation |
|
2 |
Partial check metering |
|
3 |
No requirement |
|
4, 4A, 5 and 6 |
No requirement |
(b) Where a check metering installation is not in place, and a financially responsible participant requests the installation of a check metering installation at a connection point , the Metering Coordinator at the connection point must arrange for the installation of a check metering installation that complies with the requirements of this schedule.
(c) A check metering installation involves either:
(1) the provision of a separate metering installation using separate current transformer cores and separately fused voltage transformer secondary circuits, preferably from separate secondary windings; or
(2) if NTESMO , in its absolute discretion, considers it appropriate, in the case of a metering installation located at the facility at one end of the two-terminal link , a metering installation located at the facility at the other end of a two-terminal link .
(d) Where the check metering installation duplicates the metering installation and accuracy level, the average of the 2 validated data sets will be used to determine the energy measurement.
(e) Partial check metering involves the use of other metering data or operational data available in 30 min electronic format as part of a validation process in accordance with Schedule 7A.7.
(f) Check metering installations may be supplied from secondary circuits used for other purposes and may have a lower level of accuracy than the metering installation , but must not exceed twice the level prescribed for the metering installation .
(g) The physical arrangement of partial check metering will be determined by the Metering Coordinator .
Programmable settings available within a metering installation of any peripheral device, which may affect the resolution of displayed or stored data, must:
(a) meet the requirements of the relevant Australian Standards and International Standards specified in schedule 7A.7; and
(b) comply with any applicable specifications or guidelines (including any transitional arrangements) specified by the National Measurement Institute under the National Measurement Act .
Without limiting the scope of detailed design, the following requirements must be incorporated in the design of each metering installation :
(a) for metering installations greater than 1 000 GWh pa per connection point , the current transformer core and secondary wiring associated with the meter(s) must not be used for any other purpose;
(b) for metering installations less than 1 000 GWh pa per connection point , the current transformer core and secondary wiring associated with the meter(s) may be used for other purposes (for example, local metering or protection) provided the Metering Coordinator is able to demonstrate that the accuracy of the metering installation is not compromised and suitable procedures/measures are in place to protect the security of the metering installation ;
(c) where a voltage transformer is required, if separate secondary windings are not provided, then the voltage supply to each metering installation must be separately fused and located in an accessible position as near as practical to the voltage transformer secondary winding;
(d) secondary wiring must be by the most direct route and the number of terminations and links must be kept to a minimum;
(e) the incidence and magnitude of burden changes on any secondary winding supplying the metering installation must be kept to a minimum;
(f) meters must:
(1) meet the requirements of relevant Australian Standards and International Standards (if any) specified in schedule 7A.7; and
(2) have a valid pattern approval issued under the authority of the National Measurement Institute or, until relevant pattern approvals exist, a valid type test certificate;
(g) new instrument transformers must:
(1) meet the requirements of relevant Australian Standards and International Standards (if any) specified in schedule 7A.7; and
(2) have a valid pattern approval issued under the authority of the National Measurement Institute or, until relevant pattern approvals exist, a valid type test certificate;
(h) suitable isolation facilities are to be provided to facilitate testing and calibration of the metering installation ;
(i) suitable drawings and supporting information, detailing the metering installation , must be available for maintenance purposes.
In addition to the design requirements specified in clause S7A.5.1, the following guidelines should be considered for each metering installation :
(a) the provision of separate secondary windings for each metering installation where a voltage transformer is required;
(b) a voltage changeover where more than one voltage transformer is available.
This schedule specifies the meter functionality requirements for type 1, 2, 3 and 4 metering installations in this jurisdiction.
In this schedule:
"communications network" means all communications equipment, processes and arrangements that lie between the meter and the NMS.
"end user customer" means the customer or retail customer who consumes electricity at the point of use.
"export "means the delivery of energy from the network to an end-use customer.
"import "means the delivery of energy from an end-use customer into a distribution network .
local disconnection means the operation of the supply contactor to effect a disconnection of supply performed locally at the meter by alternative electronic means.
"metering system "means the installed metering installation , communications network or infrastructure, and any other systems required under this schedule.
"NMS (Network Management System) "means the component of a metering system that manages the communications network.
remote disconnection means the utilisation of the communication system to disconnect the end-use customer's supply at the meter by the operation of a contactor.
"supply contactor "means the contactor in the meter that, when opened, causes the supply to be disconnected and, when closed, allows the supply to become connected .
total accumulated energy means the total or accumulated amount of energy measured and recorded per channel of a meter since the installation of the meter or the resetting of the value.
Clause S7A.5.2 applies to meters in type 1, 2 and 3 metering installations .
(a) The configuration for a meter must be:
(1) three phase Low Voltage CT connect (excluding supply contactor); or
(2) three phase CT / VT .
(b) Meters must meet the relevant requirements of AS 62052.11, AS 62053.22 and AS 62053.21, and any pattern approval requirements of the National Measurement Institute.
Meters must comply with the following requirements:
(a) three phase meters must be four quadrant meters and must be able to separately record active energy and reactive energy , import and export in recording intervals ;
(b) meters must record total accumulated energy for each recorded channel of interval data;
(c) the resolution for collection of interval energy data must be at least 0.1 kWh for active energy and 0.1 kVArh for reactive energy ;
(d) meters must have a minimum storage of 35 days per channel of interval energy data ;
(e) all channels of interval energy data must be able to be read locally as well as remotely read;
(f) it must be possible to remotely and locally select or configure whether import interval energy data is recorded or not;
(g) it must be possible to remotely and locally select or configure whether reactive energy interval energy data is recorded from three phase meters or not.
Clause S7A.5.3 applies to meters in type 4 metering installations .
(a) The configuration for a meter must be:
(1) single phase, single element;
(2) single phase, two element;
(3) three phase direct connect; or
(4) three phase CT connect (excluding supply contactor).
(b) Meters must meet the relevant requirements of AS 62052.11, AS 62053.22 and AS 62053.21, and any pattern approval requirements of the National Measurement Institute.
Meters must comply with the following requirements:
(a) single phase meters must be two quadrant meters and must be able to separately record active energy for import and export in recording intervals ;
(b) three phase meters must be four quadrant meters and must be able to separately record active energy and reactive energy , import and export in recording intervals ;
(c) meters must record total accumulated energy data for each recorded channel of interval energy data ;
(d) the resolution for collection of interval energy data must be at least 0.1 kWh for active energy and 0.1 kVArh for reactive energy ;
(e) the resolution of energy consumption displayed on a meter's display must be at least 0.1 kWh and 0.1 kVArh for direct connected meters ;
(f) meters must have a minimum storage of 200 days per channel of interval energy data ;
(g) all channels of interval energy data must be able to be read locally as well as by remote acquisition ;
(h) the values that must be recorded for import and export are the actual values at the connection point for direct connect meters ;
(i) it must be possible to remotely and locally select or configure whether import interval energy data is recorded or not;
(j) it must be possible to remotely and locally select or configure whether reactive energy interval energy data is recorded from three phase meters or not.
Note:
Export is when energy is exported from the network to a customer and import is when the customer delivers energy into the network. See clause S7A5.1.2.
(a) If a meter is remotely read:
(1) the meter's total accumulated energy data per collected channel must be able to be collected once every 24 hours; and
(2) the interval energy data per collected channel must be able to be collected once every 24 hours.
(b) If a meter is locally read, the meter ' s total accumulated energy per collected channel and the interval energy data per collected channel must be able to be collected.
(c) For individual reads of meters , it must be possible to select up to 35 days of interval energy data to be collected per channel.
(a) Meters excluding CT connected meters must have a supply contactor.
(b) Meters must support both local and remote disconnect, and local and remote reconnection of end-use customer supply via the supply contactor. When a meter performs a disconnection operation, all outgoing circuits from the meter must be disconnected .
(c) To confirm the current state of a meter , the meter must support "on-demand" remote polling of the meter to determine whether the supply contactor is open or closed.
(d) A meter must provide clear local visual indication of the status (open/closed) of the supply contactor.
(a) A meter must support both local and remote end-use customer supply disconnection functionality.
Local disconnection
Note:
The circumstances in which local disconnection may occur include where:
(a) a technician is already on-site performing works and it is most efficient for the technician to perform the disconnection; or
(b) a meter that is capable of remote reading is installed; however the communications infrastructure has not been rolled out or has failed.
(b) Local disconnection via the meter must only be able to be performed by an authorised technician. Unauthorised persons must be physically prevented from operating the supply contactor to disconnect supply .
(c) A meter must support the following:
(1) opening of the supply contactor performed locally;
(2) remote communication of the status (open/closed) of the supply contactor (if communications are active) from the meter to the NMS;
(3) event logging of the local disconnection at that meter .
Remote disconnection
(d) A meter must support the following:
(1) opening of the supply contactor performed remotely;
(2) remote communication of the status (open/closed) of the supply contactor (if communications are active) from the meter to the NMS;
(3) event logging of the remote disconnection at that meter.
(a) A meter must support both local and remote end-use customer supply reconnection functionality.
Local reconnection
(b) Reconnection via the meter must only be able to be performed locally by an authorised technician. Unauthorised persons must be physically prevented from operating the supply contactor to reconnect supply .
(c) A meter must support the following:
(1) closing of the supply contactor performed locally;
(2) remote communication of the status (open/closed) of the supply contactor (if communications are active) from the meter to the NMS;
(3) event logging of local reconnection at that meter .
Remote reconnection
(d) A meter must support the following:
(1) closing of the supply contactor performed remotely;
(2) remote communication of the status (open/closed) of the supply contactor from the meter to the NMS; and
(3) event logging of remote reconnection .
Date and time within meters must be maintained within 20 seconds of Australian Central Standard Time .
(a) A meter must support the recording of Quality of Supply (QoS) events and other events that occur at each meter as detailed as follows:
|
ID |
Events |
|---|---|
|
1 |
Import energy detected |
|
2 |
Supply contactor opened – local |
|
3 |
Supply contactor opened – remote |
|
4 |
Supply contactor closed – local |
|
5 |
Supply contactor closed – remote |
|
6 |
Undervoltage event |
|
7 |
Overvoltage event |
|
8 |
Tamper detected |
|
9 |
Whenever there is a change of meter settings locally |
Undervoltage and overvoltage recording
(b) A meter must support the recording of undervoltage and overvoltage events. The thresholds shall be remotely and locally settable for undervoltage in the range of at least -5% to -20% in 1% steps and for overvoltage in the range of at least +5% to +20% in 1% steps.
Tamper detection
(c) A meter must support the detection and recording of an attempt to tamper with the meter as an event.
A meter must support the detection and recording as an event attempts to tamper with the meter .
All device elements must contain the necessary security to prevent unauthorised access or modification of data.
Meters must have the capability for their firmware to be remotely upgraded. It must be possible to remotely change firmware without impacting the metrology functions of the meter .
Meters must have the capability to be remotely armed.
(a) The Metering Coordinator must ensure that equipment comprised in a purchased metering installation has been tested to the required class accuracy with less than the uncertainties set out in Table S7A.6.1.1.
(b) The Metering Coordinator must ensure appropriate test certificates of the tests referred to in paragraph (a) are retained.
(c) The Metering Coordinator (or any other person arranging for testing) must ensure that testing of the metering installation is carried out:
(1) in accordance with:
(i) clause 7A.7.2 and this schedule; or
(ii) an asset management strategy that defines an alternative testing practice (other than time based) determined by the Metering Coordinator and approved by NTESMO ;
(2) in accordance with a test plan that has been registered with NTESMO ;
(3) to the same requirements as for new equipment where equipment is to be recycled for use in another site; and
(4) so as to include all data storage and processing components specified in schedule 7A.7.
(d) The testing intervals may be increased if the equipment type/experience proves favourable.
(e) The maximum allowable level of testing uncertainty (±) for all metering equipment must be in accordance with Table S7A.6.1.1.
Table S7A.6.1.1 Maximum allowable level of testing uncertainty (±)
|
Description |
Metering Equipment Class | |||||
|---|---|---|---|---|---|---|
|
Class 0.2 |
Class 0.5 |
Class 1.0 |
General Purpose |
Class 2.0 | ||
|
In Laboratory |
CTs ratio phase |
0.05% 0.07 crad |
0.1% 0.15 crad |
n/a |
n/a |
n/a |
|
VTs ratio Phase |
0.05%
|
0.1%
|
n/a |
n/a |
n/a | |
|
Meters Wh |
0.05/cosφ% |
0.1/cosφ% |
0.2/cosφ% |
0.2/cosφ% |
n/a | |
|
Meters varh |
n/a |
0.2/sinφ% |
0.3/sinφ% |
n/a |
0 .4/sinφ% | |
|
In Field |
CTs ratio Phase |
0.1%
|
0.2%
|
n/a |
n/a |
n/a |
|
In Field |
CTs ratio Phase |
0.1%
|
0.2%
|
n/a |
n/a |
n/a |
|
VTs ratio Phase |
0.1%
|
0.2%
|
n/a |
n/a |
n/a | |
|
Meters Wh |
0.1/cosφ% |
0.2/cosφ% |
0.3/cosφ% |
0.3/cos φ% |
n/a | |
|
Meters varh |
n/a |
0.3/sinφ% |
0.4/sinφ% |
n/a |
0.5/sinφ% | |
Where cosφ is the power factor at the test point under evaluation.
Table S7A.6.1.2 Maximum Period Between Tests
Unless the Metering Coordinator has developed an approved asset management strategy that defines practices that meet the intent of this schedule, the maximum period between tests must be in accordance with Table S7A.6.1.2.
|
Description |
Metering Installation Type | ||||
|
Type 1 |
Type 2 |
Type 3 |
Type 4 & 4A |
Types 5 & 6 | |
|
CT |
10 years |
10 years |
10 years |
10 years |
10 years |
|
VT |
10 years |
10 years |
10 years | |
n/a |
|
Burden tests |
When meters are tested or when changes are made | ||||
|
CT connected meter (electronic) |
5 years |
5 years |
5 years |
5 years |
5 years |
|
CT connected meter (induction) |
2.5 years |
2.5 years |
5 years |
5 years |
5 years |
|
Whole current meter |
The testing and inspection requirements must be in accordance with an approved asset management strategy. Guidelines for the development of an asset management strategy are set out in Schedule 7A.7 | ||||
Table S7A.6.1.3 Period between inspections
Unless the Metering Coordinator has developed an approved asset management strategy that meets the intent of this schedule and is approved by NTESMO , the maximum period between inspections must be in accordance with Table S7A.6.1.3.
|
Description |
Metering Installation Type | |||
|
Type 1 |
Type 2 |
Type 3 |
Type 4, 4A, 5 & 6 | |
|
Metering installation equipment inspection |
2.5 years |
12 months (2.5 years if check metering installed) |
> 10 GWh: 2 years 2≤ GWh ≤ 10: 3 years <2 GWh: when meter is tested. |
When meter is tested. |
(a) Current transformer and voltage transformer tests are primary injection tests, or other approved testing procedures as approved by NTESMO .
(b) The calculations of accuracy based on test results are to include all reference standard errors.
(c) An "estimate of testing uncertainties" must be calculated in accordance with the ISO "Guide to the Expression of Uncertainty for Measurement".
(d) Where operational metering is associated with settlements metering then a shorter period between inspections is recommended (but is not mandatory).
(e) For sinφ and cosφ, refer to the ISO "Guide to the Expression of Uncertainty in Measurement" , where cosφ is the power factor .
(f) A typical inspection may include:
(1) check the seals;
(2) compare the pulse counts;
(3) compare the direct readings of meters ;
(4) verify meter parameters and physical connections; and
(5) current transformer ratios by comparison.
(a) This schedule applies to NTESMO , Registered Participants , Metering Coordinators , Metering Providers , Metering Data Providers and the Utilities Commission in relation to connection points in this jurisdiction.
(b) This schedule provides information on the application of metering installations to connection points and sets out provisions for metering installations and metering data services .
(c) For service provision at connection points where:
(1) the Metering Provider and the Metering Data Provider are part of the same company; and
(2) metering installation , provision or maintenance work is performed using internal processes and procedures,
those internal processes and procedures will be taken to be compliant with this schedule if the metering work satisfies the performance and quality outcomes of this schedule.
In this schedule:
accumulation meter means a meter where the energy data recorded in the meter represents a period in excess of a recording interval .
"estimated reading" means:
(a) an estimate of a meter reading where an actual meter reading has not occurred; or
(b) a substitute of a meter reading used for the purposes of transferring a retail customer to a new Retailer where an actual meter reading has not occurred.
final reading means the last actual meter reading for a retail customer when they vacate an address or change retailer or the last actual meter reading taken before all or any part of a metering installation is removed or modified and where the modification affects the energy data in the metering installation .
ILAC means International Laboratory Accreditation Cooperation.
"inventory table "means a table of devices for unmetered loads associated with each NMI as described in clauses S7A.7.14.2(c) and S7A.7.14.3(c).
load table means a table of unmetered device loads as described in clause S7A.7.14.1.
on/off table means a table recording the switching status (On = 1, Off = 0) for each recording interval for the unmetered loads associated with a NMI as described in Part B of this schedule.
physical inventory means a physical count of devices.
public holiday means a day that is a public holiday, as defined in section 17 of the Interpretation Act 1978 (NT), that is observed in the City of Darwin, other than a public holiday that is part of a day.
"routine testing", for the purposes of this schedule, includes the ongoing and regular maintenance testing, compliance testing and in-service testing of metering installation components initiated by the Metering Coordinator or Metering Provider to fulfil their obligations in accordance with schedule 7A.6.
Sample Test Plan means a statement of the sample size or sizes to be taken, the frequency of sample testing and the required accuracy.
scheduled reading date means the date of the next scheduled meter reading.
unmetered means a load or a connection point at which a meter is not necessary under schedule 7A.6.
In this schedule, a reference to the relevant retailer is a reference to Power Retail Corporation (trading as Jacana Energy) ABN 65 889 840 667.
The purpose of this Part is to set out:
(a) the obligations of the Metering Coordinator , in relation to metering installations that are referred to in the Rules ;
(b) the obligations of Metering Providers in relation to the provision, installation, routine testing and maintenance of a metering installation ; and
(c) the obligations of Metering Data Providers in relation to the provision of metering data services.
This schedule provides information on the application of metering installations to connection points . In particular, this schedule sets out provisions for metering installations and metering data services relating to:
(a) Metering Providers , which include:
(1) the type of metering installation permitted for the measurement of active energy ;
(2) the provision, installation, testing, inspection and maintenance of metering installations ;
(3) the components of each type of metering installation ; and
(4) storage of, and access rights to, energy data in the metering installation ; and
(b) Metering Data Providers , which include:
(1) the collection or calculation, processing and delivery of metering data ; and
(2) storage of metering data in the metering data services database and rights of access to metering data.
(a) Metering Coordinators must use Metering Providers to provide, install, test and maintain the relevant components, characteristics and service requirements of the metering installation as specified in the Rules .
(b) Metering Coordinators are responsible for the design of a metering installation and warrant that the design complies with the components, characteristics and service requirements specified in the Rules .
(c) Metering Coordinators must ensure the components have been selected, installed, tested and commissioned by the Metering Providers so that the metering installation satisfies the relevant accuracy and performance requirements in the Rules .
(a) Meters used in type 1, 2, 3, 4, 4A, 5 and 6 metering installations must comply with any applicable specifications or guidelines (including transitional arrangements) specified by the National Measurement Institute, under the National Measurement Act , and must also meet the relevant requirements of Australian Standards and International Standards:
(1) for type 1, 2, 3, 4, 4A, and 5 (including type 3 and 4 whole current) metering installation measurement elements : AS 62052.11, AS 62053.21 and AS 62053.22; and
(2) for type 6 metering installation measurement elements : AS 1284.1, AS 62053.21 and AS 62052.11.
(b) Current transformers for type 1, 2, 3, 4, 4A, 5 and 6 metering installations must meet the relevant requirements of AS 60044.1 and must also comply with any applicable specifications or guidelines (including transitional arrangements) specified by the National Measurement Institute under the National Measurement Act.
(c) Voltage transformers for type 1, 2, 3, 4, 4A, 5 and 6 metering installations must meet the relevant requirements of AS 60044.2 , AS 60044.3, AS 60044.5 and AS 1243 and must also comply with any applicable specifications or guidelines (including transitional arrangements) specified by the National Measurement Institute under the National Measurement Act .
(d) New current transformers and voltage transformers must comply with current Australian Standards .
(e) In-service current transformers and voltage transformers must comply with the Australian Standard that applied at the time of installation.
(f) Unless otherwise permitted by the Rules , the Metering Coordinator must ensure that new meters and related equipment used at a connection point have a valid pattern approval issued under the authority of the National Measurement Institute or, until relevant pattern approvals exist, a valid type test certificate issued by a NATA accredited laboratory or a body recognised by NATA under the ILAC mutual recognition scheme. Relevant approval certificates must be provided to the Utilities Commission on request .
(g) A visible display must be provided to display, at a minimum, the cumulative total energy for each register measured by that metering installation .
(h) Any programmable settings available within the metering installation , or any peripheral device, which may affect the resolution of displayed or stored data, must meet the relevant requirements of AS 62052.11, AS 62053.21 and AS 62053.22 and must comply with any applicable specifications or guidelines (including transitional arrangements) specified by the National Measurement Institute under the National Measurement Act .
(a) Where requested by a financially responsible participant, the Metering Coordinator must provide pulse output facilities representing the quantity of electricity measured in accordance with the relevant Australian Standard for that meter within a reasonable time of receiving the request.
(b) For type 1, 2, 3, 4, 4A and 5 metering installations with a pulse output, the measurement element pulse output must provide a number of energy pulses in each integrating period commensurate with the accuracy class of the metering installation when operating at the top of the range of measurement of the metering installation but may be set at a lower rate where the anticipated operating range is significantly lower than the top of the range of measurement of the metering installation.
(c) A type 4A or 5 metering installation must have an optical port that meets the AS 1284.10.2 or AS 62056.21 or a computer serial port to facilitate downloading of 90 days of interval energy data for each meter associated with the metering installation in 35 seconds or less.
Where the metering installation includes equipment for load control or the measurement of reactive energy , the installation and operation of that equipment will be governed by an instrument other than the Rules , for example, a ‘use of system' agreement between the Local Network Service Provider and the financially responsible participant.
Note
No specific requirements are included under this heading for this jurisdiction at this stage. The clause may be used as part of the phased implementation of the Rules in this jurisdiction.
(a) A type 4A, 5 or 6 metering installation clock is to be reset to within ± 20 seconds of Australian Central Standard Time on each occasion that the metering installation is accessed in the circumstances referred to in paragraphs (b) and (c), and the maximum drift in the type 4A or 5 metering installation clock permitted between successive meter readings is ± 300 seconds.
(b) A Metering Provider must reset a type 4A, 5 or 6 metering installation clock when inspecting, maintaining or commissioning the metering installation .
(c) A Metering Data Provider must reset a type 4A, or 5 metering installation clock when interval metering data is collected from the metering installation .
(d) For type 6 metering installations with different time of day rates, the metering installation must meet AS 62054.11, AS 62054.21 and AS 62052.21, or have the switching between the different rates controlled by a frequency injection relay or time clock operated by the Local Network Service Provider.
Where a metering installation records interval energy data the interval periods must be based on recording intervals or parts of a recording interval in accordance with the following requirements:
(a) the end of each interval for a 15-minute interval period must be on the hour, on the half-hour and on each quarter of an hour ( ACST );
(b) the end of each interval for a 30-minute interval period must be on the hour and on the half-hour ( ACST );
(c) for other sub-multiple intervals –where agreed with NTESMO (in respect of a metering installation that is used for the purposes of settlements ), the Local Network Service Provider and the relevant financially responsible participant, provided that the ends of the intervals correspond each and every exact hour ( ACST ) and half-hour ( ACST ).
(a) Where an interval meter supports alarm functionality, the Metering Provider is required to enable the following alarms:
(1) power failure/ meter loss of supply for instrument transformer connected metering installations only;
(2) voltage transformer or phase failure;
(3) pulse overflow;
(4) cyclic redundancy check error; and
(5) time tolerance.
(b) Where there are alarm sensitivity settings, these must be set at appropriate levels to ensure meaningful alarm outputs (for example, for contestable supplies a voltage drop of -15% is nominally appropriate).
(a) If summation metering is achieved by paralleling current transformer secondary circuits, the overall metering system must meet the minimum standards for a new metering installation under all load combinations of the individual current transformer secondaries.
(b) If summation metering is achieved by the arithmetic sum of data registers or the accumulation of pulses, each individual metering point must meet the minimum standards for a new metering installation and the Metering Coordinator must on request demonstrate that the summation techniques reliably and accurately transfer data.
(c) Current transformer secondaries can only be paralleled using appropriate arrangements of links; this must not be done at the meter terminals.
(d) For type 2 metering installations only – direct summation, in which secondary wiring from a multiple number of feeders are connected directly into the terminals of a meter, or summation current transformers , are permitted provided that the overall errors of the installation are considered.
Note
No requirements are included in this clause for this jurisdiction at this stage. The clause may be used as part of the phased implementation of the Rules in this jurisdiction.
(a) Unless a Metering Coordinator has an Asset Management Strategy approved by NTESMO , metering installations must be tested and inspected in accordance with rule 7A.7 and schedule 7A.6. Paragraphs (b) to (f) provide guidelines that:
(1) the Metering Coordinator will need to take into consideration when seeking approval of an Asset Management Strategy; and
(2) NTESMO will need to take into consideration in approving a proposed Asset Management Strategy.
(b) An acceptable alternative testing practice or test plan for in-service meter performance must demonstrate compliance with Australian Standard " AS 1284.13: Electricity Metering in-service compliance testing".
(c) Unless the Metering Coordinator has developed an alternative accuracy assessment method for type 5 and 6 metering installations that meets the intent of Tables S7A.4.2.5 and S7A.4.2.6 and is approved by NTESMO , the overall metering installation error is calculated by the vector sum of the errors of each metering installation component, being a + b + c where:
a = error of VT and wiring
b = error of CT and wiring
c = error of meter .
(d) Where the Metering Coordinator is not testing and inspecting metering installations in accordance with rule 7A.7 and schedule 7A.6 (that is, not time-based), the Metering Coordinator must include in its Asset Management Strategy an alternative inspection practice that meets the requirements of schedule 7A.6 .
(e) The Metering Coordinator must provide a copy of the Asset Management Strategy to each relevant Metering Provider .
(f) For those meters for which new or amended pattern approval has been received from the National Measurement Institute or, in the absence of pattern approval, new or amended type testing has been undertaken by a NATA accredited laboratory or a body recognised by NATA under the ILAC mutual recognition scheme, the Metering Coordinator must ensure that the Sample Test Plan stipulates that this population of meter is tested at least once in the first three years of being placed in service .
(a) If requested by a Registered Participant with a financial interest in the metering installation or the energy measured by the metering installation , the Metering Coordinator must make arrangements for the testing of the metering installation in accordance with clause 7A.7.2 of the Rules .
(b) If requested by a Registered Participant with a financial interest in the metering installation, the Utilities Commission must make arrangements in accordance with clause 7A.7.4 of the Rules to determine the consistency of metering data held in the metering data services database and the energy data held in the type 1, 2, 3, 4, 4A, 5 and 6 metering installation .
(c) Where the Registered Participant requests a metering installation test in accordance with paragraphs (a) and (b):
(1) the Metering Coordinator or the Utilities Commission (as applicable) must use reasonable endeavours to conduct the test within 15 business days of the request;
(2) if the requirement under subparagraph (1) would prevent the Registered Participant's customer witnessing the test, then the Metering Coordinator or the Utilities Commission may agree to a mutually convenient time to conduct the test; and
(3) the Metering Coordinator or the Utilities Commission (as applicable) must, if requested, provide an estimate of costs associated with the test prior to any test being undertaken.
S7A.7.4 Installation of meters and de-commissioning
The Metering Coordinator must use reasonable endeavours to ensure that, at the time of installation, a metering installation is:
(a) protected against damage;
(b) installed in such a way that it allows safe and unimpeded access to the retail customer or any person whose obligation it is to test, adjust, maintain, repair, or replace the metering installation , or to collect metering data from the metering installation ; and
(c) available to the retail customer or any person whose obligation it is to test, adjust, maintain, repair, or replace the metering installation , or to collect metering data from the metering installation via safe, convenient and unhindered access when it is not located at the site .
The Metering Coordinator must ensure that when each type 4A, 5 or 6 metering installation is installed at a connection point , it is checked such that it has the optical port, communications port and visual display located so that the optical port, communications port, or visual display can be readily accessed for meter reading.
(a) Before de-commissioning all or any part of an existing metering installation the Metering Provider undertaking the work must ensure that:
(1) arrangements are put in place to ensure a final reading is taken at the time of de-commissioning of all metering data maintained in the existing meter ; and
(2) the ownership of the existing meter is ascertained and arrangements made for the meter to be returned to its owner within 10 business days unless otherwise agreed with the asset owner.
(b) Where the metering data from the final reading is not transferred to the relevant Metering Data Provider at the time of de-commissioning, the owner must ensure the metering data or final reading (as applicable), is provided to that Metering Data Provider within 2 business days of receipt of the meter .
Note
No requirements are included in this clause for this jurisdiction at this stage. The clause may be used as part of the phased implementation of the Rules in this jurisdiction.
Note
No requirements are included in this clause for this jurisdiction at this stage. The clause may be used as part of the phased implementation of the Rules in this jurisdiction.
S7A.7.6 Responsibility for metering data services
Note
No requirements are included in this clause for this jurisdiction at this stage. The clause may be used as part of the phased implementation of the Rules in this jurisdiction.
To facilitate the verification of metering data for type 4, 4A, 5, 6 and 7 metering installations :
(a) each Metering Coordinator must ensure that a Sample Test Plan is established and maintained in accordance with Australian Standards "AS 1199: Sampling procedures for inspection by attributes – Sampling schemes indexed by acceptance quality limit (AQL) for lot-by-lot inspection" or "AS 2490: Sampling Procedures and Charts for Inspection by Variables for Percent Nonconforming" to validate that all metering data stored in the metering data services database is consistent with the energy data stored in the metering installation or the physical inventory (as applicable);
(b) verification tests must be conducted in accordance with the Sample Test Plan, which must not be less than once every 12 months;
(c) the calculated metering data stored in a metering data services database for a NMI is consistent with the physical inventory if the error associated with calculating the energy value for the sample, that is:
is within ± 2.0%; and
(d) if there is an inconsistency between the inventory table held in a metering data services database for a type 7 metering installation and the physical inventory, the physical inventory is to be taken as prima facie evidence of the actual number of unmetered devices.
Note
Provisions relating to type 7 metering installations will only apply in this jurisdiction in the event of a type 7 metering installation being available in this jurisdiction and after a 12 month transitional period allowing all participants to achieve compliance.
(a) For the purposes of sample testing type 7 metering installations , the Metering Coordinator must ensure that the sample size is determined using Table S7A.7.5.3.1. The sample is to be selected from unmetered devices in the inventory table for a Metering Coordinator .
(b) The Metering Coordinator must ensure that the sample size for the first two validation tests is based on a ‘normal' sample size indicated in Table S7A.7.5.3.1.
Table S7A.7.5.3.1 -–Unmetered devices in inventory table
|
Number of Unmetered Devices in Inventory Table |
Sample Size | ||
|
Reduced |
Normal |
Tightened | |
|
2 to 8 |
2 |
2 |
3 |
|
9 to 15 |
2 |
3 |
5 |
|
16 to 25 |
3 |
5 |
8 |
|
26 to 50 |
5 |
8 |
13 |
|
51 to 90 |
5 |
13 |
20 |
|
91 to 150 |
8 |
20 |
32 |
|
151 to 280 |
13 |
32 |
50 |
|
281 to 500 |
20 |
50 |
80 |
|
501 to 1200 |
32 |
80 |
125 |
|
1201 to 3200 |
50 |
125 |
200 |
|
3201 to 10000 |
80 |
200 |
315 |
|
10001 to 35000 |
125 |
315 |
500 |
|
35001 to 150000 |
200 |
500 |
800 |
|
150001 to 500000 |
315 |
800 |
1250 |
|
500001 to over |
500 |
1250 |
2000 |
(c) The Metering Coordinator must ensure that the sample size for subsequent variation tests is based on the following:
Reduced
Current sample size?
Tightened
Normal
Reduced
Previous sample size?
Tightened
Normal
Previous test within accuracy requirement?
No
Yes
Yes
Yes
Current test within accuracy requirement?
No
No
Current test within accuracy requirement?
No
Next sample size - Tightened
Next sample size - Reduced
Next sample size - Normal
(d) The Metering Coordinator must select sample unmetered devices for a validation test from random geographic areas depending on the sample size. The selection of the geographic area must be such that each unmetered device has an equal chance of being included in the sample .
(e) The Metering Coordinator must ensure that the validation test is conducted at least once every 6 months, commencing from the first validation test.
(f) Should the results of two consecutive validation tests, based on a reduced sample size, be within the accuracy requirements for that test, the Metering Coordinator must ensure that the next validation test is conducted at least once every 12 months .
If requested to test a type 7 metering installation by a Registered Participant under clause 7A.7.2, the Metering Coordinator must:
(a) arrange to test that the calculated metering data stored in the metering data services database reflects the physical inventory for the type 7 metering installation ;
(b) use reasonable endeavours to conduct the test within 15 business days of the request; and
(c) prior to any test being undertaken, provide an estimate of costs associated with the test .
(a) Where metering data has been substituted, NTESMO must advise affected Registered Participants at the same time as that metering data is sent to financially responsible participants for settlements .
(b) If metering data has not been transferred to NTESMO to meet the settlements time frames or such metering data has been transferred but is unusable, NTESMO must, in accordance with clause 7A.9.2:
(1) take action to obtain the metering data ; or
(2) request the Metering Coordinator take action to obtain the metering data.
The purpose of this Part is to set out obligations concerning the validation, substitution and forward estimation of metering data to satisfy the Rules .
(a) This Part applies to Metering Data Providers , NTESMO and Metering Coordinators .
(b) This Part must be read in conjunction with Schedule 7A.8 Part B.
S7A.7.8 Principles for validation, substitution and estimation
The principles to be applied to validation, substitution and estimation include the following:
(a) the Metering Coordinator must coordinate the resolution of issues arising from the non-performance of metering systems , including any liaison with associated Registered Participants, Metering Providers and Metering Data Providers , and the Metering Coordinator must respond promptly to requests for remedial action from the Metering Data Provider or NTESMO ;
(b) the Metering Data Provider must identify metering data errors resulting from data collection and processing operations using validation processes in accordance with this Part.
(a) The Metering Data Provider must undertake substitutions on behalf of NTESMO or the Metering Coordinator, as appropriate, in a manner consistent with this Part.
(b) Substitutions may be required in the following circumstances:
(1) where the system or equipment supporting the remote or manual collection of metering data has failed or is faulty;
(2) where the metering installation for a connection point has failed or is removed from service;
(3) to enable timely provision of metering data to financially responsible participants or NTESMO for billing transactions or settlements purposes, as relevant;
(4) in situations where metering data has been irretrievably lost;
(5) where the metering data is found to be erroneous or incomplete;
(6) where metering data has not completed validation as part of the registration or transfer of a connection point ;
(7) where metering data has failed or has not completed the validation process;
(8) where metering data cannot be obtained in the performance timeframes required for the data period in question:
(i) metering data for metering installations with remote acquisition must be substituted if metering data cannot be obtained to meet either settlements or billing transactions timeframes, as relevant, or the required performance in Schedule 7A.8 Part C; and
(ii) metering data for manually read metering installations must be substituted if metering data cannot be obtained on or within the expected timeframe of the next scheduled reading date for a connection point , and any historical or previous estimated metering data must be replaced with substituted metering data ;
(9) when an inspection or test on the metering installation establishes that a measurement error exists due to a metering installation fault;
(10) when the affected financially responsible participant, the relevant retailer and Local Network Service Provider have all agreed and subsequently informed the Metering Data Provider that a previous substitution was inaccurate and that a re-substitution of metering data is required;
(11) where the metering data calculation has failed the validation tests for a metering installation with calculated metering data ;
(12) in response to customer transfers authorised in this jurisdiction;
(13) in situations involving meter churn.
(a) The Metering Data Provider must undertake estimations on behalf of the Metering Coordinator in a manner consistent with this Part.
(b) Estimations may be required in the following circumstances:
(1) routinely for a period equal to or just greater than the period to the next scheduled reading date or another forward period;
(2) in response to customer transfers authorised in this jurisdiction;
(3) where the current published scheduled reading date has changed due to a revised scheduled reading route and the existing estimated metering data does not extend to or beyond the revised next scheduled reading date, and in this case the Metering Data Provider must adjust the estimated metering data for the revised next scheduled reading date.
(a) The Metering Data Provider must assign the relevant metering data quality flags to metering data as follows:
|
Quality Flag |
Description |
|
A |
Actual metering data . |
|
S |
For any substituted metering data that is considered temporary and may be replaced by actual metering data . Substitutions apply to historical date/time periods at the time of substitution. |
|
E |
For any estimated metering data that is considered temporary and may be replaced by actual metering data or substituted metering data . Estimations apply to a period that has an end date/time in the future. |
|
F |
For substitutions that are of a permanent or final nature and, subject to paragraph S7A.7.8.5(b) and (e), the metering data would not be replaced by actual metering data at any time. |
|
N |
This quality flag is only utilised within the interval metering data file for instances where no metering data exists in the metering data services database for the periods concerned. |
(b) Unless specified otherwise in this Part, Metering Data Providers must apply the following quality flag rules in the metering data services database :
(1) ‘A' metering data can only be replaced with ‘A', ‘S' or ‘F' metering data ;
(2) ‘S' metering data can only be replaced with ‘A', ‘S' or ‘F' metering data ;
(3) ‘E' metering data can only be replaced with ‘A', ‘E', ‘S' or ‘F' metering data ;
(4) ‘F' metering data can only be replaced with ‘F' metering data as per paragraph S7A.7.8.5(f) or ‘A' metering data as per paragraph S7A.7.8.5(b) or S7A.7.8.5(h).
The Metering Data Provider must undertake final substitutions in the following circumstances:
(a) where a notice has been received from either the Metering Coordinator or the Metering Provider detailing a failure of the metering installation that affects the quality of the energy data ;
(b) if actual metering data is unexpectedly recovered from the metering installation and a final substitution has been undertaken in accordance with paragraph (1), and in this case the Metering Data Provider must replace the final substituted metering data with the actual metering data and maintain a record of the reason;
(c) where the Metering Data Provider must undertake final substitutions following a meter churn;
(d) where the Metering Data Provider has received a notice that the affected financially responsible participant, the relevant retailer and Local Network Service Provider have agreed that the metering data is erroneous and that a final substitution is required;
(e) where NTESMO requests the provision of substitutions and final readings in response to customer transfers authorised in this jurisdiction where required for the purposes of settlements ;
(f) where the Metering Data Provider may undertake to replace existing final substituted metering data with new final substituted metering data in accordance with this Part;
(g) where the Metering Data Provider has found actual metering data to be erroneous;
(h) where the Metering Data Provider is replacing type 6 final substituted metering data with accumulated metering data that spans consecutive meter readings on agreement with the financially responsible participant, the relevant retailer and the Local Network Service Provider .
S7A.7.9 Substitution for acquisition of metering data from
remotely read metering installations
(a) For metering installations with remote acquisition installed in accordance with paragraph 7A.6.8(a), the Metering Data Provider may perform substitutions in accordance with clause S7A.7.10.
(b) For all other metering installations with remote acquisition , the Metering Data Provider must perform substitutions in accordance with clause S7A.7.9.
The Metering Data Provider must apply the following rules when performing a substitution:
(a) the Metering Data Provider must obtain clear and concise identification as to the cause of any missing or erroneous metering data for which substitutions are required;
(b) the Metering Data Provider must undertake to do a type 11 substitution and use metering data obtained from any check metering installation associated with the connection point as the first choice considered for the source of metering data for any substitutions undertaken;
(c) SCADA data , where available, may be used by the Metering Data Provider as check metering data for substitutions;
(d) the Metering Data Provider may only undertake substitution type 13 where substitution types 11 and 12 are not applicable or cannot be carried out;
(e) for connection points where the financially responsible participant is a generator :
(1) the Metering Data Provider may directly undertake type 11, type 12 or type 13 substitutions if metering data has failed validation;
(2) the Metering Data Provider may undertake type 16 or 18 substitutions following consultation and agreement with the affected generator that the substituted metering data is an accurate reflection of the interval metering data concerned;
(3) if metering data cannot be collected from a metering installation or substituted within the required timeframes, the Metering Data Provider must undertake type 19 substitutions as an interim until metering data can be collected from the metering installation or substituted;
(f) the Metering Data Provider may only undertake substitution types 14, 15, 16, 17, 18, or 19 where substitution types 11, 12 and 13 are not applicable or cannot be carried out;
(g) the Metering Data Provider may perform all substitution types except type 16 or 18 without the agreement of the affected financially responsible participant, Local Network Service Provider or relevant retailer and the Metering Data Provider may change the quality flag to an existing type 16 or 18 substitution without seeking further agreement from those parties;
(h) the Metering Data Provider must notify the Local Network Service Provider , relevant retailer and the financially responsible participant for the connection point of any substitution within two business days of the substitution being carried out, and this notification is to be achieved via the participant metering data file as detailed in the MDFF Specification;
(i) where there is a metering installation malfunction that cannot be repaired within the periods specified in clause 7A.6.9 , the Metering Data Provider must:
(1) where the metering installation malfunction is due to a failure of the meter to correctly record interval energy data and the Metering Coordinator has been granted an exemption to repair the metering installation, substitute the missing metering data in accordance with this Part;
(2) for type 1-3 metering installations and other instrument transformer connected metering installations , and where a metering installation malfunction is due to a failure of the remote acquisition system, arrange for an alternative method for the collection of metering data from the metering installation in a timeframe that ensures the Metering Data Provider complies with metering data delivery requirements; or
(3) for non- instrument transformer connected metering installations , and where a metering installation malfunction is due to a failure of the remote acquisition system, substitute the missing metering data in accordance with this Part;
(j) the Metering Data Provider must ensure that all substituted metering data is replaced with actual metering data when it becomes available.
Type 11 – Check data
(a) To perform a type 11 substitution, the Metering Data Provider must use interval metering data obtained from the check metering installation for that metering point where:
(1) the metering installation and check metering installation are installed at the same connection point ;
(2) the metering installation and check metering installation are installed on different ends of a transmission line where the difference due to transmission line losses can be accurately determined; or
(3) the metering installation and the check metering installation are installed across a parallel set of feeders having similar line impedances between a common set of busbars.
Type 12 – Calculated
(b) To perform a type 12 substitution, the Metering Data Provider must calculate the interval metering data to be substituted where they relate to a single unknown feed to a node based on the other known energy flows to or from that node.
Type 13 – SCADA
(c) To perform a type 13 substitution:
(1) the Metering Data Provider must use SCADA data provided by NTESMO in the agreed format for substitution purposes, which originates from a similar measurement point as the meter ;
(2) where SCADA data is inferior in accuracy or resolution and in a dissimilar format to the metering data , (for example, 30 Min. demand values). the Metering Data Provider may have to adjust the data in both magnitude and form so that the substitution is valid; and
(3) where SCADA data is to be used for Substitution, both the provided ‘E' channel and ‘B' channel SCADA data streams must be used.
Type 14 – Like day
(d) To perform a type 14 substitution, the Metering Data Provider must substitute missing or erroneous metering data using the nearest equivalent day or like day method, as detailed in Table 1.
Table 1
|
TYPE 14 | |
|---|---|
|
Substitution day |
Nearest equivalent day or like day (in order of availability) |
|
Monday |
Monday ## |
|
Tuesday |
Tuesday## Wednesday## Thursday## Wednesday# Thursday# |
|
Wednesday |
Wednesday## Tuesday# Thursday## Thursday# Tuesday## |
|
Thursday |
Thursday## Wednesday# Tuesday# Wednesday## Tuesday## |
|
Friday |
Friday## |
|
Saturday |
Saturday## |
|
Sunday |
Sunday## |
|
Substitutions for like day to be as detailed above, unless: (a) No metering data is available on the first listed day, the next listed preferred day is to be used. If there is no other suitable listed day, or no metering data is available on any of the listed days type 15 substitution must be used. (b) The substitution day was a public holiday, in which case the most recent Sunday is to be used. (c) The substitution day was not a public holiday and the listed day is a public holiday, then the next listed preferred day that is not a public holiday is to be used. # Occurring in the same week as the substitution day. | |
Type 15 – Average like day
(e) To perform a type 15 substitution, the Metering Data Provider may substitute missing or erroneous metering data using the average like day method, as detailed in Table 2.
Table 2
|
TYPE 15 |
|
The interval metering data to be substituted will be calculated using an average of the metering data from each corresponding interval from the preceding 4 weeks, or any part of those. This averaging technique may be applied in either of the following ways: (a) where the averaged interval metering data is used to provide the value for the metering data requiring substitution; (b) where the averaged interval metering data is used to provide the profile and is scaled to a pre-determined consumption value for the metering data to be substituted. Type 15 substitutions must not be used for public holidays. |
Type 16 – Agreed method
(f) Where the Metering Data Provider is required to undertake substitution for any period greater than seven days for type 1 –3 metering installations or greater than 15 days for other metering installation types, the Metering Data Provider must consult and use reasonable endeavours to reach an agreement with the financially responsible participants, relevant retailer and the Local Network Service Provider for the connection point . This may include changes to existing substitutions for any period where those affected parties have directed that as a result of site or end user information, the original substitutions are in error and a correction is required.
Type 17 – Linear interpolation
(g) To perform a type 17 substitution, the Metering Data Provider may substitute metering data for consecutive intervals up to, but not exceeding two hours, by using simple linear interpolation.
Type 18 – Alternative
(h) To perform a type 18 substitution, the Metering Data Provider may use an alternative method of substitution subject to agreement with the financially responsible participants, relevant retailer and the Local Network Service Provider for the connection point . The specifics of this substitution type may involve a globally applied method or a method where an adjusted profile is used to take into account local conditions that affect consumption (for example, local holiday or end user shutdown), or where alternative metering data may be available for quality checks, such as using metering register data.
Type 19 – Zero
(i) The Metering Data Provider must undertake substitutions of ‘zero' where:
(1) the Local Network Service Provider or the Metering Provider has informed the Metering Data Provider of a de-energised connection point or an inactive meter and the consumption is reasonably believed to be zero; or
(2) substitutions are applicable for connection points where the financially responsible participant is a Generator in accordance with clause S7A.7.9.2.
S7A.7.10 Substitution and estimation for manually read interval
metering installations
(a) The substitution and estimation requirements in this clause S7A.7.10 are only to be used for metering installations where:
(1) interval metering data is manually collected as a scheduled meter reading; or
(2) the metering installations have been installed with remote acquisition in accordance with paragraph 7A.6.8(a).
(b) Where remote acquisition of metering data has failed at the metering installation and manual collection of interval metering data is required, the substitution requirements specified in clause S7A.7.9 apply.
(a) The Metering Data Provider must ensure that all substituted metering data and estimated metering data are replaced with actual metering data when it becomes available.
(b) The Metering Data Provider must obtain clear and concise identification as to the cause of any missing or erroneous metering data for which substitutions are required.
(c) Where there is a metering installation malfunction that cannot be repaired within the periods specified in clause 7A.6.9 , the Metering Data Provider must substitute the missing metering data in accordance with this Part.
(d) The Metering Data Provider must only apply the following substitution and estimation types:
(1) substitutions may be type 51, 52, 53, 54, 55, 56, 57 or 58;
(2) estimations may be type 51, 52, 56, 57 or 58.
(e) The Metering Data Provider must only use type 56 or 57 substitutions or estimations where the historical data does not support the application of a type 51 or 52 substitution or estimation.
(f) The Metering Data Provider must notify the Local Network Service Provider , the relevant retailer and the financially responsible participant for the connection point of any substitution or estimation within 2 business days of the substitution.
(g) Metering Data Providers must not perform type 53 or 55 substitutions or type 56 substitutions or estimations without the agreement of the Local Network Service Provider , the relevant retailer and the financially responsible participant for the connection point . Metering Data Providers may change the quality flag to an existing type 53 or 55 substitution or type 56 substitution or estimation without seeking further agreement from those parties.
Type 51 – Previous years method (nearest equivalent day or like day method)
(a) To perform a type 51 substitution, the Metering Data Provider must provide a substitute or estimate using the metering data from the nearest equivalent day or like day from the same, or similar, meter reading period in the previous year. The nearest equivalent day or like day is to be determined from Table 3.
Type 52 – Previous meter reading method (nearest equivalent day or like day method)
(b) To perform a type 52 substitution, the Metering Data Provider must provide a substitute or estimate using the metering data from the nearest equivalent day or like day from the previous meter reading period. The nearest equivalent day or like day is to be determined from Table 3.
Table 3
|
TYPE 51 or 52 | |
|---|---|
|
Substitution day |
Nearest equivalent day or like day (in order of availability) |
|
Monday |
Monday ## Monday# |
|
Tuesday |
Tuesday## Wednesday## Tuesday# Wednesday# |
|
Wednesday |
Wednesday## Tuesday## Thursday## Wednesday# Thursday# Tuesday# |
|
Thursday |
Thursday## Wednesday## Tuesday## Thursday# Wednesday# Tuesday# |
|
Friday |
Friday## Friday# |
|
Saturday |
Saturday## Saturday# |
|
Sunday |
Sunday## Sunday# |
|
Substitutions or estimations for like day to be as detailed above, unless: (a) no metering data is available on the first listed day, in which case the next listed preferred day is to be used. If there is no other suitable day, or no metering data is available on any of the listed days, type 52 must be used; (b) the substitution or estimation day was a public holiday, in which case the most recent Sunday is to be used; or (c) the substitution or estimation day was not a public holiday and the listed day is a public holiday, in which case the next listed preferred day that is not a public holiday, Saturday or Sunday is to be used. ## For type 51 utilise metering data from the corresponding week in the previous year. ## For type 52 utilise metering data from the corresponding week of the previous meter reading period. # For type 51 utilise metering data from the week preceding the corresponding week in the previous year. # For type 52 utilise metering data occurring in the week preceding the corresponding week of the previous meter reading period. | |
(c) Alternatively, the Metering Data Provider must provide substituted metering data or estimated metering data using the average like day method, as detained in Table 4.
Table 4
|
TYPE 52 (Alternative) |
|
The interval metering data for which substitution or estimation is to be carried out will be calculated using an average of the metering data from each corresponding interval from any part, or all, of the preceding 4 weeks. This averaging technique may be applied in either of the following ways: • where the averaged interval metering data is used to provide the value for the metering data requiring substitution or estimation; • where the averaged interval metering data is used to provide the profile and are scaled to a pre-determined consumption value for the metering data that are the subject of substitution or estimation . Type 52 substitutes or estimates must not be used for public holidays. |
Type 53 – Revision of substituted metering data
(d) To perform a type 53 substitution, the
Metering Data Provider must re-substitute or change substituted metering data
to collecting an actual meter reading , where the financially responsible
participant, the relevant retailer and the Local Network Service Provider have
agreed, on the basis of site or end user information, that the original
substituted metering data is in error and a correction is required.
Type 54 – Linear interpolation
(e) To perform a type 54 substitution, the Metering Data Provider may substitute metering data for intervals up to, but not exceeding 2 hours, by using simple linear interpolation.
Type 55 – Agreed substitution method
(f) To perform a type 55 substitution, the Metering Data Provider may undertake to use another method of substitution (which may be a modification of an existing substitution type), where none of the existing substitution types apply, subject to using reasonable endeavours to form an agreement with the financially responsible participant, the relevant retailer and Local Network Service Provider for the connection point. The specifics of this substitution type may involve a globally applied method.
Type 56 – Prior to first reading – agreed method
(g) Prior to the first actual meter reading and where no historical data exists for the connection point , the Metering Data Provider may provide a substitution or estimation for the interval metering data using a method agreed between the financially responsible participant, the relevant retailer and Local Network Service Provider .
Type 57 – Prior to first reading – customer class method
(h) [ Not used ]
Type 58 – Zero
(i) The Metering Data Provider must undertake substitutions or estimations of ‘zero' where either the Local Network Service Provider or the Metering Provider has informed the Metering Data Provider of a de-energised connection point or an inactive meter and where the consumption is known to be zero.
S7A.7.11 Substitution and estimation for metering installations
with accumulated metering data
(a) The Metering Data Provider must replace all estimated metering data with either actual metering data or substituted metering data when:
(1) actual metering data covering all or part of the estimation period is obtained;
(2) the scheduled meter reading could not be undertaken, by replacing the estimated metering data with substituted metering data with a quality flag of ‘F'; or
(3) the scheduled meter reading could not be undertaken, by replacing the estimated metering data with substituted metering data with a quality flag of ‘F' unless it was identified that the metering installation no longer has an accumulation meter installed, in which case a quality flag of ‘S' may be used.
(b) Any final substituted metering data provided by the Metering Data Provider must be re-validated, updated or re-calculated by the Metering Data Provider when:
(1) the value of the metering data obtained at the next actual meter reading is found to be less than the previous final substitution; or
(2) the final substituted value is disputed and following consultation and agreement with the financially responsible participant, the relevant retailer and the Local Network Service Provider for the connection point , the new agreed value will be determined using type 64 substitution.
(c) The Metering Data Provider must obtain clear and concise identification as to the cause of any missing or erroneous metering data for which substitutions are required.
(d) The Metering Data Provider may apply the following substitution and estimation types:
(1) substitutions may be type 61, 62, 63, 64, 65, 66, 67 or 68;
(2) estimations may be type 61, 62, 63, 65 or 68.
When to use Type 62 substitution
(e) Where the scheduled meter reading cycle is less frequent than monthly, the Metering Data Provider may only use a type 62 substitution or estimation method when metering data from the same, or similar, meter reading period last year (that is, type 61) is not available.
When to use Type 63 substitution
(f) The Metering Data Provider may use type 63 substitutions or estimations only when the metering data from the same, or similar, meter reading period last year and metering data from the previous meter reading period is not available (that is, when type 61 and type 62 substitution or estimation methods cannot be used).
When to use Type 65 substitution
(g) The Metering Data Provider may use type 65 substitutions or estimations only when the metering data from the same, or similar, meter reading period last year or the metering data from the previous meter reading period is not available (that is, when type 61 and type 62 substitution or estimation methods cannot be used).
When to use Type 67 substitution
(h) The Metering Data Provider must only use a type 67 substitution when:
(1) directed by the Metering Coordinator ;
(2) not expressly disallowed in this jurisdiction ;
(3) the retail customer -provided meter reading meets the validation rules for that data stream; or
(4) the Metering Data Provider has no actual metering data.
When to use Type 64 or 66 substitution
(i) Metering Data Providers must not perform type 64 or 66 substitutions without seeking the agreement of the financially responsible participant, the relevant retailer and the Local Network Service Provider for the connection point . Metering Data Providers may, however, undertake to change the quality flag to an existing type 64 or 66 substitution without seeking further agreement from those parties.
(j) The Metering Data Provider must notify the relevant parties for the connection point of any substitution or estimation within 2 business days of the substitution or estimation. Notification must comply with the obligations set out in S7A.8.9.11.
Type 61 – Previous year method (average daily consumption method
(a) To perform a type 61 substitution, the Metering Data Provider must provide a substitution or estimation of the meter reading by calculating the energy consumption as per the following formula:
Type 62 – Previous meter reading method (average daily consumption method)
(b) To perform a type 62 substitution, the Metering Data Provider must provide a substitution or estimation of the meter reading by calculating the energy consumption as per the following formula:
Type 63 – Customer class method
(c) To perform a type 63 substitution, the Metering Data Provider must provide a substitution or estimation by calculating the energy consumption as per the following formula:
Type 64 – Agreed method
(d) To perform a type 64 substitution, the Metering Data Provider may undertake to use another method of substitution (which may be a modification of an existing substitution type), where none of the existing substitution types are applicable, subject to using reasonable endeavours to form an agreement with the financially responsible participant, the relevant retailer and Local Network Service Provider for the connection point. The specifics of this substitution type may involve a globally applied method.
Type 66 – ADL method
(e) [ Not used ]
Type 66 – Revision of substituted metering data
(f) To perform a type 66 substitution, the Metering Data Provider must re - substitute or change substituted metering data prior to collecting an actual meter reading where the financially responsible participant, the relevant retailer and the Local Network Service Provider for the connection point have agreed to revise the original substituted metering data , on the basis of site or end user specific information.
Type 67 – Customer reading
(g) Unless the Metering Data Provider is required to apply a type 68 substitution, the Metering Data Provider must substitute any previously substituted metering data or estimated metering data based directly on a meter reading provided by an end user.
Type 68 – Zero
(h) The Metering Data Provider must undertake substitutions or estimations of ‘zero' where either the Local Network Service Provider or Metering Provider has informed the Metering Data Provider of a de-energised connection point or an inactive meter and where the consumption is known to be zero.
S7A.7.12 Substitution and estimation for calculated metering
data
(a) The Metering Data Provider must:
(1) obtain clear and concise identification as to the cause of any missing or erroneous calculated metering data for which substituted metering data are required;
(2) ensure that all substituted metering data and estimated metering data are based on calculated metering data and not on any previous substitutions or estimations (as applicable);
(3) base calculated metering data for type 7 metering installations on inventory table data as follows:
(i) where the inventory table has not been updated for the period concerned, calculated metering data must be based on the most recent available information and provided as an estimate; and
(ii) where the inventory table is correct for the period concerned, the calculated metering data must be flagged as ‘A' metering data , however, when the inventory table is subsequently updated for the period concerned, the calculated metering data must be flagged as ‘F' metering data ;
(4) notify the Local Network Service Provider, the relevant retailer and the financially responsible participant for the connection point of any substituted calculated metering data within 2 business days of the substitution, and this notification is achieved via the Participant metering data file as detailed within Schedule 7A.8; and
(5) flag all calculated metering data substitutions as ‘F'.
(b) The Metering Data Provider may apply the following substitution and estimations types:
(1) substitutions may be type 71, 72, 73, or 74;
(2) estimations may be type 75.
Type 71 – Recalculation
(a) To perform a type 71 substitution, the Metering Data Provider must substitute calculated metering data with the calculated metering data obtained by a recalculation based on the current inventory tables, load tables and on/off tables.
Type 72 – Revised tables
(b) Where the error in the calculated metering data is due to errors in the inventory table, load table and on/off table, the Metering Data Provider must substitute calculated metering data by a recalculation based on the most recent inventory tables, load tables and on/off tables in which there were no errors.
Type 73 – Revised algorithm
(c) Where the error in the calculated metering data is due to an error in its calculation, the Metering Data Provider must substitute the most recent calculated metering data for which there was no error.
Type 74 – Agreed method
(d) The Metering Data Provider may use another method of calculated metering data substitution (which may be a modification of an existing substitution type), where none of the existing substitution types is applicable, subject to using reasonable endeavours to form an agreement between the financially responsible participant, the relevant retailer and Local Network Service Provider for the connection point. The specifics of this substitution type may involve a globally applied method.
Type 75 – Existing table
(e) The Metering Data Provider must provide an estimate for the calculated metering data based on the most recent inventory table until such time as an updated inventory table is received for the period concerned.
S7A.7.13 Data validation requirements
Metering Data Providers must manage systems and processes on the basis that:
(a) stored metering data held in the meter buffer might be subject to installation measurement error;
(b) data delivered by reading systems, (for example, remote reading systems, hand-held readers and conversion software) might not be recovered from the meters without corruption; and
(c) auditable validation procedures are of critical importance and can have a direct impact on disputes. It is essential that Metering Data Providers comply with these validation procedures and that all metering data is subject to validation prior to delivery to NTESMO , Registered Participants and financially responsible participants.
(a) The Metering Data Provider must validate interval metering data against the following meter alarms when these are provided in the meter :
(1) power failure/ meter loss of supply;
(2) voltage transformer or phase failure;
(3) pulse overflow;
(4) cyclic redundancy check error; and
(5) time tolerance.
(b) Where interval metering installations assign alarms to the data channel and the interval metering data concerned, the Metering Data Provider must process the alarm along with the metering data as part of the required validation.
(c) The Metering Data Provider must ensure that all metering data alarm reports are signed off and dated by the person actioning the data exception report review as part of the validation.
(d) The Metering Data Provider must validate all interval metering data with all metering data alarms prior to providing to NTESMO , Registered Participants or financially responsible participants.
(e) All Metering Data Provider exception reports must provide, for all instances where the interval metering data was found to be corrupted, an indication of the subsequent actions undertaken by the Metering Data Provider .
Validations during collection of interval metering data
(a) The validations to be performed by Metering Data Providers responsible for the collection of interval metering data from manually read metering installations are as follows:
(1) the meter serial number matches the recorded meter serial number;
(2) the security of the metering installation is intact, for example, meter seals are in place and in good order;
(3) the time synchronisation of the metering installation is correct to ACST inclusive of any load control devices.
Validations during collection of accumulated metering data
(b) The validations to be performed by Metering Data Providers responsible for the collection of accumulated metering data are as follows:
(1) the value of metering data from the current meter reading ≥ the value of metering data from the previous meter reading;
(2) the value of metering data from the current meter reading is valid against an expected minimum value;
(3) the value of metering data from the current meter reading is valid against an expected maximum value;
(4) the meter serial number matches the recorded meter serial number;
(5) the security of the metering installation is intact, for example, meter seals are in place and in good order;
(6) the time synchronisation of the metering installation is correct to ACST inclusive of any load control devices;
(7) the dial capacity is checked against the recorded dial capacity.
General requirements
(a) Metering Data Providers must confirm information about the NMI is provided to NTESMO , where this is required in accordance with clause 7A.10.1, after any installation or change to a metering installation prior to the provision of any metering data to NTESMO or Registered Participants for the purposes of settlements.
Validation of metering data from remotely read metering installations
(b) Metering Data Providers must carry out the following validations after any installation or change to a metering installation with remote acquisition of metering data prior to the distribution of any interval metering data to NTESMO , Registered Participants or financially responsible participants for the purposes of settlements or billing transactions :
(1) for instrument transformer connected metering installations , the metering installation is recording metering data correctly, in conjunction with the Metering Provider ;
(2) for whole current metering installations , the metering data correctly pertains to the registered metering installation ;
(3) all data streams are captured.
Validation of interval metering data from manually read metering installations
(c) The Metering Data Provider must carry out the following validations in conjunction with the Metering Provider for manually read interval metering installations after any changes to a metering installation prior to the provision of any interval metering data to NTESMO, Registered Participants or financially responsible participants for the purposes of settlements or billing transactions :
(1) the metering data correctly pertains to the registered metering installation ;
(2) all data streams are captured.
Validation of accumulated metering data from manually read metering installations
(d) Metering Data Providers must carry out the following validations, following any changes to a metering installation and prior to the provision of any accumulated metering data to NTESMO, Registered Participants or financially responsible participants for the purposes of settlements or billing transactions :
(1) the metering data correctly pertains to the registered metering installation ;
(2) all data streams are captured.
Validation of type 7 metering installations
(e) Metering Data Providers must validate the calculated metering data on registration of all metering installations to verify that the inventory tables, load tables and on/off tables are complete and correct for the specifics of the metering installation .
General
(a) For metering installations with remote acquisition installed in accordance with paragraph 7A.6.8(a), the Metering Data Provider may perform validation in accordance with clauses S7A.7.14.4 and S7A.7.14.5, instead of clause S7A.7.14.2.
Validations for remotely read metering installations
(b) Metering Data Providers must, as a minimum, undertake the following validations within the metering data services database for metering installation types with remote acquisition of metering data:
(1) a check of all interval metering data against a nominated maximum value:
(i) this validation is to ensure that erroneous interval metering data spikes are trapped and substituted;
(ii) this check may additionally be performed in the polling software;
(2) a check of the maximum value of active energy and reactive energy :
(i) for current transformer metering installations , the maximum value is to be initially determined by the connected current transformer ratio of the metering installation ;
(ii) for whole current metering installations the maximum rating of the meter is to be used;
(3) a check against a nominated minimum value or, alternatively, a 'zero' check that tests for an acceptable number of zero intervals values per day to be derived from the site's historical metering data ;
(4) a check for null (no values) metering data in the metering data services database for all data streams:
(i) the aim of this check is to ensure that there is a 100% metering data set (and substitution for any missing interval metering data is undertaken);
(ii) the minimum check required is to ensure that there is at least one non-null active energy or reactive energy value per interval per metering data stream ;
(5) a check for the meter alarms referred to in clause S7A.7.13.2 and ensure:
(i) that a process is in place that captures these meter alarms within the validation and ensures that any meter alarm occurrences are retained as part of the metering data audit trail;
(ii) the provision of details of the occurrences of meter alarms to relevant Registered Participants within the metering data file in accordance with the MDFF Specification.
Validations for metering installations with checking metering or partial check metering
(c) Metering Data Providers must undertake the following validations by comparing the metering data and check metering data for all metering installations that have associated check metering installations or partial check metering installations :
(1) for metering installations where the check metering installation duplicates the metering installation accuracy, the Metering Data Provider must validate the metering installation data streams and check metering data streams on a per interval basis, and the average of the two validated metering data sets will be used to determine the energy measurement;
(2) for installations where the check metering data validation requires a comparison based on nodal balance (comparing the sum energy flow to the busbar against energy flow from the busbar):
(i) the Metering Data Provider must construct a validation algorithm within the metering data services database that will facilitate comparison of interval metering data for each energy flow on a per interval basis;
(ii) the Metering Data Provider must conduct an analysis of the historical metering data for each connection point to ascertain whether error differences in nodal balance are acceptable;
(iii) the Metering Data Provider should use this information to refine its validation algorithms to minimise the error difference for each connection point , based on historical metering data;
(iv) the maximum error difference considered acceptable for any connection point is 1% on a per interval basis, and the Metering Data Provider should minimise this for each connection point , based on historical metering data;
(3) where the check metering installation is remote from the metering installation (for example, at the other end of a transmission line or the other side of a transformer ):
(i) the Metering Data Provider must construct a validation algorithm within the metering data services database that will facilitate comparison of interval metering data from the metering installation and the check metering installation on a per interval basis with adjustment for respective transformer or transmission line losses;
(ii) the Metering Data Provider must conduct an analysis of the historical metering data for each connection point to ascertain whether the error differences between the metering data from the metering installation and check metering installation are acceptable;
(iii) the Metering Data Provider should use this information to refine its validation algorithms to minimise the error difference for each connection point , based on historical metering data;
(iv) the maximum error difference considered acceptable for any connection point is 5% on a per interval basis, and the Metering Data Provider should minimise this for each connection point , based on historical metering data;
(4) for connection points where SCADA data is made available by NTESMO for the purposes of validation, the Metering Data Provider must validate the metering data by comparison of the interval metering data against the SCADA data as provided by NTESMO in the agreed format:
(i) the Metering Data Provider must construct a validation algorithm within the metering data services database that will facilitate comparison of interval metering data from the metering installation and the SCADA data on a per interval basis;
(ii) the Metering Data Provider must conduct an analysis of the historical metering data for each connection point to ascertain whether error differences between the interval metering data from the metering installation and the SCADA data are acceptable;
(iii) the Metering Data Provider should use this information to refine its validation algorithms to minimise the error difference value for each connection point , based on historical metering data;
(iv) the Metering Data Provider must construct an appropriate validation algorithm as the SCADA data may be derived from a different measurement point, have a different interval collection period or have a different base unit of measurement, (for example, power not energy value) with allowances for a larger error of measurement;
(5) the Metering Data Provider is only required to undertake validation of metering data against the SCADA data on the primary data channel i.e. only ‘B' channel validation where the financially responsible participant is a Generator and only ‘E' channel validation for loads, such as pumps.
Validations for interval metering data from manually read metering installations with current transformers
(d) Metering Data Providers must, as a minimum, undertake the following validations on interval metering data from manually read metering installations with current transformers within the metering data services database :
(1) a check of all interval metering data against a nominated maximum value:
(i) this validation is to ensure that erroneous interval metering data spikes are trapped and substituted;
(ii) this check may additionally be performed in the collection software;
(2) a check of the maximum value of active energy , which must initially be determined by the connected current transformer ratio of the metering installation (maximum reactive energy checks may also be performed as an option);
(3) a check against a nominated minimum value or, alternatively, a ‘zero' check that tests for an acceptable number of zero interval values per day to be derived from the site's historical metering data ;
(4) a check for null (no values) metering data in the metering data services database for all metering data streams:
(i) the aim of this check is to ensure that there is a 100% metering data set (and that substitution for any missing interval metering data is undertaken);
(ii) the minimum check required is to ensure that there is at least one non-null active energy or reactive energy value per interval per metering data stream;
(5) a check for meter alarms referred to in clause S7A.7.13.2 and ensure that:
(i) a process is in place that captures these meter alarms within the validation and ensures that any meter alarm occurrences are retained as part of the metering data audit trail; and
(ii) the relevant Registered Participants are notified of the occurrences of these meter alarms within the metering data file in the MDFF specification;
(6) where supported by the meter(s) , validation for a given period of interval metering data by comparison of the totalised interval energy data (accumulation register reading) and the change in the meter cumulative registers ( energy tolerance); it is acknowledged that this check would not identify current transformer ratio changes that have occurred after initial commissioning and have not been advised to the Metering Data Provider ;
(7) a check of the metering data for continuity and reasonability over the meter reading period:
(i) check that no gaps in the metering data exist;
(ii) check that metering data for the expected period has been delivered based on the scheduled meter reading date.
Validations for interval metering data from whole current manually read metering installations
(e) Metering Data Providers must, as a minimum, undertake the following validations on metering data from whole current manually read interval metering installations within the metering data services database :
(1) a check of all interval metering data against a nominated maximum value:
(i) this validation is to ensure that erroneous interval metering data spikes are trapped and substituted;
(ii) this check may additionally be performed in the collection software;
(2) a check of the maximum value of active energy (maximum reactive energy checks may also be performed as an option), and the maximum value is to be initially set to the rating of the meter ;
(3) a check for null (no values) metering data in the metering data services database for all metering data streams:
(i) the aim of this check is to ensure that there is a 100% metering data set (and that substitution for any missing interval metering data is undertaken);
(ii) the minimum check required is to ensure that there is at least one non-null active energy or reactive energy value per interval per metering data stream;
(4) a check for meter alarms referred to in clause S7A.7.13.2 and the Metering Data Provider is not required to validate the interval metering data for power outage or power failure alarms, but must ensure that:
(i) a process is in place that captures these meter alarms within the validation and ensures that any meter alarm occurrences are retained as part of the metering data audit trail;
(ii) the relevant Registered Participants are notified of the occurrences of these meter alarms within the metering data file in accordance with the MDFF specification;
(5) where supported by the meter(s) , validation for a given period of interval metering data by comparison of the totalised interval energy data (accumulation register reading) and the change in the meter cumulative registers ( energy tolerance);
(6) a check of the metering data for continuity and reasonability over the meter reading period:
(i) check that no gaps in the metering data exist;
(ii) check that metering data for the expected period has been delivered based on the scheduled meter reading date.
Validations for accumulation metering data from manually read metering installations
(f) Metering Data Providers must undertake the following validations within the metering data services database for metering installations with accumulated metering data :
(1) a check against a nominated minimum value of metering data collected from the metering installation ;
(2) a check against a nominated maximum value of metering data collected from the metering installation , and this is to be applied to both the metering data collected from the metering installation and the calculated energy consumption values;
(3) the current value of metering data collected from the metering installation ≥ previous value of metering data collected from the metering installation ;
(4) the current value of metering data collected from the metering installation is numeric and ≥ 0;
(5) the current date that metering data is collected from the metering installation > the previous date that metering data was collected from the metering installation ;
(6) a check for null (no values) metering data in the metering data services database for all metering data streams, and the aim of this check is to ensure that there is a 100% metering data set and substitution for any missing metering data is undertaken.
Validations for type 7 metering installations
(g) Metering Data Providers must undertake the following validations of calculated metering data within the metering data services database :
(1) a check against a nominated maximum calculated metering data value;
(2) for subparagraph (1), calculated metering data value is numeric and ≥ 0;
(3) a check for null (no values) calculated metering data for all metering data streams, and the aim of this check is to ensure that there is a 100% calculated metering data set (and substitution for any missing calculated metering data has been undertaken);
(4) a check of the inventory tables, load tables and on/off
tables using a process approved by the Metering Coordinator to ensure that the
correct version of these tables is being used for the production of calculated
metering data ;
(5) a check against a nominated minimum value, or alternatively, a ‘zero' check that tests for an acceptable number of zero Interval values per day;
(6) calculated metering data date > previous calculated metering data date.
Note
Obligations for determination of metering data for unmetered load, including requirements and methodologies for calculating metering data and associated responsibilities, will be considered in the event of a type 7 metering installation being available in this jurisdiction and after a 12 month transitional period allowing all participants to achieve compliance.
Note
Responsibility for developing, maintaining and publishing the load table will be considered in the event of a type 7 metering installation being available in this jurisdiction and after a 12 month transitional period allowing all participants to achieve compliance.
(a) The load table must set out:
(1) for each controlled unmetered device, its load (which includes any associated control gear, in watts) for use in calculating interval metering data in accordance with clause S7A.7.14.2; and
(2) for each uncontrolled unmetered device, its annual energy consumption in accordance with clause S7A.7.14.3. The annual energy consumption is used to calculate the calculated device wattage (in watts) which is used to calculate the interval metering data for each device type as follows:
Where i = Uncontrolled unmetered device type i .
(b) Proposals to add a new unmetered device load to the load table must include load measurement tests conducted by a NATA accredited laboratory or an overseas equivalent.
(c) Agreement for an unmetered device load to be added to the load table does not replace any obligation for an interested party to obtain appropriate approvals related to the performance and acceptance of use of the unmetered device.
Metering data calculation
(a) The Metering Coordinator must ensure that the interval metering data for controlled unmetered devices classified as a type 7 metering installation are calculated in accordance with the following algorithm:
Interval metering data for TIj for NMI (in watt hours) =
where:
i = device type
j = TI
k = proportion of device attributable to that NMI
TI is in minutes.
Unmetered device wattage/device wattage is determined from the load table.
Unmetered device count/device count is determined from the inventory table.
Period load is switched on is determined from the on/off table.
Inventory table
(b) For each NMI , a separate inventory table is required that identifies each unmetered device type that forms part of the load and for each unmetered device type lists:
(1) the unmetered device type;
(2) the form of on/off control – photoelectric cell control, timer control, ripple control or other control;
(3) if timer control or ripple control, the on/off times for the timer control or the ripple control system;
(4) if other control, the on/off times;
(5) if an unmetered device is shared with another NMI , the proportion of load that is agreed by affected Registered Participants to be attributable to that NMI (k), and each k factor will be less than 1 and the sum of the k factors for a shared unmetered device across each respective NMI must be equal to 1;
(6) if an unmetered device is not shared with another NMI , the k factor must be equal to 1;
(7) the number of such unmetered devices installed;
(8) the effective start date – the first day on which that record in the inventory table is to be included in the calculation of metering data for that NMI ;
(9) the effective end date – the last day on which that record in the inventory table is to be included in the calculation of metering data for that NMI ; and
(10) the last change date – the date that record in the inventory table was most recently created or modified.
(c) Each unmetered device in the inventory table is a unique combination of physical hardware, time control classification and shared portion. For example, if an unmetered device is shared with another NMI , the individual portions of the unmetered device(s) must be included in the inventory table as a separate unmetered device type on each NMI .
(d) Each Metering Coordinator must develop the initial inventory table for the NMI s for which it is responsible. The initial inventory table must be agreed by each affected Registered Participant and the relevant end user.
(e) Each Metering Coordinator must update the inventory table for the NMIs for which it is responsible on at least a monthly basis to ensure that the accuracy requirements in clause S7A.7.6.2 are met. Any changes to the inventory table may only be made on a retrospective basis where:
(1) agreed by the Metering Coordinator and the affected Registered Participants ; or
(2) necessary to comply with clause 7A.7.4.
(f) The Metering Coordinator must communicate any material changes to the inventory table to the affected Registered Participants .
(g) The Metering Coordinator must provide the inventory table to relevant Registered Participants when requested.
On/off table
(h) The form of on/off control may be:
(1) photoelecetric;
(2) timer control, or ripple control; or
(3) other control.
Photoelectric cell control
(i) The Metering Coordinator must ensure that the appropriate sunset times and sunrise times are obtained from the Australian Government Geoscience website ( www.ga.gov.au/geodesy/astro/sunrise.jsp
), based on the longitude and latitude of the relevant town and Australian Central Standard Time .
(j) The Metering Coordinator must ensure that the period that the load is switched on during a recording interval is calculated as follows:
|
Recording interval |
Period load is switched on |
|---|---|
|
For the recording intervals commencing after sunset and finishing prior to sunrise |
Period load is switched on = 1 |
|
For the recording intervals commencing after sunrise and finishing prior to sunset |
Period load is switched on = 0 |
|
For the recording interval during which the sunset occurs |
(Period load is switched on) = |
|
For the recording interval during which the sunrise occurs |
(Period load is switched on) = |
Timer control
(k) If the on/off times for an unmetered device is controlled by a timer or ripple injection system:
(1) On time = ON time set on timer or ripple injection system;
(2) Off time = OFF time set on timer or ripple injection system.
(l) The Metering Coordinator must ensure that the period that the load is switched on during a recording interval is calculated as follows:
|
Recording interval |
Period load is switched on |
|---|---|
|
For the recording intervals commencing after on time and finishing prior to off time |
Period load is switched on = 1 |
|
For the recording intervals commencing after off time and finishing prior to on time |
Period load is switched on = 0 |
|
For the recording interval during which the on time occurs |
(Period load is switched on)=
|
|
For the recording interval during which the off time occurs |
(Period load is switched on)=
|
Other control
(m) Where the on/off times for an unmetered device are not in accordance with paragraphs (i) to (m), the following alternative forms of control may be used:
(1) On time = sunset time + ON delay or ON time set on timer or ripple injection system;
(2) Off time = sunrise time + OFF delay or OFF time set on timer or ripple injection system or a fixed duration after ON time.
(n) Where sunrise or sunset times are used, the time is determined in accordance with paragraph (j).
(o) The Metering Coordinator must ensure that the period that the load is switched on during a recording interval is calculated as follows:
|
Recording interval |
Period load is switched on |
|---|---|
|
For the recording intervals commencing after on time and finishing prior to off time |
Period load is switched on = 1 |
|
For the recording intervals commencing after off time and finishing prior to on time |
Period load is switched on = 0 |
|
For the recording interval during which the on time occurs |
(Period load is switched on)=
|
|
For the recording interval during which the off time occurs |
(Period load is switched on)=
|
(a) [Not used]
Energy calculation
(b) The Metering Coordinator must ensure that the interval metering data for other unmetered loads , which have been classified as a type 7 metering installation, is calculated in accordance with the following algorithm:
Inventory table
(c) For each NMI , a separate inventory table is required that identifies each device type that forms part of the NMI load and for each device type lists:
(1) the device type;
(2) the form of on/off control (24 hours per day);
(3) if a device is shared with another NMI , the proportion of load that is agreed by relevant financially responsible participants to be attributable to that NMI (k), and each k factor will be less than 1 and the sum of the k factors for a shared unmetered device across each respective NMI must be equal to 1;
(4) if a device is not shared with another NMI , the k factor must be equal to 1;
(5) the number of such devices installed;
(6) the effective start date – the first day on which that record in the inventory table is to be included in the calculation of metering data for that NMI ;
(7) the effective end date – the last day on which that record in the inventory table is to be included in the calculation of metering data for that NMI ; and
(8) the last change date – the date that record in the inventory table was most recently created or modified.
(d) Each device in the inventory table is a unique combination of physical hardware, time control classification and shared portion. For example, if a device is shared with another NMI , the individual portions of the device(s) must be included in the inventory table as a separate device type on each NMI.
(e) Each Metering Coordinator must develop the initial inventory table for the NMIs for which it is responsible. The initial inventory table must be agreed by the relevant financially responsible participants and the relevant end-use customer.
(f) Each Metering Coordinator must use reasonable endeavours to update the inventory table, for the NMIs for which it is responsible, on at least a monthly basis for any additions, deletions and modifications to ensure that the accuracy requirements in clause S7A.7.6.2 are met. Such additions, deletions or modifications to the inventory table may only be made on a retrospective basis where:
(1) agreed by the Metering Coordinator and the relevant financially responsible participants; or
(2) necessary to comply with clause 7A.7.6.
(g) The Metering Coordinator must communicate any material changes to the inventory table to the relevant financially responsible participants.
(h) The Metering Coordinator must provide the inventory table to relevant financially responsible participants when requested.
On/off table
(i) Other unmetered loads are assumed to operate 24 hours per day.
(j) For each recording interval period load is switched on = 1.
(a) This schedule applies to Metering Providers and Metering Data Providers .
(b) This schedule sets out:
(1) the requirements for the provision, installation and maintenance of metering installations by Metering Providers ;
(2) requirements for the systems and processes for the collection, processing and delivery of metering data by Metering Data Providers ;
(3) the performance levels associated with the collection, processing and delivery of metering data ;
(4) the data formats that must be used for the delivery of metering data ;
(5) the requirements for the management of relevant NT NMI Data ; and
(6) the requirements for the processing of metering data associated with connection point transfers and the alteration of metering installations where one or more devices are replaced.
In this schedule:
collect, collection, collected mean a process undertaken by the Metering Data Provider to obtain metering data from a meter or metering installation .
Service Providers means Metering Data Providers , Metering Providers and Local Network Service Providers .
Part B Metering provider services
(a) Part B of this schedule:
(1) details the obligations, technical requirements, measurement process and performance requirements that are to be performed, administered and maintained by a Metering Provider ;
(2) details the obligations and technical/operational requirements in the provision, installation and maintenance of the metering installation by a Metering Provider ;
(3) relates to Metering Providers who undertake the provision, installation and maintenance of various metering installation types as stipulated; and
(4) sets out minimum requirements for Metering Providers .
(b) For service provision at connection points where:
(1) the Metering Provider and the Metering Data Provider are part of the same company; and
(2) metering installation provision or maintenance work is performed using internal processes and procedures,
those internal processes and procedures will be deemed to be compliant with this Part if the metering work satisfies the performance and quality outcomes of this Part.
The Metering Provider is responsible for the provision of metering provision services, including but not limited to:
(a) maintaining the ongoing metering installation compliance with the Rules ;
(b) the provision and maintenance of physical metering installation security controls;
(c) the provision, installation and maintenance of the metering installation ;
(d) the maintenance of metering installation password security; and
(e) the development and maintenance of an Asset Test Plan.
Metering Providers must:
(a) employ personnel with the skills, knowledge and expertise necessary for the discharge of the responsibilities under Chapter 7A and have procedures for ensuring that personnel maintain their knowledge and understanding of the requirements of the Rules ;
(b) maintain a register of employees, which for each employee must include:
(1) skills, knowledge and expertise;
(2) qualifications, registrations and accreditations where applicable to the discharge of Metering Provider duties;
(3) training undertaken and planned;
(4) authorisations to provide opinions and interpretations of technical information; and
(5) authorisations to access metering installations within secure and restricted areas;
(c) have policies and procedures for making statements of opinions and interpretations, documented within the quality system;
(d) comply with:
(1) AS 3000 Wiring Rules;
(2) applicable Australian Communications and Media Authority (ACMA) communications and cabling requirements;
(3) C-Tick compliance requirements;
(4) jurisdictional legislation, including safety legislation and regulations; and
(5) any reasonable requirements of the Local Network Service Provider when working on or around Local Network Service Provider .
Where a Metering Provider engages a sub-contractor to perform any of its obligations specified in the Rules , the Metering Provider :
(a) must have policies and procedures for assessing the sub-contractor's capability, competency and processes, procedures and systems, to ensure that they are compliant with the Rules ;
(b) must ensure that auditable processes are in place to certify that all work performed by the sub-contractor complies with the Rules ;
(c) remains liable for all acts and omissions of any sub-contractor; and
(d) must authorise the sub-contractor to provide any specific opinion or interpretation of technical information.
The Metering Provider must:
(a) hold public liability insurance for an amount not less than $10,000,000 per occurrence;
(b) hold professional indemnity insurance for an amount of not less than $1,000,000 per occurrence; and
(c) provide the Utilities Commission with certified current copies of insurance policies on request.
Note
If a Metering Data Provider, Metering Provider and Metering Coordinator are the same legal entity, a single insurance policy for public liability insurance for an amount not less than $10,000,000 per occurrence and professional indemnity insurance for an amount of not less than $1,000,000 per occurrence that covers the operations of the Metering Data Provider, Metering Provider and Metering Coordinator roles will satisfy the insurance requirements under this schedule.
S7A.8.4 Device management and test equipment
The Metering Provider must have processes and systems in place for the procurement of meters , instrument transformers and any other devices that can be installed by the Metering Provider within a metering installation , and ensure that metering installation components are suitable for use in accordance with the Rules .
(a) The Metering Provider must have processes that are consistent with good industry practice, specifying the requirements for storage, handling (including packaging) and transport (including return to owner) of any equipment that is calibrated including meters , instrument transformers and test equipment. The processes must be designed to:
(1) minimise the risk of physical or environmental damage to the equipment; and
(2) identify conditions under which the physical condition of the equipment or accuracy is compromised as a result of storage, transport or handling.
(b) The Metering Provider must ensure that meters , instrument transformers and devices removed from the metering installation are returned to their owner within 10 business days following their removal, unless otherwise agreed with the owner.
The Metering Provider must:
(a) establish a register of test equipment used for testing metering installations , meters and instrument transformers ;
(b) maintain records of test equipment, including records of calibration certificates, for at least 7 years from the issue date of the calibration certificate;
(c) ensure that all test equipment is calibrated by a NATA accredited testing laboratory holding ISO 9001 and 17025 accreditation for the calibration of test equipment, current at the time of calibration; and
(d) ensure that all tests are undertaken with test equipment where the calibration certificate is current and stated calibration due date has not passed.
The Metering Provider must:
(a) establish a register of equipment and authorised software used for programming meters ; and
(b) maintain records of equipment, authorised software and programs used for programming meters , including any changes to firmware or software within the meter , for at least 7 years from the most recent date of use.
S7A.8.5 Installation and commissioning requirements
The Metering Provider must develop, maintain and operate processes and procedures for the installation and commissioning of metering installations for which they are accredited, which must include installation and verification requirements to ensure that:
(a) electrical wiring at the metering installation is:
(1) wired and terminated in compliance with meter and instrument transformer manufacturer requirements, relevant Australian Standards and jurisdictional requirements;
(2) terminated in a manner that ensures no electrical conductors are exposed, that the cable type and size, and number of cables terminated in any one termination are appropriate and that all terminations are tight;
(3) of an appropriate cable type, size and insulation that meets the requirements of AS 3000;
(4) connected with the correct polarity at each termination and connection; and
(5) connected with the correct phase sequence, where three phases are connected at the metering installation ; in the case of a change to an existing metering installation , the existing phase sequence is maintained;
(b) the accuracy class of metering installations and any documentation from a certified body verifying the errors of meters and instrument transformers comply with the Rules ;
(c) nameplate information reflects the design accuracy class of the meters and instrument transformers ;
(d) the actual connected ratios of all instrument transformers at a metering installation and the calculation of the constant to be applied to the collection and processing of metering data by the Metering Data Provider are aligned;
(e) burdens applied to instrument transformers are within the rated burden specified on the name plate of the instrument transformer ;
(f) voltage phase sequence relationships are correct unless the Metering Provider can verify to the satisfaction of NTESMO the accuracy of the metering installation when a non-standard phase sequence is applied;
(g) the combined current and voltage phase relationships at the meter terminals are correct;
(h) the meter programming parameters, display and error functions are all correct in accordance with manufacturer specifications, including the measurement of the forward rotation of energy applied to the meter , and that the correct pulse rates have been programmed into the meter ;
(i) where the metering installation includes instrument transformers , register readings are validated by use of a load being placed on the load side of the metering installation and may include a timing check by comparing the readings on the meter display or pulse indicators against load and time;
(j) where the metering installation has meter alarms, occurrences of alarms identified on commissioning are investigated and resolved prior to leaving the site;
(k) where an aerial or antenna is installed as part of the metering installation , it is installed in accordance with the manufacturer's instructions and in a manner that maintains the integrity of the meter enclosure, including water and environmental seals; and
(l) the time setting of the metering installation is referenced in accordance with clause 7A.8.8.
The Metering Provider must develop, maintain and operate processes and procedures for the validation of interval metering data with the Metering Data Provider on the installation or alteration of that metering installation , which must include processes to ensure that:
(a) metering data is validated in accordance with schedule S7A.7;
(b) where validation has failed or cannot reasonably be undertaken, the Metering Provider informs the Metering Data Provider and the Metering Coordinator that the metering installation cannot be validated and undertake wiring checks which visibly verify correct connection and phase relationships of voltage and current circuits and also undertake one or more of the following alternative measurements and commissioning checks to enable the Metering Coordinator and Metering Provider to confirm that the metering installation complies with the Rules :
(1) utilisation of meter energy measurement to calculate load / demand and that this value is reflective of expected magnitude;
(2) use of a dummy load or phantom load box to verify correct energy measurement at the metering installation ; and
(3) compare meter measurement of energy or load with an alternative measurement of demand, current and other measurements of electrical energy;
(c) where the Metering Provider has undertaken in-situ testing to verify correct energy measurement at the metering installation , the Metering Provider informs the Metering Data Provider of the start and end times of the test to facilitate the Metering Data Provider substituting and validating metering data .
S7A.8.6 Metering installation maintenance
(a) The Metering Provider must develop and maintain Asset Test Plans that provide confirmation of the Metering Provider's testing approach to ensure metering installations are maintained:
(1) in accordance with the testing and inspection requirements of the Rules ;
(2) in accordance with approved Asset Management Strategies; or
(3) in any combination of the above.
(b) As a minimum, the Metering Provider's Asset Test Plans must include:
(1) the approach to testing and inspecting for each metering installation , or groups of metering installations ;
(2) where appropriate, the approach to testing and inspecting various device types; and
(3) the details of the test equipment and test methodology to be employed in undertaking works considered in the test plan.
(a) The Metering Provider must have processes and systems to support the Metering Coordinator in identifying and rectifying a metering installation malfunction in the timeframes specified in clause 7A.6.9.
(b) Where a Metering Provider identifies a metering installation malfunction, the Metering Provider must advise the Metering Data Provider and the Metering Coordinator within 1 business day of identification in accordance with paragraph 7A.6.9(d).
(a) The Metering Provider must advise the Metering Data Provider and the Metering Coordinator if communications equipment is to be temporarily disconnected such that it may affect the remote acquisition of metering data .
(b) The Metering Provider must use reasonable endeavours to assist the Metering Coordinator and the Metering Data Provider with the manual collection of metering data from the metering installation where remote acquisition becomes unavailable.
The Metering Provider must have a process for the management of non-conforming test results or calibrations at a metering installation , and for devices removed from a metering installation for testing and evaluation, which must include:
(a) a process to perform the evaluation of the non-conformance;
(b) authority for management of the non-conformance;
(c) notification of the non-conformance to parties affected by the non-conformance, which must include the Metering Coordinator , Metering Data Provider , financially responsible participant, Local Network Service Provider and NTESMO ; and
(d) initiation of corrective action.
S7A.8.7 Systems and administration
(a) The Metering Provider must establish and maintain a register of metering installations which must include:
(1) the identity and characteristics of metering equipment ( instrument transformers , metering installation and check metering installation ), including:
(i) serial numbers;
(ii) metering installation identification name;
(iii) metering installation types and models;
(iv) instrument transformer ratios (available and connected);
(v) current test and calibration programme details, test results and references to test certificates;
(vi) asset management plan and testing schedule;
(vii) calibration tables, where applied to achieve metering installation accuracy ;
(viii) Metering Provider (s) and Metering Data Provider (s) details;
(ix) summation scheme values and multipliers; and
(x) data register coding details;
(2) for metering installations for connection points in a market operated or administered by NTESMO – any matters identified by NTESMO in a communication guideline issued in from time to time accordance with clause S7A.1.3.
(b) The register must be retained electronically for at least 13 months for each metering installation from when the details of the metering installation are first recorded in the register and may be archived after this period.
(c) The register must be retained for at least 7 years for each metering installation from when the details of the metering installation are first recorded in the register and any archiving retrieval mechanisms must facilitate analysis and management of information using the same processing rules applied to the electronic register.
(d) The Metering Provider must provide information from their register of metering installations to a party authorised to receive data in accordance with clause 7A.13.5 in a timeframe agreed with that party.
(a) The Metering Provider must establish and maintain a disaster recovery plan and business continuity processes that include:
(1) detailed documentation that is maintained up to date, showing revisions and the date of the last review;
(2) confirmation at least annually by the Metering Provider's management that the plan is current for the systems and processes in place; and
(3) confirmation that the plan has been subjected to an annual end-to-end test that facilitates both a ‘fail-over' from and ‘recovery' back to the production system.
(b) In the event of an IT system failure, the Metering Provider must ensure that systems are returned to normal operational service within 5 business days of the failure, as evidenced by:
(1) the software and the most recent back-up of data being restored to operational service within the 5 business days ; and
(2) no outstanding processing or delivery of NT NMI Data to NTESMO and Registered Participants .
(c) The Metering Provider must at its earliest opportunity notify NTESMO of any failure where the Metering Provider has a requirement to implement its disaster recovery plan.
The Metering Provider must undertake all services in a manner that is auditable by the Utilities Commission and must provide all reasonable assistance to the Utilities Commission in discharging its obligations under the Rules and any relevant jurisdictional legislation in relation to metering installations .
Part C Metering Data Provider services
(a) The purpose of Part C of this schedule is to detail the obligations, technical requirements, measurement processes and performance requirements that are to be performed, administered and maintained by the Metering Data Provider .
(b) This Part details:
(1) the obligations of Metering Data Providers in the provision of metering data services;
(2) the obligations of Metering Data Providers to establish and maintain a metering data services database ; and
(3) the obligations of Metering Data Providers in support of the Metering Coordinator .
Metering data services
(a) Each Metering Data Provider must:
(1) provide metering data services in accordance with the Rules and relevant jurisdictional codes and policies;
(2) establish, maintain and operate a metering data services database ;
(3) ensure that metering data is kept confidential and secure and only provided to persons entitled to have such access in accordance with the Rules ;
(4) undertake the collection, processing and delivery of metering data and meter alarm occurrences; and
(5) co-operate in good faith with NTESMO, and all Registered Participants, Metering Providers and Metering Data Providers.
Insurance
(b) The Metering Data Provider must:
(1) hold public liability insurance for an amount not less than $10,000,000 per occurrence; and
(2) hold professional indemnity insurance for an amount of not less than $1,000,000 per occurrence.
Note
If a Metering Data Provider, Metering Provider and Metering Coordinator are the same legal entity, a single insurance policy for public liability insurance for an amount not less than $10,000,000 per occurrence and professional indemnity insurance for an amount of not less than $1,000,000 per occurrence that covers the operations of the Metering Data Provider, Metering Provider and Metering Coordinator roles will satisfy the insurance requirements under this schedule.
Use of sub-contactors
(c) Where a Metering Data Provider engages a sub-contractor to perform any of the Metering Data Provider's obligations specified in the Rules , the Metering Data Provider :
(1) must have policies and procedures for assessing the sub-contractor's capability, competency, processes, procedures and systems, to ensure that the sub-contractor complies with the Rules ;
(2) must ensure that auditable processes are in place to certify that all work performed by the sub-contractor complies with the Rules ;
(3) remains liable for all acts and omissions of its sub-contractor;
(4) must authorise the sub-contractor to provide any specific opinion or interpretation of technical information where a Metering Data Provider so engages a sub-contractor; and
(5) must provide the Utilities Commission , on request, with any information pertaining to the sub-contractor that the Utilities Commission reasonably considers necessary for the discharge of the Metering Data Provider's responsibilities under the Rules .
Specific obligations
(d) Each Metering Data Provider must:
(1) undertake validation, substitution and estimation of metering data in accordance with schedule S7A.7 Part C;
(2) provide metering data services ;
(3) ensure registered details of the connection point are fully recorded in the Metering Data Provider's metering data services database ;
(4) ensure metering details and parameters within the metering data services database are correct such that the metering data in the metering data services database is accurate;
(5) facilitate the timely commissioning and registration of the metering installation ; and
(6) establish and maintain a metering register in its metering data services database .
Metering register
(e) Each Metering Data Provider must ensure that information in its metering register is:
(1) registered in co-operation with the Metering Coordinator and Metering Provider ;
(2) provided on request to persons entitled to have access to that information in accordance with paragraph 7A.13.5(c);
(3) communicated to other Metering Data Providers having the right of access as a result of the transfer of a connection point ;
(4) populated with the following:
(i) connection and metering point reference details, including:
(A) agreed locations and reference details (for example, drawing numbers);
(B) loss compensation calculation details;
(C) site identification names;
(D) details of financially responsible participants and Local Network Service Providers associated with the connection point ;
(E) details of the Metering Coordinator ;
(ii) the identity and characteristics of metering equipment (that is, instrument transformers , metering installation and check metering installation ), including:
(A) serial numbers;
(B) metering installation identification name;
(C) metering installation types and models;
(D) Metering Provider (s) and Metering Data Provider (s) details;
(E) summation scheme values and multipliers; and
(F) data register coding details;
(iii) for types 1, 2, 3 and 4 metering installations , data communication details, if relevant, including:
(A) telephone number(s) for access to energy data;
(B) communication equipment type and serial numbers;
(C) communication protocol details or references;
(D) data conversion details;
(E) user identifications and access rights; and
(F) 'write' password (to be contained in a hidden or protected field);
(iv) data validation, substitution and estimation processes agreed between affected parties, including;
(A) algorithms;
(B) data comparison techniques;
(C) processing and alarms (for example, voltage source limits; phase angle limits);
(D) check metering compensation details; and
(E) alternate data sources; and
(5) for metering installations for connection points in a market operated or administered by NTESMO , includes any relevant matters identified by NTESMO in a communication guideline issued from time to time in accordance with clause S7A.1.3.
Each Metering Provider must maintain and operate a metering data services database to facilitate the:
(a) collection of metering data ;
(b) processing, calculation, validation, substitution and estimation of metering data ;
(c) delivery of metering data and metering register data to NTESMO , Registered Participants , financially responsible participants and other Service Providers;
(d) assignment and version control of participant roles for connection points ;
(e) commissioning of each metering installation into the Metering Data Provider's metering data services database ;
(f) loading of metering data relating to meter churn; and
(g) storage and archiving of metering data and validated metering data from the metering installation .
Each Metering Data Provider must maintain and operate a metering data services database that provides a full audit trail and version control capability. This functionality must be applied to:
(a) metering data ;
(b) assigned data quality flags;
(c) substitution and estimation types;
(d) meter alarms;
(e) metering register information;
(f) the delivery of metering data to Registered Participants , financially responsible participants and NTESMO ; and
(g) the mapping of all metering data streams (including logical metering data streams).
Each Metering Data Provider must maintain, operate and monitor a system that supports the detection of system or process errors. These exception reports must include, but not be limited to:
(a) missed reads and missing intervals of metering data within the metering data services database ;
(b) long term substitutions and estimations;
(c) metering data errors and data overlaps;
(d) validation or metering register errors;
(e) failed batch processing, database errors and hardware failures;
(f) the capture of file syntax errors, failed and rejected metering data deliveries;
(g) status management of collection interfaces; and
(h) status management of metering installation malfunctions .
(a) Each Metering Data Provider must use reasonable endeavours to ensure actual meter readings and occurrences of meter alarms are collected for all connection points .
(b) Each Metering Data Provider must operate a process that:
(1) records and logs faults and problems associated with the reading function of meters , and this process must record and log, but is not limited to, any:
(i) access problems;
(ii) metering installation security problems;
(iii) metering installation faults;
(iv) read failures; and
(v) metering installation time synchronisation errors; and
(2) supports the Metering Coordinator , the Metering Provider , or both, in the rectification of any metering installation malfunctions or problems associated with the reading function of meters .
(c) On request by the financially responsible participant, a Metering Data Provider must use reasonable endeavours to carry out a special meter reading or final reading within 3 business days of the receipt of the request unless an alternative timeframe has been agreed.
(a) Each Metering Data Provider must be capable of initiating a remote acquisition for metering data from type 1 to 3 metering installations where relevant metering data is missing, erroneous or has failed validation.
(b) Each Metering Data Provider must operate and maintain a process that:
(1) initiates an alternative method to collect metering data where remote acquisition becomes unavailable; and
(2) provides a log detailing successful reading events for each metering installation , or alternatively an exception report of failed meter readings.
Each Metering Data Provider must:
(a) develop and maintain a meter reading schedule in accordance with Schedule 7A.7 Part B;
(b) maintain reading routes with particular attention to any specific access requirements and hazard information;
(c) use reasonable endeavours to ensure that metering data is collected at least once every 3 months;
(d) ensure that scheduled reading date lists and programmed reading equipment is provisioned, updated and maintained;
(e) use reasonable endeavours to ensure that metering data is collected within 2 business days prior to or 2 business days subsequent to a scheduled reading date; and
(f) ensure that all metering data collected and any fault reason codes associated with a reading failure are transferred to the metering data services database within 1 business day of the data being collected or attempted to be collected from the metering installation .
General
(a) Each Metering Data Provider must have a process to:
(1) confirm and utilise the roles for connection points ;
(2) assign and store the date/time stamp of when the metering data was entered into the Metering Data Provider's metering data services database ;
(3) ensure that all metering data is stored in the metering data services database with the correct:
(i) quality flag;
(ii) applicable substitution or estimation type code; and
(iii) applicable substitution or estimation reason code;
(4) check the metering data services database for missing metering data and overlaps;
(5) aggregate interval metering data for a connection point into a 30-minute interval net metering data stream prior to delivery to NTESMO or financially responsible participants in accordance with the Rules ;
(6) load metering data in an alternative format provided by a Metering Provider where there is a communications error, failed reading or metering installation malfunction that prevents the normal collection of metering data from a metering installation ; and
(7) whenever any substitutions or estimations are carried out, notify:
(i) NTESMO (in respect of a metering installation used for the purposes of settlements );
(ii) Registered Participants for the connection point ; and
(iii) financially responsible participants (in respect of a metering installation used for the purposes of billing transactions ).
Erroneous data
(b) Where the Metering Coordinator or Metering Provider informs a Metering Data Provider of a situation that may cause metering data to be erroneous, the Metering Data Provider must identify and substitute any erroneous metering data .
(c) Where any Registered Participant for the connection point disputes metering data , the Metering Data Provider must investigate, and, if necessary correct the metering data in accordance with Schedule 7A.7 Part C.
Meter alarms
(d) Where a meter alarm has occurred, the Metering Data Provider must process the occurrence of the meter alarm along with the metering data as part of the validation process in accordance with Schedule 7A.7 Part C.
Each Metering Data Provider must be able to undertake simple cumulative or subtractive processes to manage complex metering configurations. Typically, the system must support:
(a) an A+B+C or A-B-C aggregation configuration;
(b) validation capability for standard partial or check meter connection points that incorporate a simple comparison of a single metering data stream to a single check metering data stream within an acceptable tolerance; and
(c) the calculation of the average of the 2 validated data sets for metering installations where the check metering installation duplicates the metering installation and accuracy level, and the average of the 2 validated data sets must be delivered to:
(1) NTESMO (in respect of a metering installation used for the purposes of settlements );
(2) Registered Participants ; and
(3) financially responsible participants (in respect of a metering installation used for the purposes of billing transactions ).
Inventory tables, load tables and on/off tables
(a) Each Metering Data Provider must store inventory tables, load tables and on/off tables in the metering data services database
(b) Each Metering Data Provider must ensure:
(1) inventory tables are complete, correct and updated with any changes provided by the Local Network Service Provider or Metering Coordinator ;
(2) on/off tables are complete and correct; and
(3) load tables are complete and correct.
(c) Each Metering Data Provider must ensure the inventory table, load table and on/off table are versioned for metering data calculations.
Processing of calculated metering data
(d) Each Metering Data Provider must ensure that all calculated metering data is validated and processed into recording intervals .
(a) Each Metering Data Provider must have a process for the creation of estimated metering data for type 4A, 5, 6 and 7 metering installations .
(b) To meet metering data delivery requirements, this process must either:
(1) create individual blocks of estimated metering data on a daily basis; or
(2) create a single block of estimated metering data :
(i) from the date of the last meter reading to a period beyond the next scheduled reading date for type 4A, 5 and 6 metering installation s; or
(ii) from the date of the last calculation to a period beyond the next scheduled calculation for type 7 metering installations .
Obligation to deliver information to NTESMO
(a) Where this clause S7A.8.9.11 imposes an obligation on a Metering Data Provider to deliver metering data or other information to NTESMO , that obligation only applies in respect of a metering installation that is used for the purposes of settlements .
Obligation to deliver information to financially responsible participants
(b) Where this clause S7A.8.9.11 (other than paragraph S7A.8.9.11(e)) imposes an obligation on a Metering Data Provider to deliver metering data or other information to financially responsible participants, that obligation only applies in respect of a metering installation that is used for the purposes of billing transactions .
Validated metering data to be delivered
(c) Each Metering Data Provider must ensure only validated metering data is delivered to NTESMO , Registered Participants and financially responsible participants.
Delivery timing requirements
(d) Subject to any agreement to the contrary as contemplated by clause S7A.8.13.1, each Metering Data Provider must:
(1) deliver to NTESMO , Registered Participants and financially responsible participants all actual meter readings that passed validation within 2 business days of the actual meter readings being received into the metering data services database ;
(2) substitute, validate and deliver to NTESMO , Registered Participants and financially responsible participants the substituted metering data within 2 business days of the actual meter readings being received into the metering data services database and failing validation;
(3) substitute, validate and deliver to NTESMO, Registered Participants and financially responsible participants the substituted metering data within 2 business days of the receipt of any fault reason codes associated with a reading failure or failed interrogation event, into the metering data services database ;
(4) validate and deliver to NTESMO , Registered Participants and financially responsible participants all substituted metering data within 2 business days of the metering data being substituted;
(5) ensure that all metering data is delivered to NTESMO , Registered Participants and financially responsible participants for the full period of any retrospectively created metering data streams within 2 business days of that metering data streams being created; and
(6) for type 4A, 5, 6 and 7 metering installations , validate and deliver to NTESMO , Registered Participants and financially responsible participants all estimated metering data within 2 business days of the metering data being estimated.
(e) Each Metering Data Provider must provide metering data to the relevant financially responsible participants within 2 business days of receiving a completed notification of a change of financially responsible participants, including estimated metering data , for a type 4A, 5, 6 or 7 metering installation.
Review of failed validations
(f) Each Metering Data Provider must ensure that all failed validations are reviewed promptly so as to:
(1) where the initial review of the failed validation identifies that the actual meter readings are valid, deliver the actual meter readings to NTESMO , Registered Participants and financially responsible participants within 2 business days of the metering data being received into the metering data services database ; and
(2) where further information is required to validate the actual meter readings, and the receipt of such information identifies that the actual meter readings are valid, deliver the actual meter readings to NTESMO , Registered Participants and financially responsible participants within 2 business days of the metering data passing validation.
Operational delays
(g) The Metering Data Provider must notify NTESMO and affected Registered Participants immediately upon the identification of any operational delays impacting on normal metering data delivery.
S7A.8.10 Data management following the alteration of type of
metering installation at a connection point
(a) Meter churn can result in a change to the configuration of metering data recorded by a metering installation . This change in metering data may result in an alteration to the Metering Data File Format file.
(b) Where a meter churn takes place, each Metering Data Provider must:
(1) comply with the Metering Data File Format requirements when constructing the Metering Data File Format file associated with the change in type of metering installation ; and
(2) for a meter churn scenario described in an item of column 1 of the following table, comply with the requirements for the management of metering data described in the provision listed in column 2 of that item of the following table:
|
Column 1 Meter churn scenario |
Column 2 Provision |
|---|---|
|
A metering installation is changed from a type 6 metering installation to a new type 6 metering installation (Scenario 1) |
Clause S7A.8.10.2 |
|
A metering installation is changed from a type 6 metering installation to a type 1, 2, 3, 4, 4A, or 5 metering installation (Scenario 2) |
Clause S7A.8.10.3 |
|
A metering installation is changed from a type 1, 2, 3, 4, 4A, or 5 metering installation to a type 6 metering installation (Scenario 3) |
Clause S7A.8.10.4 |
|
A metering installation is changed from a type 1, 2, 3, 4, 4A, or 5 metering installation to a new type 1, 2, 3, 4, 4A, or 5 metering installation (Scenario 4) |
Clause S7A.8.10.5 |
The Metering Data Provider must have a process to ensure that:
(a) the final accumulation meter reading(s) from the removed type 6 metering installation are applied at the end of the day prior to the meter churn;
(b) the start reading(s) for a new type 6 metering installation are applied at the start of the day of the meter churn; and
(c) estimated metering data is provided for any metering data streams made active as a result of the meter churn.
(a) The Metering Data Provider must have a process to ensure that:
(1) the final accumulation meter reading(s) from the removed type 6 metering installation are applied at the end of the day prior to the meter churn;
(2) the metering data for the new type 1, 2, 3, 4, 4A, or 5 metering installation commences at the start of the day of the meter churn; and
(3) estimated metering data is provided for any metering data streams made active as a result of the meter churn for a new type 4A or type 5 metering installation .
(b) The Metering Data Provider must have a process to ensure that the metering data for the period of the meter churn day between the start of the day and the commissioning of the new metering installation is provided as zeroes with a quality flag of F.
Where reversion from a type 1, 2, 3, 4, 4A, or 5 metering installation to a type 6 metering installation is permitted, the Metering Data Provider must have a process to ensure that:
(a) the final reading(s) from the removed type 1, 2, 3, 4, 4A, or 5 metering installation cease at the end of the day of the meter churn;
(b) the metering data for the period of the meter churn day between commissioning of the new metering installation and the end of the day of the meter churn is provided as zeroes with a quality flag of F; and
(c) the start reading(s) for the new type 6 metering installation are applied at the start of the day following the day of the meter churn.
Each Metering Data Provider must have a process to ensure compliance with the following requirements:
(a) the final reading(s) from the removed type 1, 2, 3, 4, 4A, or 5 metering installation is collected up to the removal of the old metering installation on the day of the meter churn;
(b) the metering data for the new type 1, 2, 3, 4, 4A, or 5 metering installation commences at the start of the day of the meter churn;
(c) the Metering Data Provider related to the new metering installation must obtain metering data for the period of the meter churn day between the start of the meter churn day and the removal of the old metering installation from the Metering Data Provider related to the old metering installation ;
(d) the Metering Data Provider related to the new metering installation must combine the metering data from the old metering installation and the new metering installation for the day of meter churn and deliver metering data for the whole day of meter churn;
(e) where meter churn results in a change to the recording of metering data from 15-minute to 30-minute intervals, the 15-minute intervals of metering data from the start of the meter churn day until the commissioning of the new metering installation are to be aggregated to form interval metering data ;
(f) where meter churn results in a change to the recording of metering data from 30-minute to 15-minute intervals:
(1) the 15-minute intervals of metering data from the commissioning of the new metering installation to the end of the meter churn day are to be aggregated to form 30-minute interval metering data ; or
(2) the 30-minute intervals of metering data for the start of the meter churn day may be disaggregated to form 15-minute interval metering data , where agreed with the Metering Coordinator ;
(g) estimated metering data is provided for any metering data streams made active as a result of the meter churn for a new type 4A or type 5 metering installation ;
(h) where meter churn results in a metering data stream being made active, the Metering Data Provider related to the new metering installation must provide metering data from the start of the day to the commissioning of the new metering installation by providing zeroes with a quality flag of F;
(i) where meter churn results in a metering data stream being made inactive, the Metering Data Provider must provide metering data from the commissioning of the new metering installation to the end of the day by providing zeroes with a quality flag of F; and
(j) the Metering Data Provider must create final substituted metering data for the period between the existing metering installation being removed and the commissioning of the new metering installation .
S7A.8.11 System architecture and administration
Each Metering Data Provider must have retrieval mechanisms (both electronic and archived) that allow the metering data retained in its metering data services database under clause 7A.8.3 to be accessed , recovered, re-evaluated and delivered in agreed timeframes to NTESMO , Registered Participants or financially responsible participants.
All metering data and metering register information must be backed-up, at a minimum, on a daily basis and held in a secure environment.
Requirement for disaster recovery plan
(a) Each Metering Data Provider must ensure that a disaster recovery plan is established and in place to ensure that in the event of a system failure, its IT systems can be returned to normal operational service within 2 business days .
(b) The Metering Data Provider must ensure that the disaster recovery plan is:
(1) up to date with all documentation showing revisions; and
(2) witnessed and dated at least annually by the Metering Data Provider as being current for the systems and processes in place.
Fall-over system approach
(c) Where a Metering Data Provider adopts a disaster recovery plan that has a complete ‘fail-over' system approach, the disaster recovery plan must be subjected to a test annually that facilitates a full ‘fail-over' to the recovery system.
Segmented system approach
(d) Where the Metering Data Provider adopts a disaster recovery plan that has a segmented system approach, the disaster recovery plan must:
(1) detail the interfaces and relationships between system segments;
(2) be established for each individual system segment;
(3) be tested annually with evidence retained to show disaster recovery for each individual system segment; and
(4) have, for each individual system segment, a procedure that clearly details the process to establish a return to full operation.
Testing
(e) Expected evidence to support disaster recovery plan testing should include, but not be limited to:
(1) a test plan of the fail-over;
(2) results of the fail-over including timing;
(3) system logs indicating fail-over and recovery; and
(4) logs or notations evidencing resumption of Metering Data Provider operations.
Actions following system failure
(f) If a system failure occur s , the Metering Data Provider must ensure that within 2 business days :
(1) its metering data services database is restored to operational service; and
(2) all processing and delivery backlogs of metering data to NTESMO and Registered Participants is completed.
Notice to NTESMO of activation of disaster recovery plan
(g) The Metering Data Provider must, at its earliest opportunity, notify NTESMO of any failure where the Metering Data Provider has a requirement to activate its disaster recovery plan.
Metering data services database
(a) The metering data services database must be operated and administered by a Metering Data Provider to facilitate:
(1) controlled access to systems and data using unique identification and passwords for each user;
(2) the restriction of access to the underlying database tables to nominated system administrators;
(3) the restriction of Registered Participant access to metering data and NT NMI data in accordance with paragraph 7A.13.5(c);
(4) a minimum of 95% system availability (that is, hardware and systems downtime do not exceed a maximum of 438 hours per annum).
Metering register
(b) Each Metering Data Provider must maintain full audit trails and version control of metering register information, metering data for at least 7 years so that any data output produced by the system can be re-produced from source data.
(a) Audits may be undertaken at any time by the Utilities Commission in accordance with the Rules and may be carried out following a request from a Registered Participant .
(b) Where an audit of a metering installation is conducted by the Utilities Commission under clause 7A.7.4, and metering data must be obtained from the Metering Data Provider in support of this audit, the Metering Data Provider must provide the metering data within 2 business days of the Utilities Commission's request.
(c) Each Metering Data Provider must assist the Utilities Commission with reasonable requests for the provisioning of metering data and relevant information relating to connection points that are part of the audit process of Metering Coordinators , Metering Providers and Metering Data Providers .
(a) Each Metering Data Provider must take corrective action on any reported instances of non-compliance identified by NTESMO or through a Metering Data Provider audit process.
(b) Where a Metering Data Provider becomes aware that incorrect metering data has been delivered to NTESMO and Registered Participants , the Metering Data Provider must provide corrected metering data to all affected parties within 1 business day as required by paragraph 7A.8.3(d).
(c) NTESMO may request corrective action where errors or omissions are found within the settlements process and such requests are to be actioned as a priority by the Metering Data Provider .
(d) Where the Metering Data Provider cannot deliver the corrected metering data in the timeframe specified above, the Metering Data Provider must advise NTESMO and agree on an alternative delivery time.
Provision of data
(a) A Registered Participant may request a Metering Data Provider to:
(1) provide metering data in an alternative format, method or timeframe;
(2) provide any other metering data services ; or
(3) any combination of the above.
No data to be provided
(b) A Registered Participant may request a Metering Data Provider to not provide or deliver any metering data to the Registered Participant as required under this Part.
System changes not required
(c) There is no requirement for a Metering Data Provider to implement system changes and processes to facilitate bilateral agreements.
Bilateral agreement not to impact metering data delivery to NTESMO
(d) Any acceptance by a Metering Data Provider to deliver metering data to a Registered Participant in accordance with any agreement contemplated by this clause S7A.8.13.1 or acceptance to not provide any metering data in accordance with such an agreement must not impact on metering data delivery to NTESMO or any other Registered Participant for the connection point(s) concerned.
Bilateral agreement to be auditable
(e) Any bilateral agreement established between a Registered Participant and a Metering Data Provider must be in writing and made available to the Utilities Commission on request for audit purposes.
Each Metering Data Provider must operate and retain a quality system that is at least equal to a quality accreditation to the ISO9001 or ISO9002 standards.
After clause 8.1.3, heading
insert
Note
Clause 8.1.3(b)(5) and (7) has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ).
After Chapter 8, Part B, heading
insert
Note:
This Part has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016 ).
After clause 8.6.1, heading
insert
Note
Clause 8.6.1(d) and (e) has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ).
After clause 8.6.2, heading
insert
Note
Clause 8.6.2(l) has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ).
Clause 8.6.5
repeal, insert
must indemnify the AER
and the AEMC
against any claim, action, damage, loss, liability, expense or outgoing which the AER
or the AEMC
pays, suffers, incurs or is liable for in respect of any breach by that Registered Participant
or any officer, agent or employee of that Registered Participant
of this rule 8.6
.
After clauses 8.6.6 and 8.6.7, headings
insert
Note
This clause has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ).
(1) Clause 8.7.1(b)(1)
omit
and AEMO
(2) Clause 8.7.1(c)(3)
omit
, all Registered Participants and AEMO
insert
and all Registered Participants
(1) Clause 8.7.2, heading
omit, insert
8.7.2 Reporting requirements and monitoring standards for Registered Participants
Note
Clause 8.7.2(a)(2) and (4) and (b)(2) has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ).
(2) Clause 8.7.2(a)(5)
omit
or AEMO
(3) Clause 8.7.2(b)(1)
omit
, AEMO
(4) Clause 8.7.2(b)(1)
omit
, (4)
(5) Clause 8.7.2(c)
omit
AEMO and
(6) Clause 8.7.2(e)
omit (all references)
and AEMO
(7) Clause 8.7.2(f)
omit
all words from "neither" to "be)"
insert
a Registered Participant must not recklessly or knowingly provide, or permit any other person to provide on behalf of that Registered Participant
(8) Clause 8.7.2(g)
omit
or AEMO
(9) Clause 8.7.2(g) and (h)
omit
and/or AEMO (as the case may be)
(10) Clause 8.7.2(g)
omit
and (to the extent relevant) AEMO
After clause 8.7.6, heading
insert
Note
Clause 8.7.6 has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ).
After Chapter 8, Parts E and G, headings
insert
Note
This Part has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ).
After Chapter 8, Part H, heading
insert
Note:
This Part has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016 ).
(1) Chapter 10, definitions accumulated energy data", "accumulated metering data , application to connect", "business day , calculated metering data", "check meter , check metering data , "check metering installation", connection point , "control centre", Customer , customer authorised representative", "day , Distribution Network Service Provider", "distribution system , estimated metering data", "facilities , financially responsible , "Generator", interval energy data , interval metering data", "Metering Coordinator , Metering Data Provider", "metering data services , metering data services database", "metering installation malfunction , "Metering Provider", National Electricity Law , "national grid", Network Service Provider , "NMI", nominal voltage , nominated pass through event considerations", "positive change event, power system , "regulatory control period", remote acquisition , "Rules", substituted metering data , "telecommunications network", time , transmission network", "Transmission Network Service Provider , transmission or distribution system and unmetered connection point
omit
(2) Chapter 10
insert (in alphabetical order)
1st regulatory control period
In relation to a Network Service Provider in this jurisdiction, means the first period during which the provider will be or is subject to a control mechanism imposed by a distribution determination, being the period from 1 July 2019 to 30 June 2024.
2009-14 NT regulatory control period
The regulatory control period that commenced on 1 July 2009 under the NT Network Access Code .
2014-19 NT regulatory control period
The regulatory control period that commenced on 1 July 2014 under the NT Network Access Code .
2014 NT Ministerial Direction
The direction issued by the shareholding Minister of Power and Water Corporation ABN 15 947 352 360 to the board of the Corporation under section 8(4)(a) of the Government Owned Corporations Act (NT), dated 19 June 2014.
2014 NT Network Price Determination
The "2014 Network Price Determination" made by the Utilities Commission under the Utilities Commission Act (NT), Electricity Reform Act (NT) and Chapter 6 of the NT Network Access Code that:
(a) applies, or applied, from 1 July 2014 to 30 June 2019; and
(b) because of section 57 of the Electricity Networks (Third Party Access) Act (NT), is, or was, a network pricing determination made under section 6A(1) of that Act,
as amended, varied or substituted from time to time.
The data that results from the measurement of the flow of electricity in a power conductor where the data represents a period in excess of a recording interval
is held in the metering installation
. The measurement is carried out at a metering point
.
, once collected from a metering installation
, is accumulated metering data
is held in a metering data services database .
An application made by a Connection Applicant
in accordance with Chapter 5, Part A for connection
to a network
and/or the provision of network services
or modification of a connection
to a network
and/or the provision of network services
.
Australian Central Standard Time (ACST)
The time that is set at 9 hours and 30 minutes in advance of Co-ordinated Universal Time .
business day
A day that is not:
(a) a Saturday or Sunday; or
(b) a public holiday as defined in section 17 of the Interpretation Act (NT) (other than a public holiday that is part of a day) in the City of Darwin.
calculated metering data
The recording interval data corresponding to the calculation of consumed energy for a type 7 metering installation in accordance with schedule 7A.7. Calculated metering data is held in the metering data services database.
An additional meter used as a source of check metering data for type 1 and type 2 metering installations as specified in schedule 7A.4.
check metering data
The energy data
, once collected from a check metering installation
, is check metering data
is held in a metering data services database .
that includes a check meter
which is used as the source of check metering data
for data validation.
connection point
The agreed point of supply
established between Network Service Provider
(s) and another Registered Participant
.
control centre
The facilities used by NTESMO for managing power system security and administering a market .
Customer
A person who:
(a) under Part 3 of the Electricity Reform Act (NT), holds a licence authorising the selling of electricity; but
(b) does not hold a licence authorising the ownership or operation of an electricity network under that Part.
customer authorised representative
A person authorised by a retail customer
to request and receive information under Chapter 7A on the retail customer's
behalf.
Unless otherwise specified, the 24 hour period beginning and ending at midnight Australian Central Standard Time .
Distribution Network Service Provider
A person who:
(a) engages in the activity of owning, controlling, or operating a distribution system ; and
(b) under Part 3 of the Electricity Reform Act (NT), holds a licence authorising the ownership or operation of an electricity network.
distribution system
Means:
(a) a distribution network , together with the connection assets associated with the distribution network , which is connected to another transmission or distribution system within the other participating jurisdictions ; or
(b) a distribution network that forms part or all of a local electricity system, together with the connection assets associated with the distribution network .
Connection assets on their own do not constitute a distribution system .
estimated metering data
The estimated values of accumulated metering data , interval metering data or calculated metering data that have been prepared in accordance with schedule 7A.7. Estimated metering data is held in a metering data services database.
facilities
A generic term associated with the apparatus, equipment, buildings and necessary associated supporting resources provided at, typically:
(a) a power station or generating unit ;
(b) a substation or power station switchyard ;
(c) a control centre (being an NTESMO control centre , or a distribution or transmission network control centre );
(d) facilities providing an exit service .
financially responsible
In relation to a connection point
, a term which is used to describe the person authorised to have either:
1. the load connected at that connection point
; or
2. the generating unit
at that connection point
.
Note:
The obligations on Customers (including retailers) and Generators in relation to the authorisation of, respectively, load or generating units connected at a connection point will be considered as part of the phased implementation of the Rules in this jurisdiction.
A person who:
(a) engages in the activity of owning, controlling or operating a generating system that is connected to, or who otherwise supplies electricity to, a transmission or distribution system ; and
(b) is a Registered Participant who, under Part 3 of the Electricity Reform Act 2000 (NT), holds a licence authorising the generation of electricity.
For the purposes of Chapter 5, the term includes a person who:
(a) is required or intends to hold a licence authorising the generation of electricity;
(b) is covered by an exemption from the requirement to hold a licence for the generation of electricity;
(c) is a non-registered embedded generator (as defined in clause 5A.A.1) who has made an election under clause 5A.A.2(c); or
(d) is a non-registered embedded generator (as defined in clause 5A.A.1) above the relevant materiality threshold (as defined in Chapter 5).
interval energy data
The data that results from the measurement of the flow of electricity in a power conductor where the data is prepared and recorded by the metering installation
in intervals which correspond to a recording interval
or are submultiples of a recording interval
is held in the metering installation
.
A meter that records interval energy data.
interval metering data
, once collected from a metering installation
is held in a metering data services database .
Metering Coordinator
A person appointed to the role of Metering Coordinator in this jurisdiction.
Metering Data Provider
A person appointed to be a Metering Data Provider for a connection point .
The services that involve the collection, processing, storage and delivery of metering data
and the management of relevant NT NMI data in accordance with the Rules
.
metering data services database
The database established and maintained by the Metering Data Provider
that holds metering data
and NT NMI data relating to each metering installation
for which the Metering Coordinator has appointed the
to provide metering data services
.
metering installation malfunction
The full or partial failure of the metering installation in which the metering installation :
(a) does not meet the requirements of schedule 7A.4;
(b) does not record, or incorrectly records, energy data ; or
(c) does not allow, or provide for, collection of energy data .
Metering Provider
A person appointed to be a Metering Provider for a connection point .
National Electricity Law
The National Electricity (NT) Law.
national grid
The sum of:
(a) all connected transmission systems and distribution systems within the other participating jurisdictions ; and
(b) the transmission systems and distribution systems in this jurisdiction.
Network Service Provider
A Distribution Network Service Provider or Transmission Network Service Provider .
NMI
A National Metering Identifier issued by the relevant Network Service Provider .
The design voltage
level, nominated for a particular location on the power system
, such that power lines and circuits that are electrically connected other than through transformers have the same nominal voltage
regardless of operating voltage
.
nominated pass through event considerations
The nominated pass through event considerations
are:
(a) whether the event proposed is an event covered by a category of pass through event
specified in clause 6.6.1(a1)(1AA) to (4) (in the case of a distribution determination) or clause 6A.7.3(a1)(1) to (4) (in the case of a transmission determination
);
(b) whether the nature or type of event can be clearly identified at the time the determination is made for the service provider;
(c) whether a prudent service provider could reasonably prevent an event of that nature or type from occurring or substantially mitigate the cost impact of such an event;
(d) whether the relevant service provider could insure against the event, having regard to:
(1) the availability (including the extent of availability in terms of liability limits) of insurance against the event on reasonable commercial terms; or
(2) whether the event can be self-insured on the basis that:
(i) it is possible to calculate the self-insurance premium; and
(ii) the potential cost to the relevant service provider would not have a significant impact on the service provider's ability to provide network services
; and
(e) any other matter the AER
considers relevant and which the AER
has notified Network Service Providers
is a nominated pass through event consideration.
NT equivalent services
Regulated network access services (as defined in clause 3 of the NT Network Access Code ) that are designated as direct control services in Table 3.1 of Part A of the 2014 NT Network Price Determination .
NT Network Access Code
The Network Access Code as defined in section 2A(1) of the Electricity Networks (Third Party Access) Act (NT).
NT NMI data
The following data in respect of a connection point :
(a) the NMI of the connection point and the street address of the relevant connection point to which that NMI is referable;
(b) the NMI checksum for the connection point ;
(c) the identity of the relevant Network Service Provider ;
(d) the relevant distribution loss factor applicable to the connection point;
(e) the Network Tariff (identified by a code) applicable in respect of the connection point ;
(f) the read cycle date, or date of next scheduled read or date in a relevant code representing the read cycle date or date of next scheduled read, for that connection point ,
and, to avoid doubt, does not include any metering data or other details of an end-user's consumption at that connection point .
positive change event
For a Distribution Network Service Provider
which entails the Distribution Network Service Provider
incurring materially
higher costs in providing direct control services
than it would have incurred but for that event, but does not include a contingent project
or an associated trigger event
.
For a Transmission Network Service Provider
which entails the Transmission Network Service Provider
incurring materially
higher costs in providing prescribed transmission services
than it would have incurred but for that event, but does not include a contingent project
or an associated trigger event
.
The electricity power system of the national grid
including associated generation
and transmission
for the supply
of electricity, operated as an integrated arrangement or arrangements.
recording interval
A 30 minute period ending on the hour ( Australian Central Standard Time ) or on the half-hour and, if identified by a time, means the 30 minute period ending at that time.
regulatory control period
In respect of a Network Service Provider
, a period of not less than 5 regulatory years
for which the provider is subject to a control mechanism imposed by a distribution determination.
remote acquisition
The acquisition of interval metering data
from a telecommunications network connected to a metering installation
that:
(a) does not, at any time, require the presence of a person at, or near, the interval meter
ing installation for the purposes of data collection or data verification (whether this occurs manually as a walk-by reading or through the use of a vehicle as a close proximity drive-by reading); and
(b) includes but is not limited to methods that transmit data via:
(1) fixed-line telephone (‘direct dial-up');
(2) satellite;
(3) the internet;
(4) wireless or radio, including mobile telephone networks;
(5) power line carrier; or
(6) any other equivalent technology.
Rules
The National Electricity Rules as defined in section 2(1) of the National Electricity Law .
substituted metering data
The substituted values of accumulated metering data , interval metering data or calculated metering data prepared in accordance with schedule 7A.7. Substituted metering data is held in a metering data services database .
telecommunications network
A telecommunications network that provides access for public use.
time
Australian Central Standard Time .
transmission network
Any of the following:
(a) a network in this jurisdiction operating at nominal voltages of 66kV and above;
(b) a network or part of a network prescribed by local instrument to be a transmission network or part of a transmission network ,
but does not include a network or part of a network prescribed by local instrument not to be a transmission network or part of a transmission network.
For a participating jurisdiction other than the State of Victoria, an identified shared user asset owned, controlled or operated by a Primary Transmission Network Service Provider (including a third party IUSA that is the subject of a network operating agreement ) forms part of that Primary Transmission Network Service Provider's transmission network .
Note:
The National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016 are a local instrument.
Transmission Network Service Provider
A person who:
(a) engages in the activity of owning, controlling or operating a transmission system ; and
(b) under Part 3 of the Electricity Reform Act (NT), holds a licence authorising the ownership or operation of an electricity network.
transmission or distribution system
A transmission system or a distribution system.
unmetered connection point
at which a meter
is not necessary under schedule 7A.1.
Utilities Commission
The Utilities Commission of the Northern Territory established by section 5 of the Utilities Commission Act (NT).
(3) Chapter 10, definition applicable regulatory instruments , at the end
insert
(6A) Northern Territory:
(a) the Electricity Reform Act (NT);
(b) all instruments made and licences granted under the Electricity Reform Act (NT);
(c) the Utilities Commission Act (NT); and
(d) all instruments made under the Utilities Commission Act (NT).
(4) Chapter 10, definition franchise customer , at the end
insert
Note:
There are no franchise customers in this jurisdiction.
(1) Chapter 10, definitions access standard", "connection alteration , connection contract", "Dedicated Connection Asset Service Provider , "dispatch", distribution network user access , "embedded network", funded augmentation , "generating system", Incoming Retailer , Local Network Service Provider", "market , market load", "metering register , normal voltage , "performance standard", plant , power system security", "profile , retail customer , "satisfactory operating state", secure operating state", "settlements , settlements ready data , system standard and transmission consultation procedures
omit
(2) Chapter 10
insert
access standard
A particular technical requirement as recorded in a connection agreement.
billing transaction
The activity of producing bills and credit notes in markets that are not operated or administered by NTESMO .
connection alteration
Has (in the context of Chapters 5A and 7A) the meaning given in clause 5A.A.1.
connection contract
Has (in the context of Chapters 5A and 7A) the meaning given in clause 5A.A.1.
Dedicated Connection Asset Service Provider
A Transmission Network Service Provider to the extent that it owns or operates a dedicated connection asset in accordance with a licence under the Electricity Reform Act 2000 (NT).
dispatch
The act of initiating or enabling all or part of the response to an instruction issued to a Generator to synchronise , supply ancillary services , or supply energy .
distribution network user access
The power transfer capability of the distribution network in respect of:
(a) generating units or a group of generating units ; and
(b) network elements ,
at a connection point which has been negotiated in accordance with rules 5.3, 5.3A and 5.3AA.
Note:
For the avoidance of doubt, distribution network user access extends to the transmission network for the purposes of Chapter 6.
electricity retail supply code
The Electricity Retail Supply Code made by the Utilities Commission under section 24 of the Utilities Commission Act 2000 (NT) (as published by the Utilities Commission from time to time).
embedded network
A distribution system that is connected to a distribution system controlled or operated by the Local Network Service Provider (other than a distribution system that is owned, controlled or operated by the Local Network Service Provider ).
energy ombudsman
The person holder or occupying the office of Ombudsman for the Northern Territory established by section 9 of the Ombudsman Act 2009 (NT).
funded augmentation
A transmission network augmentation for which the Transmission Network Service Provider is not entitled to receive a charge pursuant to Chapter 6.
generating system
(a) Subject to paragraph (b), for the purposes of the Rules , a system comprising one or more generating units .
(b) For the purposes of Chapter 5, a system comprising one or more generating units and includes auxiliary or reactive plant that is located on the Generator's side of the connection point and is necessary for the generating system to meet its performance obligations .
Incoming Retailer
A retailer that:
(a) that has a contract with a customer at a connection point ; and
(b) has initiated the customer transfer process in accordance with the electricity retail supply code ,
but which is not yet designated the financially responsible participant for that connection point .
Local Network Service Provider
Power and Water Corporation ABN 15 947 352 360.
market
Means:
(a) except for the purposes of Chapter 7A:
(i) a market or exchange operated or administered by NTESMO , whether being a market for energy or any other market or exchange; or
(ii) a market or exchange for energy that is not operated or administered by NTESMO ; and
(b) for the purposes of Chapter 7A, a market or exchange for energy .
market load
A load for an NMI classified by the relevant retailer or, with the consent of the financially responsible person for that load , by some other person, as a market load . There can be more than one market load at any one connection point.
metering register
A register of information associated with a metering installation as required by schedule 7A.1 .
new meter deployment
The replacement of an existing electricity meter of one or more small customers which is arranged by a retailer , other than where the replacement is:
(a) at the request of the relevant small customer or to enable the provision of a product or service the customer has agreed to acquire from the retailer or any other person;
(b) a maintenance replacement; or
(c) required as a result of a metering installation malfunction .
normal voltage
In respect of a connection point , its nominal voltage or such other voltage up to 10% higher or lower than normal voltage , as approved by NTESMO , for that connection point , at the request of the Network Service Provider who provides connection to the power system.
NTESMO (being the Northern Territory Electricity System and Market Operator )
As the case requires:
(a) the entity that undertakes the performance of the functions set out in the Rules that relate to monitoring or controlling the operation of the power system in respect of one or more of the local electricity systems; or
(b) the entity that undertakes the performance of the functions set out in the Rules that relate to operating or administering a market in respect of one or more of the local electricity systems.
performance standard
A standard of performance that:
(a) is established as a result of it being taken to be an applicable performance standard in accordance with jurisdictional electricity legislation ; and
(b) forms part of the terms and conditions of a connection agreement .
"plant"
In relation to a connection point , includes all equipment involved in generating, utilising or transmitting electrical energy.
power system security
The safe scheduling, operation and control of the power system on a continuous basis in accordance with the principles set out in jurisdictional electricity legislation.
Note:
The principles that will be set out in jurisdictional electricity legislation in the above definition will correspond to principles set out in clause 4.2.6 in the Rules applying in other participating jurisdictions.
profile
Metering data or costs for a longer period than a recording interval allocated into recording intervals .
retail customer
Has the same meaning as in the National Electricity Law.
Note:
In the context of Chapter 5A, the above definition has been supplemented by a definition specifically applicable to that Chapter. See clause 5A.A.1.
satisfactory operating state
In relation to the power system , has the meaning given in jurisdictional electricity legislation .
Note:
The meaning given in jurisdictional electricity legislation in the above definition will correspond to the meaning given in clause 4.2.2 in the Rules applying in other participating jurisdictions.
secure operating state
In relation to the power system , has the meaning given in jurisdictional electricity legislation .
Note:
The meaning given in jurisdictional electricity legislation in the above definition will correspond to the meaning given in clause 4.2.4 in the Rules applying in other participating jurisdictions.
settlements
The activity of producing bills and credit notes in markets operated or administered by NTESMO.
settlement ready data
The metering data that has undergone a validation and substitution process by NTESMO for the purposes of settlements and is held in the metering database .
system standard
A standard for the performance of the power system as set out in jurisdictional electricity legislation that:
(a) is necessary for the safe and reliable operation of the power system;
(b) is necessary for the safe and reliable operation of the facilities of Registered Participants ; and
(c) is consistent with good electricity industry practice.
transmission consultation procedures
The procedures set out in Part H of Chapter 6A (as applying in the other participating jurisdictions ) that must be followed by:
(a) the AER in making, developing or amending guidelines, models or schemes or in reviewing methodologies; or
(b) the AEMC in developing or amending guidelines.
(1) Chapter 10, definitions approved pass through amount , negative pass through amount and positive pass through amount
omit
(2) Chapter 10
insert (in alphabetical order)
approved pass through amount
In respect of a positive change event for a Transmission Network Service Provider :
(a) the amount which the AER determines should be passed through to Transmission Network Users under clause 6A.7.3(d)(2); or
(b) the amount which the AER is taken to have determined under clause 6A.7.3(e)(1),
as the case may be.
In respect of a positive change event or NT positive change event for a Distribution Network Service Provider :
(a) the amount the AER determines should be passed through to Distribution Network Users under clause 6.6.1(d)(2) or 6.6.1AB(d)(2); or
(b) the amount the AER is taken to have determined under clause 6.6.1(e)(1) or 6.6.1AB(e)(1),
as the case may be.
Note:
The modification to this definition expires on 1 July 2024.
negative pass through amount
In respect of a negative change event for a Transmission Network Service Provider , an amount that is not greater than a required pass through amount as determined by the AER under clause 6A.7.3(g).
In respect of a negative change event or NT negative change event for a Distribution Network Service Provider , an amount that is not greater than a required pass through amount as determined by the AER under clause 6.6.1(g) or 6.6.1AB(g).
Note:
The modification to this definition expires on 1 July 2024.
NT negative change event
A negative change event (as defined in Part B of the 2014 NT Network Price Determination ) for a Distribution Network Service Provider :
(a) that occurred during the 2014-19 NT regulatory control period ; and
(b) in relation to which, on or before 30 June 2019, a determination had not been made under clause 3.1.5(a) of Part B of the 2014 NT Network Price Determination and the time for making it had not expired.
Note:
This definition expires on 1 July 2024.
NT positive change event
A positive change event (as defined in Part B of the 2014 NT Network Price Determination ) for a Distribution Network Service Provider :
(a) that occurred during the 2014-19 NT regulatory control period ; and
(b) in relation to which, on or before 30 June 2019, either:
(i) a statement had not been submitted under clause 3.1.2 of Part B of the 2014 NT Network Price Determination and the time fixed for submitting it had not expired; or
(ii) a statement had been submitted under clause 3.1.2 of Part B of the 2014 NT Network Price Determination but a determination had not been made under clause 3.1.3(a) of Part B of the Determination and the time for making it had not expired.
Note:
This definition expires on 1 July 2024.
For a Transmission Network Service Provider
, an amount (not exceeding the eligible pass through amount
) proposed by the provider under clause 6A.7.3(c).
For a Distribution Network Service Provider
, an amount (not exceeding the eligible pass through amount
) proposed by the provider under clause 6.6.1(c) or 6.6.1AB(c).
Note:
The modification to this definition expires on 1 July 2024.
(3) Chapter 10, definition eligible pass through amount , at the end
insert
In respect of an NT positive change event for a Distribution Network Service Provider , the increase in costs in the provision of direct control services or NT equivalent services that, as a result of that NT positive change event , the Distribution Network Service Provider has incurred and is likely to incur (as opposed to the revenue impact of that event) until the end of the 1st regulatory control period .
Note:
The modification to this definition expires on 1 July 2024.
(4) Chapter 10, definition required pass through amount , at the end
insert
In respect of an NT negative change event for a Distribution Network Service Provider , the costs in the provision of direct control services or NT equivalent services that, as a result of the NT negative change event , the Distribution Network Service Provider has saved and is likely to save (as opposed to the revenue impact of that event) until the end of the 1st regulatory control period .
Note:
The modification to this definition expires on 1 July 2024.
Chapter 10
insert (in alphabetical order)
2nd regulatory control period
In relation to a Network Service Provider in this jurisdiction, means the second period during which the provider will be or is subject to a control mechanism imposed by a distribution determination, being the period from 1 July 2024 to 30 June 2029.
Note:
This definition expires on 1 July 2029.
Chapter 10, definition energy laws
omit, insert
energy laws
Means:
(a) the national electricity legislation as defined in the National Electricity Law ;
(b) these Rules and instruments made under these Rules ;
(c) the national gas legislation as defined in the National Gas (NT) Law;
(d) the National Gas Rules as defined in the National Gas (NT) Law and instruments made under those Rules; and
(e) any other Northern Territory legislation that regulates energy.
Note:
The modifications to this definition expire when the National Energy Retail Law is applied as a law of this jurisdiction.
After Chapter 11, heading
insert
Note:
Parts A to ZZI, ZZK, ZZL, ZZN (except for clause 11.86.8), ZZO to ZZT, ZZV and ZZX have no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ). The application of those Parts may be revisited as part of the phased implementation of the Rules in this jurisdiction.
Clause 11.93.1, definition subsequent regulatory control period
omit, insert
subsequent regulatory control period of:
(a) Power and Water Corporation – means the 1st regulatory control period ; or
(b) another affected DNSP or affected TNSP – means the regulatory control period for that affected DNSP or affected TNSP that immediately follows the current regulatory control period.
After Chapter 11
insert
11A. NT Savings and Transitional Rules
Part A Savings and transitional rules for Chapter 5
11A.1 Chapter 5 provisions
(1) In
this Rule:
regulatory investment test means a regulatory investment test under Part D of Chapter 5.
(2) A Primary Transmission Network Service Provider is not required to publish or provide information under clause 5.2A.5(a) until 1 July 2020.
(3) A Distribution Network Service Provider is not required to have and publish its first information pack under clause 5.3A.3(a)(3) until 1 July 2020.
(4) A Distribution Network Service Provider is not required to include in its first Distribution Annual Planning Report published under clause 5.13.2 the information specified in clause S5.8(a)(5) if information on energy and demand forecasts was not required to be reported by the Distribution Network Service Provider under jurisdictional electricity legislation applicable at the time the previous report was prepared.
(5) The requirement to undertake a regulatory investment test does not apply in relation to:
(a) a project that was assessed by the AER for the purposes of its distribution determination for Power and Water Corporation (ABN 15 947 352 360) for the period of 5 years commencing on 1 July 2019; or
(b) a project where an assessment equivalent to a regulatory investment test has been commenced by Power and Water Corporation before 1 July 2019.
(6) A Transmission Network Service Provider is not required to comply with clause 5.18A.3(f) until 1 July 2024 in relation to the content of an impact assessment under that clause.
Part B Savings and transitional rules for Chapter 5A
Note
Part B of this Chapter has no effect in this jurisdiction until 1 July 2019 (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ).
In this Rule:
NT distributor means Power and Water Corporation ABN 15 947 352 360.
relevant provisions means Chapter 5A and Chapter 6, Part DA.
transition date means the date on which the transition period ends.
transition period means the period from the commencement of the 1st regulatory control period (being 1 July 2019) to 30 June 2020.
During the transition period:
(a) a basic connection service includes not only a connection service for which a model standing offer has been approved by the AER (see paragraph (c) of the definition in clause 5A.A.1) but also one for which the AER's approval of a model standing offer is not required;
(b) a standard connection service includes not only a connection service for which a model standing offer has been approved by the AER (see the definition in clause 5A.A.1) but also one for which the AER's approval of a model standing offer is not required; and
(c) a model standing offer includes a document prepared and published by the NT distributor, without the AER's approval, as a model standing offer to have effect during the transition period (but not beyond the end of that period).
(a) During the transition period, the relevant provisions operate subject to the exclusions, qualifications and modifications prescribed by this Rule.
(b) However, the relevant provisions operate without the exclusions, qualifications and modifications prescribed by this Rule insofar as they relate to:
(1) a period beyond the transition period; or
(2) a person (such as a new entrant to the industry) that is not the NT distributor.
Example
If the NT distributor submits a regulatory proposal for the regulatory control period that follows the transition period, the distributor is bound by the relevant provisions (without exclusion, qualification or modification) in relation to the regulatory proposal even though the proposal is submitted during the transition period.
(c) A transaction commenced by or with the NT distributor during the transition period may be continued and completed after the transition period without regard to changes to the rules governing the transaction that take effect at the end of the transition period.
During the transition period, the relevant provisions apply to, and in relation to, the NT distributor subject to the following exclusions, qualifications and modifications:
Model standing offers (basic connection services)
(a) A document, prepared by the NT distributor and published on the NT distributor's website, will (although not approved by the AER ) be regarded as a model standing offer to provide basic connection services during the transition period if it complies with the requirements of clause 5A.B.2(b) as to its terms and conditions.
(b) If, during the transition period, the AER approves a model standing offer for the same basic connection services , the approved model standing offer supersedes the former model standing offer under this clause.
(c) The NT distributor's obligation to have a model standing offer to provide basic connection services (clause 5A.B.1) operates during the transition period but the AER's approval of the model standing offer is not required until the transition date.
(d) The NT distributor's obligation to submit for the AER's approval a proposed model standing offer to provide basic connection services (clause 5A.B.2(a)) does not arise until 31 December 2019.
Model standing offer (standard connection services)
(e) A document, prepared by the NT distributor and published on the NT distributor's website, will (although not approved by the AER ) be regarded as a model standing offer to provide standard connection services during the transition period if it complies with the requirements of clause 5A.B.4(c) as to its terms and conditions.
(f) If, during the transition period, the AER approves a model standing offer for the same standard connection services , and the approved model standing offer is to take effect before the end of the transition period, the approved model standing offer supersedes the former model standing offer .
(g) The NT distributor may submit for the AER's approval a model standing offer to provide standard connection services (clause 5A.B.4) during the transition period but the AER's approval of the standing offer is not required until the transition date.
Amendment of standing offers
(h) During the transition period, the NT distributor may amend a standing offer to provide basic connection services or standard connection services during the transition period by publishing the amendments and the amended text on its website. (This paragraph applies during the transition period to the exclusion of clause 5A.B.6.)
A reference to any of the relevant provisions in a legislative or other instrument will be construed, during the transition period, as a reference to the provision as modified by this Rule.
Part C Savings and transitional rules for Chapter 7A
Note
Part C of this Chapter has no effect in this jurisdiction until 1 July 2019 (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations ). The application of Part C will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(a) This rule applies in relation to a metering installation installed at a connection point on a transmission network or distribution network in this jurisdiction that is in service immediately before 1 July 2019.
(b) The following requirements must be complied with in relation to the metering installation :
(1) the requirements imposed on a metering installation at a connection point on a distribution network or transmission network in this jurisdiction by, under or for the purposes of a law of this jurisdiction that is in force immediately before 1 July 2019 (the NT requirements ); and
(2) the requirements imposed in respect of the metering installation by the Rules .
(c) The requirements imposed in respect of the metering installation by the following provisions are taken to be complied with:
(1) clause 7A.6.2(a);
(2) clause 7A.6.3(a);
(3) clause 7A.6.4, other than paragraph (b);
(4) clause 7A.6.5;
(5) schedule 7A.1, other than clause S7A.1.3;
(6) clause S7A.3.2.2;
(7) schedule 7A.5.
(d) For the purposes of the operation of Chapter 7A in respect of the metering installation , a reference in:
(1) clause 7A.7.2 to "the technical requirements";
(2) clause 7A.7.3 to "requirements of the Rules ";
(3) clause 7A.7.4 to "schedule 7A.1" or "relevant accuracy requirement";
(4) clause 7A.8.7 to "schedule 7A.1";
(5) clause S7A.3.2.2(c) to "requirements of the Rules "; and
(6) Chapter 10, definition metering installation malfunction , to "the requirements of schedule 7A.1",
must be regarded as a reference to "the NT requirements".
(e) If the metering installation is replaced on or after 1 July 2019, paragraphs (b) to (d) no longer apply in respect of the metering installation .
The time periods for testing of metering installations under Table S7A.6.1.2 do not apply to metering installations that are at least 10 years old on 1 July 2019 until 1 July 2022.
(1) The Metering Data Provider for this jurisdiction on 1 July 2019 is not, on or after that date, required to comply with all the requirements under rule 7A.8 relating to establishing and maintaining a metering data services database but the following requirements will apply:
(a) the Metering Data Provider must ensure that all of those requirements under rule 7A.8 are complied with by 31 March 2025 (with the period between 1 July 2019 and 31 March 2025 being referred to as the transitional period ), including by acquiring, gaining or upgrading computing capabilities, equipment and other assets and materials, and establishing or enhancing processes and systems, to ensure compliance;
(b) during the transitional period, the Metering Data Provider must, insofar as is reasonably practicable, use its existing resources and capabilities (and any upgraded, enhanced, additional or new resources and capabilities as they become reasonably available) to comply with those requirements under rule 7A.8, especially in relation to the validation, substitution and estimation of metering data in its metering data services database ; and
(c) without limiting paragraph (b), the Metering Data Provider must use its best endeavours to:
(i) maximise the quality of metering data ; and
(ii) maximise transparency in processes for verifying, validating, calculating and estimating metering data .
(2) During the transitional period:
(a) the requirements imposed by clause S7A.7.13.5(c)(4) and (5) will not apply in relation to the Metering Data Provider ;
(b) the Metering Data Provider is only required to include information, data and matters on its metering register in accordance with the requirements of clause S7A.8.8.2(e)(4) to the extent that it is reasonably able to do so; and
(c) the reference in clause S7A.8.8.2(e)(5) to a communication guideline, in its application to the Metering Data Provider , will be taken to be a reference to the interim communication guideline prepared by NTESMO under rule 11A.6.
(3) In addition, during the transitional period:
(a) the Metering Provider is only required to include information, data and matters on a register of metering installations in accordance with the requirements of clause S7A.8.7.1(a)(1) to the extent that it is reasonably able to do so; and
(b) the reference in clause S7A.8.7.1(a)(2) to a communication guideline, in its application to the Metering Provider , will be taken to be a reference to the interim communication guideline prepared by NTESMO under rule 11A.6.
(4) For the transitional period, if information about a metering installation is included in the metering register , then the metering installation is to be taken, for the purposes of Chapter 7A, to be registered with NTESMO .
NTESMO is not required to have a comprehensive communication guideline in place under clause S7A.1.3 until the Metering Data Provider is in a position to comply with its obligations under rule 7A.8 relating to establishing and maintaining a metering data services database , after taking into account the operation of rule 11A.5, but the following requirements will apply:
(a) NTESMO must have an interim communication guideline in place by 1 January 2020;
(b) the interim communication guideline must comply with the requirements of clause S7A.1.3(c), (d) and (e) insofar as is reasonably practicable and after taking into account the Metering Data Provider's resources and capabilities during the period applying under clause 11A.5(1)(a);
(c) NTESMO must maintain the interim communication guideline until the M etering Data Provider is in a position to comply the obligations under rule 7A.8, and may review and vary the interim communication guideline from time to time; and
(d) NTESMO must revise or replace the interim communication guideline so that a comprehensive communication guideline is in place when the M etering Data Provider is in a position to comply with its obligations under rule 7A.8.
(1) In this rule:
"commencement date" means 1 July 2019.
maintenance replacement means the replacement of a retail customer's existing meter arranged by a retailer that is based on the results of sample testing of a meter population carried out in accordance with Chapter 7A:
(a) which indicates that it is necessary or appropriate, in accordance with good electricity industry practice, for the meter to be replaced to ensure compliance with Chapter 7A; and
(b) details of which have been provided to the retailer under Chapter 7A, together with the results of the sample testing that support the need for the replacement.
"new meter deployment "means the replacement of an existing meter of one or more retail customers which is arranged by a retailer other than where the replacement is:
(a) at the request of the relevant retail customer or to enable the provision of a product or service the retail customer has agreed to acquire from the retailer or any other person;
(b) a maintenance replacement; or
(c) as a result of a metering installation malfunction .
(2) This rule applies where, before the commencement date, a retailer has an outstanding request for a meter to be installed, including in relation to a new connection , at a retail customer's premises and that request does not relate to a new meter deployment or a metering installation malfunction (an existing metering installation request ).
(3) On and from the commencement date, Chapter 7A will apply to an existing metering installation request as if:
(a) the timeframe for the meter to be installed for the purposes of clause 7A.6.10(a)(2) ends at the later of:
(i) 6 business days from the date the retailer is informed that the connection service (as defined in clause 5A.A.1) is complete; and
(ii) 6 business days from the commencement date;
(b) for the purposes of clause 7A.6.11(a)(2), the retailer received the request from the retail customer on the commencement date; and
(c) for the purposes of clause 7A.6.12(a)(1)(ii) and (d), the retailer received the request from the retail customer on the commencement date.
Schedule 3 Further modifications to operation of National Electricity Rules commencing on 1 December 2017
This Schedule modifies the operation of the National Electricity Rules with effect on and from 1 December 2017.
Clause 8.6.1A
repeal, insert
For the purposes of this Part only, " Registered Participant " is deemed to include not just Registered Participants but also Metering Providers and Metering Data Providers .
Chapter 10, definition retail customer
omit, insert
retail customer
Has the same meaning as in the National Electricity Law
.
Otherwise, a person to whom electricity is sold by a retailer
, and supplied in respect of connection points
, for the premises of the person, and includes a person (or a person who is of a class of persons) prescribed by these Rules
for the purposes of this definition.
Note:
In the context of Chapter 5A, the above definition has been supplemented by a definition specifically applicable to that Chapter. See clause 5A.A.1.
Schedule 4 Further modifications to operation of National Electricity Rules commencing on 1 July 2019
This Schedule modifies the operation of the National Electricity Rules with effect on and from 1 July 2019.
Chapter 10, definition Registered Participant
omit, insert
Registered Participant
Each of the following:
(a) a Registered participant as defined in the National Electricity Law ;
(b) for the purposes of the Rules , other than Chapter 5, Part A – a Metering Coordinator ;
(c) as set out in clause 8.6.1A, for the purposes of Chapter 8, Part C – a Metering Provider or Metering Data Provider .
