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2020ELECTRICITY DISTRIBUTION SERVICES
DEFAULT PRICE-QUALITY PATH
ANNUAL COMPLIANCE STATEMENT
For the year ending 31 March 2020
Pursuant to the Electricity Distribution Services Default Price-Quality Path Determination 2015
6 August 2020
2
Table of Contents 1. Introduction ......................................................................................................................................... 3
2. Compliance with the Price Path (Clause 11.2(a)(i)) ......................................................................... 4
Price path compliance approach .......................................................................................................... 5
3. Compliance with the Quality Standards (Clause 11.2(a)(ii)) .......................................................... 9
Quality standards compliance summary ............................................................................................. 9
2020 Reliability Assessment (9.1(a))...................................................................................................... 9
Prior Period Reliability Assessment (9.1(b)) ....................................................................................... 10
Quality of supply summary 2019/2020 .............................................................................................. 11
4. Director Certification (Clause 11.3(a)) ............................................................................................ 15
5. Assurance Report (Clause 11.3(b)) .................................................................................................. 16
Appendix A Price Path Compliance Calculations (Clause 11.4(c)) ....................................................... 19
Appendix B Pass-through Balance and Pass-through & Recoverable Costs (Clause 11.4(e) – (k)) . 20
Description of the methodology used to calculate Distribution Prices and Pass-through Prices
(clause 11.4(e)(i) ..................................................................................................................................... 21
Appendix C Price and Quantity Schedules (Clause 11.4(c) – (d)) ......................................................... 23
Appendix D Transmission Assets, Transactions and Restructuring of Prices (Clauses 11.2(d) and
11.6 – 11.8) ................................................................................................................................................. 37
Introduction ........................................................................................................................................... 37
Background ............................................................................................................................................ 37
Price restructures .................................................................................................................................. 37
Appendix E Quality Standard Compliance and Incentive (Clause 11.5(c), (d) and (f)) ...................... 41
Quality Incentive Calculations ............................................................................................................. 42
Major Event Days (MED) ....................................................................................................................... 43
Appendix F Policies and Procedures for Recording SAIDI and SAIFI (Clause 11.5(e)) ...................... 44
3
1. Introduction
TLC complies with the default price-quality price path for the 2020 Assessment Period as this
document demonstrates. Our compliance headroom is $1.1m.
The Lines Company Limited (TLC) restructured prices on 1 October 2018 and moved to our new
pricing (kWh time-of-use and anytime) for ‘non-major’ customers. There are several price
restructure compliance considerations for TLC in the RY2020 year:
• Deriving kW quantities for demand prices to September 2018;
• Deriving kWh quantities for new prices from October 2018;
• Adjustments to lagged kW quantities due to changes in business rules up to September 2018;
• New Pricing Transition Discounts from April 2019 to September 2019.
Also, TLC continues to estimate the prompt payment discount offered to customers1.
TLC does not comply with the default price-quality quality standards for the 2020 Assessment
Period. This document provides a discussion of TLC’s quality non-compliance.
1 TLC has included the prompt payment discount into prices from 1 April 2020.
4
2. Compliance with the Price Path (Clause 11.2(a)(i))
TLC does comply with the default price-quality price path at the assessment date, 31 March 2020,
as specified in the Electricity Distribution Services Default Price-Quality Path Determination 2015.
Clause 8.3 The notional revenue (NR) of a Non-exempt EDB in the Assessment Period must not
exceed the allowable notional revenue (ANR) for the Assessment Period.
Compliance is demonstrated in the following table, which details that notional revenue during the
Assessment Period does not exceed allowable notional revenue.
Table 1 Demonstration of compliance with the default price-quality price path
Supporting evidence is presented in Appendices A, B, C and D.
Test:
NR2019/20 40,153,738$
ANR2019/20 41,226,139$
Result < 1
Result Price path is compliant
0.974
NR 2019/20 ≤ ANR 2019/20
5
Price path compliance approach
There are several price restructure compliance considerations for TLC in the 2020 year2:
• Deriving kW quantities for demand prices up to September 2018;
• Deriving kWh quantities for new prices from October 2018;
• Adjustments to lagged kW quantities due to changes in business rules up to September 2018;
• New Pricing Transition Discounts from April 2019 to September 2019.
TLC continues to estimate the prompt payment discount offered to customers.
1. Deriving kW quantities for demand prices to September 2018
The kW quantities for each connection are constant across a pricing year. kW charges are
expressed as a $/kW/month line charge. Accordingly, revenue from kW charges is constant each
month of the pricing year for each connection. This occurs because the kWs used for billing
purposes reflect demand in the prior year i.e. the prior year peaks determine the kW measure for
each customer’s connection in the pricing year.
For allowable notional revenue (ANR) in the 2020 Assessment Period, the quantity associated with
each price is the kW quantity billed during the 2018 Assessment Period i.e. 1 April 2017 to 31 March
2018. This quantity measure is derived from peak demand largely during the winter of 2016. Thus,
the kW charge in any pricing year is independent of demand behaviour in that year. Accordingly,
kW charges are not seasonal. As the kW charges only applied for the 1 April 2018 – 30 September
2018 period, the kW charge is applied for six months rather than 12, for the 2020 ANR. This applies
for those ICPs connected to the network between 1 April 2017 and 30 September 2017, using the
kW quantities billed at that time i.e. t-2. This is illustrated in table 1 below:
Winter 2016 April 2017 to September
2017 (t-2) April 2018 to September
2018 (t-1)
Quantity (kW) Average of 6 x 2-hour peaks during load control periods
= kW per ICP
kW per ICP (from 2016 winter demand)
kW per ICP (from 2016 winter demand)
Quantity (ICP) Connected ICPs by consumer
group for demand (kW) pricing
Connected ICPs from April 2017 to September 2017
Price ($/kW) Fixed $/kW/month (from 1
April 2017) Fixed $/kW/month (from 1
April 2018)
Revenue kW x $/kW/month= fixed
monthly charge x 6 kW x $/kW/month= fixed
monthly charge x 6
Actual revenue Used for ANR
Table 2 Deriving ANR kW quantities and prices for 2020 Assessment Period
1. Deriving kWh quantities for new prices from October 2018
2. Deriving kWh quantities for new prices from October 2018
The restructured prices were introduced from 1 October 2018. A key component of the restructure
was a switch from kW-based pricing to kWh-based pricing. kWh based pricing is charged based on
the actual kWhs consumed in the pricing period. The new kWh-based prices include TOU prices
(reflecting energy consumption during peak, shoulder and off-peak pricing periods) and Anytime
2 Relating to standard customer connections less than 150 kVA
6
prices (which apply to all consumption, irrespective of the time of day). Anytime prices apply where
TOU metering is not available.
For the purpose of calculating NR, kWh quantities must reflect the 1 April 2017 to 31 March 2018
period (t-2), while kWh quantities must reflect the 1 October 2017 to 31 March 2018 period (t-1)
for the purpose of calculating ANR.
TLC’s historical datasets include half-hourly kWh data or register read data for individual ICPs for
this period for most connections. This data has been used as a basis for deriving the quantities
which correspond to the new kWh-based prices. Also, TLC has considered the demand response
to the new pricing structure and has adjusted the historical data to reflect the observed response
since the new prices came into effect on 1 October 2018.
In summary, TLC has observed an increase in total consumption, after considering weather-
related impacts, but no discernible change in the demand profile (i.e. the time of use) for the first
six months of the new pricing. Our analysis indicates that the kWh quantities have increased by a
factor of approximately 4.5%. This adjustment has been applied to t-2 quantities, increasing ANR
and NR by $384K and $838K respectively, decreasing the ANR/NR difference by $454K in the 2020
Assessment Period. ANR and NR are different, in part, due to the timing differences for deriving
kWh quantities as table 3 below demonstrates.
The table below summarises the deriving ANR kW quantities for demand prices to September 2018
and deriving kWh quantities for new prices from October 2018.
RY2020 Compliance
2017/18 (t-2) 2018/19 (t-1) 2019/20 (t)
Apr – Sep Oct – Mar Apr – Sep Oct – Mar Apr – Mar
Allowable Notional Revenue
kW Quantities TOU Quantities kW Prices TOU Prices
Notional Revenue TOU Quantities TOU Prices
Table 3 Summary of the derivation of quantities and prices for 2020 Assessment Period
2. Metering charges associated with new prices from October 2018
3. Adjustments to lagged kW quantities due to changes in business rules to September
2018
As in previous Assessment Periods, price restructures for kW charges have occurred, as the
business rules for establishing kW quantities occurred during the kW measurement period used
for price path compliance. These price restructures impact ANR and only apply for the first six
months. These restructures are detailed in Appendix D.
4. New Pricing Transition Discounts from April 2019
As part of TLC’s TOU price restructure, we implemented a New Pricing Transition Discount to cap
line charge increases from 1 October 2018 to 30 September 2019. The cap was set at +20% of the
lines charges which applied to each customer’s connection, immediately prior to the new pricing
coming into effect.
The New Pricing Transition Discount formed part of TLC’s pricing arrangements with customers, it
was assessed quarterly and included as a credit on TLC invoices to customers. TLC calculated and
applied the discount to a customer’s total invoices for the applicable period.
7
For the avoidance of doubt and to determine the correct treatment of the New Pricing Transition
Discount, TLC reviewed the Electricity Distribution Services Input Methodologies Determination
2012 definitions of prices and discount:
‘Prices’3 means-
(a) individual tariffs, fees or charges; or
(b) individual components thereof,
in nominal terms exclusive of GST for the supply of an electricity distribution service, and must
include a discount taken up by consumers.
'discount'4 means a discount to charges payable for the supply of electricity distribution services-
(a) that is offered by an EDB;
(b) the take-up of which is determined by consumers; and
(c) that is included in the individual tariffs, fees, or charges (or individual components thereof) used
to calculate forecast revenue from prices for the disclosure year that those individual tariffs, fees,
or charges apply to.
The New Pricing Transition Discount did not form part of TLC’s electricity distribution service
prices; hence TLC has excluded it from the default price-quality price path assessment.
5. Basis of estimates
The Lines Company Limited offers a 10% prompt payment discount (PPD) on most of our charges.
The PPD available is included in our schedule of prices, where we publish two sets of prices (before
and after the deduction of the PPD, where applicable). The take-up of the PPD is determined by
consumers, as the receipt of the discount is based on the date of payment.
Our default price-quality price path is demonstrated in table 1. Notional revenue is a product of
posted prices multiplied by corresponding billed quantities. In accordance with the 2015 DPP
Determination, quantities are lagged two years, and thus for this compliance statement, reflect
2018 billable quantities.
The price and quantity schedules included in Appendix C, therefore, include two sets of prices and
two sets of quantities comprising:
• pre-PPD posted prices and post-PPD posted prices;
• quantities for each based on the estimated take-up of the PPD.
As we do not have sufficient data to be able to determine for each price, the actual billed quantities
where PPD has been applied, and the actual billed quantities where PPD has not been applied, for
the 2020 Assessment Period we have estimated the quantities using the following method.
We have estimated the split between 2018 quantities with PPD applied, and 2018 quantities with
no PPD applied. Due to system limitations, the quantity splits have been estimated by reference
to the PPD values applied and not applied to applicable consumers. In 2018, the PPD was applied
(by value) to 90.10% of the PPD offered. We note that the PPD is applied in full to Major Customers
(standard and non-standard) charges and Streetlight charges. Also, De-Energisation and Re-
Energisation charges receive no PPD.
3 Electricity Distribution Services Input Methodologies Determination 2012, clause 3.1.1(9). 4 Electricity Distribution Services Input Methodologies Determination 2012, clause 3.1.1(11).
8
Also, the above exercise was undertaken to adjust the 2020 pass-through and recoverable
revenue. In 2020, the PPD was applied (by value) to 87.20% of the PPD offered.
9
3. Compliance with the Quality Standards (Clause 11.2(a)(ii))
TLC does not comply with the requirements of the default price-quality quality standards at the
assessment date, 31 March 20, as specified in the Electricity Distribution Services Default Price-Quality
Path Determination 2015.
Quality standards compliance summary
Clause 9.1 A Non-exempt EDB must, in respect of each Assessment Period, either:
(a) comply with the annual reliability assessment specified in clause 9.2 for that Assessment
Period; or
(b) have complied with the annual reliability assessment in each of the two preceding Assessment
Periods.
Table 4 Demonstration of non-compliance with the default price-quality quality standards
TLC has exceeded the SAIDI compliance limit for the 2020 Assessment period. This represents non-
compliance as TLC exceeded the SAIDI limits for the 2017/18 and 2018/19 Assessment Periods.
TLC did not exceed the SAIFI limit for the 2020 Assessment Period but did for the 2017/2018 and
2018/2019 Assessment Periods.
Supporting evidence is presented in Appendices E and F.
2020 Reliability Assessment (9.1(a))
Clause 9.1(a) requires compliance with Clause 9.2: To comply with the annual reliability
assessment for the current Assessment Period:
• a Non-exempt EDB's SAIDI Assessed Values for the Assessment Period must not exceed the
SAIDI Limit specified in Schedule 4A; and
SAIDI SAIFI Compliance
Exceeds limit Does not exceed limit Does not comply
or
Compliance with 9.1(b) Does not comply
2018/19 Assessment Period Exceeds limit Exceeds limit Does not comply
2017/18 Assessment Period Exceeds limit Exceeds limit Does not comply
Clause 9.1 Result: Does not comply
Compliance with 9.1(a)
2019/20 Assessment Period
10
• a Non-exempt EDB's SAIFI Assessed Values for the Assessment Period must not exceed the
SAIFI Limit specified in Schedule 4A.
Table 5 2020 Reliability Assessment (9.1(a))
Prior Period Reliability Assessment (9.1(b))
Clause 9.1(b): A Non-exempt EDB must have complied with the annual reliability assessments in
each of the two preceding Assessment Periods.
Non-compliance is demonstrated in the following tables.
Table 6 Prior Period Reliability Assessment (9.1(b))
Test:
SAIDI Assess 2019/20 271.42
SAIDI Limit 234.18
> 1
Clause 9.1(a) Result: Exceeds limit
Test:
SAIFI Assess 2019/20 3.00
SAIFI Limit 3.47
0.865 < 1
Clause 9.1(a) Result: Does not exceed limit
SAIDI Assess 2019/20 ≤ SAIDI Limit
SAIFI Assess 2019/20 ≤ SAIFI Limit
1.159
285.55 SAIFI Assess 2018/19 4.41
SAIDI Limit 2018/19 234.18 SAIFI Limit 2018/19 3.47
> 1 1.271 > 1
Exceeds limit Exceeds limit
243.34 SAIFI Assess 2017/18 3.75
SAIDI Limit 2017/18 234.18 SAIFI Limit 2017/18 3.47
> 1 1.081 > 1
Exceeds limit Exceeds limit
SAIDI Assess 2018/19
1.219
1.039
SAIDI Assess 2017/18
11
Quality of supply summary 2019/2020
The 2020 regulatory year saw TLC exceed its cap for the SAIDI quality measure by 37.3 minutes
per customer. This outcome was driven by significant SAIDI contributions from outages caused by
vegetation and third-party damage. The increase in unplanned SAIDI in RY2020 from vegetation
and third-party damage was 94.6 raw SAIDI minutes more than TLC’s historical average5. Almost
all of that increase fell in the second half of the regulatory year (from October to March) resulting
from a sequence of high impact vegetation and third-party damage events that were higher than
historical norms. We have provided more detail in relation to the causes of SAIDI quality non-
compliance below.
Based on our analysis of our performance in RY2017 to RY2020, the principal challenges we face
on an ongoing basis relate to vegetation management and inherently low security of supply.
We are committed to improving our reliability performance, and we have continued our focus on
that objective in our 2018, 2019 and 2020 AMPs. We are continuing to make significant
investments in vegetation management, reliability, and security of supply. As these projects are
completed, we expect they will provide ongoing improvements to our reliability performance.
Continuation of Higher Vegetation Related Outages
TLC continued to experience higher than normal vegetation-related outages in RY20. Historically,
vegetation-related outages have contributed approximately 30 minutes per customer to SAIDI6.
However, in RY20 vegetation outages contributed approximately 75 minutes per customer to
SAIDI. No vegetation outages were above TLC’s MED limit of 10.97 minutes. In total TLC
experienced 82 outages, with 12 of those outages resulting in 54.7 SAIDI minutes or 72% of
vegetation SAIDI.
Six of these top 12 outages were related to forestry plantations and accounted for 33 SAIDI
minutes, indicating that maturing plantations on the network are emerging as a present risk factor
for TLC. The two largest outages (by SAIDI) occurred one month apart in an area of the network
where there was low security of supply, and no 11kV backfeed was possible. A generator was
deployed and connected to restore supply to the ca. 150 customers affected by the damaged line
while repairs were undertaken. These two outages were caused by trees outside of the trim zone
damaged by high winds (18 December 2019 and 4 January 2020). An image of the damaged area
is shown in Figure 1.
5 RY2010 to RY2016. Raw data assessment. 6 The average for the period 2010 to 2016 (prior to the application of any MED deductions).
12
Figure 1 Image of the damaged area with the yellow line representing where the line was
Reducing the occurrence and impact of vegetation outages is a key focus for TLC, and in the 2020
AMP, we increased our forecast spend on vegetation management for RY2021 from $1.2 million
to $1.4 million. We are also undertaking a range of new initiatives to better understand and
manage our vegetation risk, including:
• A LIDAR survey to identify, quantify and measure the vegetation stock on our network.
• The establishment of a vegetation database to catalogue our vegetation stock and apply risk
assessment methods to target and optimise our vegetation management activities.
Vegetation outages are resulting in significant SAIDI impact in areas of our network where we have
low security of supply. TLC has a number of reliability improvement programmes to enhance
security and resilience which are expected to reduce the impact of vegetation and other outages.
These programmes include:
• The installation of 19 new automated switches during RY2021 at a cost of $1.06m; and
• The automation of 9 existing switches at a cost of $0.51m.
These investments are targeted at both identifying key areas of vegetation risk and reducing their
impact when they occur.
Third-Party Damage Incidents
In October 2019 TLC experienced a significant car vs pole third-party damage (TPD) outage which
impacted the single 33kV supply to Turangi. Turangi substation is afforded with N-1 Switched
13
security of supply for most customers7. Hence, the outage initially affected all of the approximately
2,000 customers, with 1,500 customers being restored with back-up supply from adjacent
substations. However, around 500 customers remained without power the full repair time of
around 11.5 hours as there is insufficient 11kV backup supply from other substations to provide
full support resulting in some customers remaining without power for the fault repair time.
To alleviate the 33kV supply risk in the future TLC has completed an upgrade of an 11kV cable
which increases our backup supply, however, it will not fully supply the Turangi town at high load
periods during the year. An alternative 33kV supply to the Turangi substation which will provide a
full backup is currently being planned and is expected to be commissioned in 2021. The security
constraints at Turangi and the associated security improvement project were included in the 2019
AMP and 2020 AMP8.
In total, Third-Party Damage raw SAIDI minutes in RY20 was the highest experienced in the past
ten-year period. Notwithstanding the application of the MED process, the inclusion of the SAIDI
boundary value of 10.97 minutes per customer resulted in a SAIDI contribution from TPDs in
RY2020 of 39.1 minutes per customer, which was nearly four times TLC’s historical average of 10.7
minutes per customer9.
Unknown Cause Outages
In RY2020 TLC experienced higher than normal unknown cause outages resulting in 30.2 SAIDI
minutes. This is approximately twice TLC’s historical average.
The key drivers for the increase were changes in protection system and control processes that TLC
put in place at the start of RY2019. Two new processes were put in place:
• A 15 minutes stand-down period before attempting to manually reclose a locked-out auto-
closing switch. This allows time for TLC to be contacted by emergency services or the public
before attempting to re-liven a tripped line and is a public safety measure recommended in
the Electricity Engineers Association (EEA) Guide for manual reclosing of high voltage circuits
following a fault.
• Disabling auto-reclosing in areas of the network subject to Total Fire Bans to reduce the risk
of fire. Only manual reclosing was allowed and only after a 15-minute stand-down period. The
15-minute stand down periods allow time for network assets and foreign objects involved in
the fault to cool, reducing the risk of fire from repeated re-livening attempts.
Both processes were in place through the RY2019 and RY2020 years. The stand-down period
meant that the SAIDI impact related to Unknown Cause outages increased by an estimated six
minutes for each of those years.
TLCs Focus on Reliability Improvement
In our 2018 AMP, we committed to aligning our asset management processes to ISO 55000,
improving the security of supply to customers, and increasing our renewal of key asset classes10.
7 N-1 Switched means the substation has a single 33kV supply and alternative 11kV supply can be switched from adjacent
substations. 8 2019 AMP, Section 3.1.3, and 2020 AMP, Section 5.3.3. 9 RY2010 to RY2016. 10 The Lines Company, “Asset Management Plan 2018”, 31 March 2018, Sections 1.2.1, 5.3.1, 5.3.3, and 5.2.
14
The 2019 and 2020 AMPs continued that focus of asset management improvement with an
emphasis on building resilience and sustainability through a committed programme of work
funded through significant increases in network operational and capital expenditure.
In our 2019 AMP Update11, we outlined the areas where we are focusing our reliability
improvement efforts, including:
• Improving the security of supply at zone substations;
• Increasing power transformer redundancy;
• Increasing the use of network automation and review of protection;
• Advancing the replacement of equipment that is not providing strong reliability performance;
and
• Enhancing our vegetation management work.
The 2020 AMP12 continued the RY2019 initiatives and added further initiatives including:
• Development of a Vegetation database and Lidar Survey; and
• Continued investment in automation of switches and sectionalising.
Despite recent challenges in maintaining our SAIDI and SAIFI performance within our regulatory
cap, we are confident that this ongoing focus and investment will drive ongoing improvements in
our quality performance, as these key projects are set in place.
11 The Lines Company, “Asset Management Plan Update 2019”, 31 March 2019, Sections 3.1 to 3.5. 12 The Lines Company, “Asset Management Plan 2020”, 31 March 2020, Section 5.3.
15
4. Director Certification (Clause 11.3(a))
We, Mark Charles Darrow and Simon Venn Young, being directors of The Lines Company Limited
certify that, having made all reasonable enquiry, to the best of our knowledge and belief, the
attached Annual Compliance Statement of The Lines Company Limited, and related information,
prepared for the purposes of the Electricity Distribution Services Default Price-Quality Path
Determination 2015 are true and accurate.
____________________________ ____________________________
Mark Charles DARROW Simon Venn YOUNG
Director Director
6 August 2020
PricewaterhouseCoopers, Corner Ward and Anglesea Streets, PO Box 191, Hamilton 3240, New Zealand T: +64 7 838 3838, F: +64 7 839 4178, pwc.co.nz
INDEPENDENT ASSURANCE REPORT TO THE DIRECTORS OF THE LINES COMPANY LIMITED AND THE COMMERCE COMMISSION The Auditor-General is the auditor of The Lines Company Limited (the company). The Auditor-General has appointed me, Matthew White, using the staff and resources of PricewaterhouseCoopers, to provide an opinion, on his behalf, on whether the Annual Compliance Statement for the year ended on 31 March 2020 on pages 3 to 15 and 19 to 46 has been prepared, in all material respects, in accordance with the Electricity Distribution Services Default Price-Quality Path Determination 2015 as amended by the Electricity Distribution Services Default Price-Quality Path (Compliance Statement Due Date and Auditor’s Report) Amendments Determination 2020, issued by the Commerce Commission NZ on 9 April 2020 (the ‘Determination as amended’). Opinion In our opinion:
• as far as appears from an examination, the information used in the preparation of the Annual Compliance Statement has been properly extracted from the company’s accounting and other records, and has been sourced, where appropriate, from its financial and non-financial systems; and
• the Annual Compliance Statement of the Company for the year ended on 31 March 2020, has been prepared, in all material respects, in accordance with the Determination, as amended.
In forming our opinion, we have obtained sufficient recorded evidence and all the information and explanations we have required. Emphasis of matter We draw attention to the Basis of Estimates section on page 7 which describes the uncertainty due to the system limitations related to the estimation of the quantities for which the Prompt Payment Discounts apply. Our opinion is not qualified in respect of these matters. Basis of opinion We conducted our engagement in accordance with the International Standard on Assurance Engagements (New Zealand) 3000 (Revised): Assurance Engagements Other Than Audits or Reviews of Historical Financial Information and the Standard on Assurance Engagements 3100 (Revised): Assurance Engagements on Compliance issued by the New Zealand Auditing and Assurance Standards Board. Copies of these standards are available on the External Reporting Board’s website. These standards require that we comply with ethical requirements and plan and perform our assurance engagement to provide reasonable assurance about whether the Annual Compliance Statement has been prepared in all material respects in accordance with the Determination, as amended. We have performed procedures to obtain evidence about the amounts and disclosures in the Annual Compliance Statement. The procedures selected depend on our judgement, including the assessment of the risks of material misstatement of the Annual Compliance Statement, whether due to fraud or error or non-compliance with the Determination, as amended. In making those risk assessments, we considered internal control relevant to the company’s preparation of the Annual Compliance Statement in order to design procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the company’s internal control.
17
In assessing the disclosures about compliance with the price path in clause 8 of the Determination, as amended, for the assessment period ended on 31 March 2020, our assurance engagement included examination, on a test basis, of evidence relevant to the amounts and disclosures contained on pages 4 to 8 and 19 to 40 of the Annual Compliance Statement. In assessing the disclosures about compliance with the quality standards in clause 9 of the Determination, as amended, for the assessment period ended on 31 March 2020, our assurance engagement included examination, on a test basis, of evidence relevant to the amounts and disclosures contained on pages 9 to 14 and 41 to 46 of the Annual Compliance Statement. Our assurance engagement also included assessment of the significant estimates and judgements, if any, made by the company in the preparation of the Annual Compliance Statement. We believe that the evidence we have obtained is sufficient and appropriate to provide a basis for our opinion. Scope and inherent limitations Because of the inherent limitations of a reasonable assurance engagement, and the test basis of the procedures performed, it is possible that fraud, error or non-compliance may occur and not be detected. We did not examine every transaction, adjustment or event underlying the Annual Compliance Statement nor do we guarantee complete accuracy of the Annual Compliance Statement. Also we did not evaluate the security and controls over the electronic publication of the Annual Compliance Statement. The opinion expressed in this independent assurance report has been formed on the above basis. Directors’ responsibilities for the preparation of the Annual Compliance Statement The directors of the company are responsible for the preparation of the Annual Compliance Statement in accordance with the Determination, as amended, and for such internal control as the directors determine is necessary to enable the preparation of an Annual Compliance Statement that is free from material misstatement. Our responsibility for the Annual Compliance Statement Our responsibility is to express an opinion on whether the Annual Compliance Statement has been prepared, in all material respects, in accordance with the Determination, as amended. Independence and quality control When carrying out the engagement, we complied with the Auditor-General’s:
• independence and other ethical requirements, which incorporate the independence and ethical requirements of Professional and Ethical Standard 1 (Revised) issued by the New Zealand Auditing and Assurance Standards Board; and
• quality control requirements, which incorporate the quality control requirements of Professional and Ethical Standard 3 (Amended) issued by the New Zealand Auditing and Assurance Standards Board.
We also complied with the independent auditor requirements specified in the Determination, as amended.
18
The Auditor-General, and his employees, PricewaterhouseCoopers and its partners and employees may deal with the Company on normal terms within the ordinary course of trading activities of the Company. In addition to the Default Price-Quality Path Compliance audit, we have carried out engagements in the areas of Statutory Financial Audit, Information Disclosure audit, Regulatory agreed upon procedures and other regulatory and professional advice which are compatible with those independence requirements. Other than the audit and these assignments, we have no relationship with or interests in the Group or any of its subsidiaries. Use of this report This independent assurance report has been prepared solely for the directors of the Company and for the Commerce Commission for the purpose of providing those parties with reasonable assurance about whether the Annual Compliance Statement has been prepared, in all material respects, in accordance with the Determination, as amended. We disclaim any assumption of responsibility for any reliance on this report to any person other than the directors of the company or the Commerce Commission, or for any other purpose than that for which it was prepared. Matthew White PricewaterhouseCoopers On behalf of the Auditor-General Hamilton, New Zealand 10 August 2020
19
Appendix A Price Path Compliance Calculations (Clause 11.4(c))
Table 7 Price Path Compliance Calculations (Clause 11.4(c))
Term Description Value $
ΣDP 2018/19 *Q 2017/18
Distribution Prices between 1 April
2018 and 31 March 2019 multiplied
by Quantities for year ending 31
March 2018
37,275,177
ANR 2018/19 - NR 2018/19
Revenue differential for year ending
31 March 2019 3,330,944
(1 +DCPI 2019/20 )Average change in Consumer Price
Index 1.0153
XX Factor, as specified in Schedule 1 of
the DPP Determination0%
ANR 2019/20
Allowable Notional Revenue for the
year ending 31 March 2020 41,226,139
Denominator Numerator
CPIDec2016 990 CPIDec2017 1006
CPIMar2017 1000 CPIMar2018 1011
CPIJun2017 1000 CPIJun2018 1015
CPISep2017 1005 CPISep2018 1024
DCPI2019/20
Source: Statistics NZ, SE9A Series
Term Description Value $
ΣDP 2019/20 *Q 2017/18
Distribution Prices between 1 April
2019 and 31 March 2020 multiplied
by Quantities for year ending 31
March 2018
40,153,738
NR 2019/20
Notional Revenue for the year ending
31 March 2020 40,153,738
Allowable Notional Revenue 2019/20
Notional Revenue 2019/20
DCPI 2019/20
1.53%
20
Appendix B Pass-through Balance and Pass-through & Recoverable
Costs (Clause 11.4(e) – (k))
Table 8 Pass-through Balance and Pass-through & Recoverable Costs (Clause 11.4(e) – (k))
Term Description Value $
PTP 2019/20 Q 2019/20
Pass-through Prices during 2019/20
multiplied by 31 March 2020
Quantities
6,622,646
Rates on system fixed assets for the
year ending 31 March 2020 340,278
Commerce Act levies for the year
ending 31 March 2020 92,163
Electricity Authority levies for the
year ending 31 March 2020 67,357
Utilities Disputes levies for the year
ending 31 March 2020 26,736
Transpower transmission charges for
the year ending 31 March 2020 5,228,777
Transpower New Investment
Contract charges for the year ending
31 March 2020*
2,414,378
System operator services charges for
the year ending 31 March 2020-
Avoided transmission charges
resulting from purchase of
transmission assets from Transpower
for the year ending 31 March 2020
-
Distributed generation allowance for
the year ending 31 March 2020 1,642,953
Claw-back for the year ending 31
March 2020-
NPV wash-up allowance for the year
ending 31 March 2020-
Energy efficiency and demand-side
management incentive allowance for
the year ending 31 March 2020
-
Catastrophic event allowance for the
year ending 31 March 2020-
Extended reserves allowance for the
year ending 31 March 2020-
Quality incentive adjustment for the
year ending 31 March 2020(390,608)
Capex wash-up adjustment for the
year ending 31 March 2020(308,654)
Reconsideration event allowance for
the year ending 31 March 2020-
PTB 2018/19
Pass-through balance from previous
Assessment Period 33,987
r Cost of Debt 6.09%
PTB 2018/19(1+r)
Pass-through balance from previous
Assessment Period multiplied by 1
plus the Cost of Debt
36,057
PTB 2019/20
Pass-through balance for the
Assessment Period ending 31 March
2020
(2,454,677)
K 2019/20
Pass-through Balance 2019/20
V 2019/20
21
Table 9 Pass-through balance reconciliation
Description of the methodology used to calculate Distribution Prices and
Pass-through Prices (clause 11.4(e)(i)
Distribution prices for the Assessment Period were considered on forecast kWh quantities from 1
April 2019. The Low Fixed Charge (LFC) prices varied in percentage movement to ensure
compliance with the LFC regulations. A validation exercise was undertaken to ensure TLC’s
compliance with the default price-quality price path and a crosscheck against TLC’s cost of supply
model in calculating these prices.
Pass-through prices for the Assessment Period were determined by estimating pass through and
recoverable costs for the year and assessing these cost estimates against forecast kWh volumes
from 1 April 2019.
The tables below provide details of TLC’s pass-through and recoverable costs for the Assessment
Period ending 31 March 2020:
Table 10 Pass-through costs
Term Description Value $
PTP 2019/20 Q 2019/20
Pass-through Prices during 2019/20
multiplied by 31 March 2020
Quantities
6,622,646
Total Pass-through and Recoverable
Costs
Total Pass-through and Recoverable
Costs for the year ending 31 March
2020
9,113,379
PTB 2019/20
Pass-through Balance for the
Assessment Period ending 31 March
2020
(2,454,677)
PTB 2018/19(1+r)
Pass-through balance from previous
Assessment Period multiplied by 1
plus the Cost of Debt
36,057
Difference
Reconciliation between Pass-through
Balance for the Assessment Period
with the Pass-through Balance for
the preceding Assessment Period
(2,490,733)
Pass-through Balance Reconciliation 2019/20
K 2019/20 Actual ($) Forecast ($) Variance ($) Variance (%)
Rates on system fixed assets 340,278 290,000 50,278 17.3%
Commerce Act levies 92,163 96,000 (3,837) (4.0%)
Electricity Authority levies 67,357 78,000 (10,643) (13.6%)
Utilities Disputes levies 26,736 56,000 (29,264) (52.3%)
Total Pass-through Costs 526,533 520,000 6,533 1.3%
Pass-through Costs for year ending March 2020
22
Table 11 Recoverable costs
Explanation for the cause of variance between forecast and actual pass-through
and recoverable costs for the Assessment Period (clause 11.4(j))
The variance that exists between actual and forecast Electricity Authority levies was due to the
actual costs being less than expected. Utilities Disputes levies were lower than forecast due to a
lower number of complaints, which reflects in the charges. Rates were higher than anticipated,
reflecting increases in local government charges.
New investment contract charges
TLC has identified a transaction which impacts the pass-through balance – a $2.347m transaction
with Transpower in RY2019 that the Input Methodologies define as a recoverable cost. In addition
to that transaction, there was also a washup payment of 68K, related to the same contract, that
was paid in RY2020.
The original transaction in RY2019 was identified after price-setting for RY2020 and was not
included in the pass-through balance which was used to set pass-through prices for RY2020. It was
also omitted from the pass-through cost component of the RY2019 DPP annual compliance
statement.
TLC has sought advice and has written to the Commerce Commission advising of the identification
of these transactions. TLC’s advice is that the appropriate treatment of these transactions is to
define them as a recoverable cost for the purpose of TLC’s default price-quality price path.
Accordingly, the full recoverable cost, including the amounts incurred in RY2019 and RY2020 are
recognised in RY2020, leading to the forecasting variance in table 11 above.
V 2019/20 Actual ($) Forecast ($) Variance ($) Variance (%)
Transpower transmission charges 5,228,777 5,222,000 6,777 0.1%
New investment contract charges 2,414,378 - 2,414,378 n/a
System operator services charges - - - 0.0%
Avoided transmission charges -
purchases from Transpower- - - 0.0%
Distributed generation allowance 1,642,953 1,655,000 (12,047) (0.7%)
Claw-back - - 0.0%
NPV wash-up allowance - - 0.0%
Energy efficiency allowance - - 0.0%
Catastrophic event allowance - - 0.0%
Extended reserves allowance - - 0.0%
Quality incentive adjustment (390,608) (390,608) - 0.0%
Capex wash-up adjustment (308,654) (308,654) - 0.0%
Reconsideration event allowance - - 0.0%
Total Recoverable Costs 8,586,846 6,177,738 2,409,109 39.0%
Recoverable Costs for year ending March 2020
23
Appendix C Price and Quantity Schedules (Clause 11.4(c) – (d))
Table 12 Summary of distribution notional revenues
Summary of distribution notional revenue
Notional revenue
ppd appliedppd not
appliedtotal ppd applied
ppd not
appliedtotal
Major Customer Non Standard Dedicated Asset 3,934,536$ -$ 3,934,536$ 4,608,450$ -$ 4,608,450$
Major Customer Network Charge 2,739,379$ -$ 2,739,379$ 2,739,379$ -$ 2,739,379$
Major Customer Transformers 162,723$ -$ 162,723$ 162,723$ -$ 162,723$
Major Customer Billing Charge 64,929$ -$ 64,929$ 64,929$ -$ 64,929$
Streetlights 708,540$ -$ 708,540$ 708,540$ -$ 708,540$
Standard/LFC Network Demand (April to September) 3,201,634$ 390,877$ 3,592,511$
Standard/LFC Demand (April to September) 7,579,696$ 925,379$ 8,505,075$
TOU Daily (October to March) 4,879,405$ 595,679$ 5,475,085$
TOU Peak (October to March) 1,799,261$ 219,702$ 2,018,963$
TOU Shoulder (October to March) 4,036,364$ 492,892$ 4,529,256$
TOU Off Peak (October to March) 1,041,100$ 127,087$ 1,168,187$
Non TOU Anytime (October to March) 948,257$ 115,739$ 1,063,995$
Non TOU Anytime (full year) 2,173,748$ 265,314$ 2,439,062$
TOU Daily (full year) 9,732,108$ 1,188,155$ 10,920,263$
TOU Peak (full year) 3,983,041$ 486,272$ 4,469,313$
TOU Shoulder (full year) 8,825,170$ 1,077,364$ 9,902,534$
TOU Off Peak (full year) 2,365,924$ 288,673$ 2,654,597$
Transformer (April to September) 1,476,977$ 177,637$ 1,654,613$
Relay fee (April to September) 154,563$ 18,875$ 173,437$
Metering fee 1,184,253$ 144,573$ 1,328,825$ 1,184,253$ 144,573$ 1,328,825$
Disconnections/Reconnections 155,123$ -$ 155,123$ 155,123$ -$ 155,123$
Total notional revenue 34,066,739$ 3,208,438$ 37,275,177$ 36,703,388$ 3,450,350$ 40,153,738$
Allowable notional revenue 2020 41,226,139$
Allowable notional revenue/notional revenue difference 1,072,401$
Result
2019 2020
Price path has not been breached
24
Table 13 Major customers – standard and non-standard contracts
31-Mar-18
Quantity (Qt-2)
Notional Revenue
(Qt-2×Pt-1)
Notional Revenue
(Qt-2×Pt)
per annum net of PPD per annum net of PPD
Non standard dedicated asset
Ata Rangi Pastoral Limited 1 154,728$ 139,256$ 139,256$ 154,728$ 139,256$ 139,256$
Department of Corrections; Tongariro Prison 1 76,308$ 68,677$ 68,677$ 76,308$ 68,677$ 68,677$
Graymont (NZ) Limited; Plant, Otorohanga 1 12,841$ 11,557$ 11,557$ 12,841$ 11,557$ 11,557$
Graymont (NZ) Limited; Quarry, Oparure 1 208,099$ 187,289$ 187,289$ 208,099$ 187,289$ 187,289$
KCE Generation Limited 1 156,000$ 156,000$ 156,000$ 826,000$ 826,000$ 826,000$
Mercury NZ Limited 1 41,280$ 41,280$ 41,280$ 41,280$ 41,280$ 41,280$
Mangapehi Power 1 54,338$ 48,904$ 48,904$ 54,338$ 48,904$ 48,904$
Ruapehu Alpine Lifts Limited; Turoa Ski Area 1 437,047$ 393,343$ 393,343$ 437,047$ 393,343$ 393,343$
Ruapehu Alpine Lifts Limited; Whakapapa Ski Area 1 561,310$ 505,179$ 505,179$ 558,104$ 502,294$ 502,294$
Speedys Road Hydro Limited 1 42,222$ 38,000$ 38,000$ 42,222$ 38,000$ 38,000$
Taharoa Ironsands Limited 1 1,960,227$ 1,764,205$ 1,764,205$ 1,960,227$ 1,764,205$ 1,764,205$
Tuaropaki Trust 1 503,647$ 453,283$ 453,283$ 511,202$ 460,082$ 460,082$
Universal Beef Packers Limited 1 15,257$ 13,731$ 13,731$ 15,257$ 13,731$ 13,731$
Winstone Pulp International Limited 1 126,481$ 113,833$ 113,833$ 126,481$ 113,833$ 113,833$
Non standard dedicated asset totals 14 3,934,536$ 4,608,450$
Major customer network charge (kVA)
400 V 240 129.02$ 116.12$ 27,869$ 129.02$ 116.12$ 27,869$
11 kV Hangatiki 15,760 122.26$ 110.03$ 1,734,073$ 122.26$ 110.03$ 1,734,073$
11 kV Whakamaru 1,000 231.41$ 208.27$ 208,270$ 231.41$ 208.27$ 208,270$
11 kV Ohakune 100 133.77$ 120.39$ 12,039$ 133.77$ 120.39$ 12,039$
11 kV Ongarue 860 138.61$ 124.75$ 107,285$ 138.61$ 124.75$ 107,285$
11 kV National Park 1,400 177.89$ 160.10$ 224,140$ 177.89$ 160.10$ 224,140$
11 kV Tokaanu 2,305 133.91$ 120.52$ 277,799$ 133.91$ 120.52$ 277,799$
33 kV 1,350 74.18$ 66.76$ 90,126$ 74.18$ 66.76$ 90,126$
Stepped 700 91.71$ 82.54$ 57,778$ 91.71$ 82.54$ 57,778$
Major customer network charge totals 23,715 2,739,379$ 2,739,379$
Billing charge 38 1,898.52$ 1,708.67$ 64,929$ 1,898.52$ 1,708.67$ 64,929$
6,738,844$ 7,412,758$
Major customers - standard and non standard contracts
Price (Pt)
Standard and non standard contract notional revenue totals
Price (Pt-1)
31-Mar-19 31-Mar-20
25
Table 14 Standard contract and low fixed charge (LFC) network charge
A B (A×PPD%) C (A×PPD%) D E (D×6) F (E×90%) G (B×E) H (C×F)
Standard contract (kVA) Billed
PPD not
applied PPD applied monthly six months net of PPD
PPD not
applied PPD applied
High Density/Low Voltage
Hangatiki 23,378 2,314 21,064 4.48$ 26.88$ 24.19$ 62,212$ 509,570$
Whakamaru 3,186 315 2,871 4.48$ 26.88$ 24.19$ 8,478$ 69,445$
Ohakune 11,332 1,122 10,211 4.50$ 27.00$ 24.30$ 30,292$ 248,116$
Ongarue 12,681 1,255 11,426 4.51$ 27.06$ 24.35$ 33,972$ 278,259$
National Park 2,617 259 2,358 5.39$ 32.34$ 29.11$ 8,379$ 68,630$
Tokaanu 21,170 2,096 19,074 4.50$ 27.00$ 24.30$ 56,587$ 463,502$
Low Density/Low Voltage
Hangatiki 4,724 468 4,256 8.62$ 51.72$ 46.55$ 24,188$ 198,123$
Whakamaru 2,512 249 2,263 7.95$ 47.70$ 42.93$ 11,862$ 97,164$
Ohakune 0 0 0 6.66$ 39.96$ 35.96$ -$ -$
Ongarue 2,041 202 1,839 8.67$ 52.02$ 46.82$ 10,511$ 86,096$
National Park 3,980 394 3,586 7.98$ 47.88$ 43.09$ 18,866$ 154,527$
Tokaanu 185 18 167 8.66$ 51.96$ 46.76$ 952$ 7,795$
High Density/High Voltage
Hangatiki 14,431 1,429 13,002 2.09$ 12.54$ 11.29$ 17,916$ 146,744$
Whakamaru 1,953 193 1,760 2.09$ 12.54$ 11.29$ 2,425$ 19,859$
Ohakune 1,701 168 1,533 2.10$ 12.60$ 11.34$ 2,122$ 17,380$
Ongarue 3,238 321 2,917 2.11$ 12.66$ 11.39$ 4,058$ 33,241$
National Park 693 69 624 2.53$ 15.18$ 13.66$ 1,041$ 8,530$
Tokaanu 2,000 198 1,802 2.11$ 12.66$ 11.39$ 2,507$ 20,532$
Low Density/High Voltage
Hangatiki 10,220 1,012 9,208 4.10$ 24.60$ 22.14$ 24,890$ 203,870$
Whakamaru 15,218 1,507 13,711 3.79$ 22.74$ 20.47$ 34,260$ 280,618$
Ohakune 0 0 0 3.16$ 18.96$ 17.06$ -$ -$
Ongarue 3,813 377 3,436 4.12$ 24.72$ 22.25$ 9,331$ 76,433$
National Park 1,237 122 1,115 3.79$ 22.74$ 20.47$ 2,785$ 22,810$
Tokaanu 586 58 528 4.12$ 24.72$ 22.25$ 1,434$ 11,747$
Standard contract totals 142,896 14,147 128,750 369,067$ 3,022,992$
Low fixed charge (No. of ICPs)
Hangatiki 2,886 286 2,600 5.07$ 30.42$ 27.38$ 8,691$ 71,191$
Whakamaru 677 67 610 5.07$ 30.42$ 27.38$ 2,039$ 16,700$
Ohakune 391 39 352 5.07$ 30.42$ 27.38$ 1,178$ 9,645$
Ongarue 1,790 177 1,613 5.07$ 30.42$ 27.38$ 5,391$ 44,155$
National Park 188 19 169 5.07$ 30.42$ 27.38$ 566$ 4,638$
Tokaanu 1,310 130 1,180 5.07$ 30.42$ 27.38$ 3,945$ 32,315$
Low fixed charge totals 7,242 717 6,525 21,810$ 178,643$
Total notional revenue 390,877$ 3,201,634$
Standard contract and low fixed charge (LFC) network charge
30-Sep-17
Quantity (Qt-2) Price (Pt-1)
30-Sep-18
Allowable Notional
Revenue (Qt-2×Pt-1)
26
Table 15 Standard contract and low fixed charge (LFC) kW Load charge
Sta
nd
ard
co
ntr
act
an
d l
ow
fix
ed
ch
arg
e (
LF
C)
kW
Lo
ad
ch
arg
e
PR
1 (
Qt-
2×
Pt-
1)
PR
2 (
Qt-
2×
Pt-
1)
PR
5 (
Qt-
2×
Pt-
1)
t-2
t-1
AN
Rt-
1 A
NR
t-1
AN
Rt-
1 A
NR
t-2
t-2
t-1
AN
Rt-
1 A
NR
t-1
AN
Rt-
1 A
NR
t-1
AN
Rt-
1 A
NR
t-1
AN
Rt-
1 A
NR
Sta
nd
ard
co
ntr
act
(k
W)
Bill
ed
PR
1P
R2
PR
5
Po
st-p
rice
rest
ruct
ure
Bill
ed
PP
D
no
t a
pp
lied
Bill
ed
PP
D
ap
plie
d
PR
1 P
PD
no
t
ap
plie
d
PR
1 P
PD
ap
plie
d
PR
2 P
PD
no
t
ap
plie
d
PR
2 P
PD
ap
plie
d
PR
5 P
PD
no
t
ap
plie
d
PR
5 P
PD
ap
plie
d
Po
st-p
rice
rest
ruct
ure
PP
D n
ot
ap
plie
d
Po
st-p
rice
rest
ruct
ure
PP
D a
pp
lied
mo
nth
lysi
x m
on
thly
ne
t o
f P
PD
Ha
ng
ati
ki2
4,0
95
-34
1
05
-22
3
23
,94
32
,38
52
1,7
10
-3
-30
1
09
4-2
2
-20
1
2,3
70
21
,57
21
9.8
6$
11
9.1
6$
10
7.2
4$
28
4,2
46
$
2,3
28
,23
0$
3
,66
8-$
11
,36
9$
2
4,2
21
-$
28
2,4
48
$
2
,31
3,5
07
$
Wh
aka
ma
ru8
,73
9-1
3
12
-34
8
,70
48
65
7,8
74
-1
-12
1
11
-3
-31
8
62
7,8
42
26
.58
$
1
59
.48
$
14
3.5
3$
13
7,9
81
$
1,1
30
,19
2$
1
,92
5-$
1,7
79
$
4
,97
4-$
13
7,4
24
$
1
,12
5,6
29
$
Oh
aku
ne
6,0
63
-13
2
0-3
2
6,0
38
60
05
,46
2-1
-1
2
21
8-3
-2
9
59
85
,44
01
6.2
7$
97
.62
$
8
7.8
6$
58
,59
1$
47
9,9
11
$
1
,16
5-$
1,7
82
$
2
,83
4-$
58
,34
9$
4
77
,93
5$
On
ga
rue
9,7
08
-33
1
2-1
62
9
,52
49
61
8,7
47
-3
-30
1
11
-16
-1
46
9
43
8,5
81
20
.84
$
1
25
.04
$
11
2.5
4$
12
0,1
74
$
98
4,3
33
$
3
,78
2-$
1,3
26
$
1
8,4
87
-$
11
7,8
95
$
9
65
,66
9$
Na
tio
na
l Pa
rk3
,12
7-4
2
4-2
3
3,1
23
31
02
,81
7-0
-4
2
21
-2
-21
3
09
2,8
14
20
.61
$
1
23
.66
$
11
1.2
9$
38
,27
8$
31
3,5
35
$
5
02
-$
2,6
70
$
2
,56
5-$
38
,23
5$
3
13
,18
1$
To
kaa
nu
9,1
98
-33
3
4-2
99
8
,90
09
11
8,2
87
-3
-29
3
30
-30
-2
69
8
81
8,0
19
18
.95
$
1
13
.70
$
10
2.3
3$
10
3,5
35
$
84
8,0
49
$
3
,37
2-$
3,4
83
$
3
0,9
36
-$
10
0,1
81
$
8
20
,57
7$
Sta
nd
ard
co
ntr
act
to
tals
60
,93
0-1
31
2
06
-77
4
60
,23
16
,03
25
4,8
98
-13
-1
18
2
01
86
-77
-6
97
5
,96
35
4,2
68
74
2,8
05
$
6,0
84
,24
9$
1
4,4
15
-$
22
,40
9$
8
4,0
17
-$
73
4,5
34
$
6
,01
6,4
97
$
Lo
w f
ixe
d c
ha
rge
(L
FC
) (k
W)
Hig
h D
en
sity
/Lo
w V
olt
ag
e
Ha
ng
ati
ki3
,41
9-1
1
30
-33
3
,40
53
38
3,0
80
-1
-9
32
7-3
-3
0
33
73
,06
82
6.4
0$
15
8.4
0$
14
2.5
6$
53
,61
2$
43
9,1
29
$
1
,51
5-$
4,3
24
$
4
,77
7-$
53
,39
8$
4
37
,37
6$
Wh
aka
ma
ru4
51
00
-2
44
94
54
07
00
00
-0
-2
44
40
53
3.1
2$
19
8.7
2$
17
8.8
5$
8,8
77
$
7
2,7
09
$
-$
7
3$
41
4-$
8
,84
0$
72
,40
6$
Oh
aku
ne
57
7-7
2
-9
56
45
75
19
-1
-6
02
-1
-8
56
50
82
2.8
5$
13
7.1
0$
12
3.3
9$
7,8
25
$
6
4,0
98
$
86
2-$
2
98
$
1,0
62
-$
7
,64
9$
62
,64
8$
On
ga
rue
2,0
28
-3
3-1
13
1
,91
42
01
1,8
27
-0
-2
02
-11
-1
02
1
90
1,7
25
27
.43
$
1
64
.58
$
14
8.1
2$
33
,04
5$
27
0,6
65
$
4
11
-$
39
2$
1
6,9
94
-$
31
,19
3$
2
55
,50
3$
Na
tio
na
l Pa
rk1
59
-2
3-6
1
54
16
14
3-0
-2
0
2-1
-5
1
51
38
28
.86
$
1
73
.16
$
15
5.8
4$
2,7
20
$
2
2,2
83
$
33
4-$
4
17
$
88
5-$
2
,63
3$
21
,56
8$
To
kaa
nu
1,9
84
-8
8-3
8
1,9
46
19
61
,78
8-1
-7
1
7-4
-3
5
19
31
,75
42
5.5
3$
15
3.1
8$
13
7.8
6$
30
,09
1$
24
6,4
73
$
1
,08
3-$
1,1
28
$
5
,34
0-$
29
,51
5$
2
41
,75
4$
Low
De
nsi
ty/L
ow
Vo
lta
ge
-$
-
$
-$
-
$
-$
Ha
ng
ati
ki4
20
03
-29
3
95
42
37
90
00
3-3
-2
6
39
35
63
4.2
1$
20
5.2
6$
18
4.7
3$
8,5
38
$
6
9,9
30
$
-$
5
99
$
5,3
39
-$
8
,02
2$
65
,70
6$
Wh
aka
ma
ru1
80
01
-2
17
91
81
62
00
01
-0
-2
18
16
13
9.6
6$
23
7.9
6$
21
4.1
6$
4,2
45
$
3
4,7
68
$
-$
1
65
$
46
2-$
4
,21
2$
34
,50
2$
Oh
aku
ne
00
00
00
00
00
00
00
02
6.9
2$
16
1.5
2$
14
5.3
7$
-$
-
$
-$
-
$
-$
-
$
-$
On
ga
rue
35
9-4
1
-16
3
40
36
32
3-0
-4
0
1-2
-1
4
34
30
63
5.2
8$
21
1.6
8$
19
0.5
1$
7,5
18
$
6
1,5
83
$
76
0-$
2
12
$
3,0
77
-$
7
,12
4$
58
,35
2$
Na
tio
na
l Pa
rk6
5-0
1
-3
64
65
9-0
-0
0
1-0
-2
6
57
33
.75
$
2
02
.50
$
18
2.2
5$
1,3
09
$
1
0,7
23
$
68
-$
2
66
$
49
9-$
1
,27
6$
10
,45
5$
To
kaa
nu
18
00
01
82
16
00
00
00
21
63
3.3
7$
20
0.2
2$
18
0.2
0$
34
9$
2
,86
1$
-$
2
3$
-$
3
52
$
2,8
81
$
Hig
h D
en
sity
/Hig
h V
olt
ag
e-
$
-$
-
$
-$
-
$
Ha
ng
ati
ki5
75
03
-18
5
60
57
51
80
00
2-2
-1
6
55
50
52
1.8
9$
13
1.3
4$
11
8.2
1$
7,4
81
$
6
1,2
76
$
-$
3
16
$
2,1
08
-$
7
,28
6$
59
,67
8$
Wh
aka
ma
ru4
80
00
48
54
40
00
00
05
44
28
.61
$
1
71
.66
$
15
4.4
9$
82
4$
6
,74
7$
-$
-
$
-$
8
24
$
6,7
47
$
Oh
aku
ne
74
-1
0-3
7
07
67
-0
-1
00
-0
-3
76
31
8.3
2$
10
9.9
2$
98
.93
$
8
05
$
6,5
92
$
6
2-$
26
$
3
31
-$
76
5$
6
,26
5$
On
ga
rue
22
60
0-2
6
20
02
22
03
00
00
-3
-24
2
01
80
22
.91
$
1
37
.46
$
12
3.7
1$
3,0
70
$
2
5,1
45
$
-$
6
2$
3,2
88
-$
2
,71
9$
22
,27
0$
Na
tio
na
l Pa
rk3
20
0-2
3
03
29
00
00
-0
-2
32
72
3.4
7$
14
0.8
2$
12
6.7
4$
45
1$
3
,69
8$
-$
-
$
24
4-$
4
25
$
3,4
80
$
To
kaa
nu
40
00
-5
35
43
60
00
0-1
-5
3
32
21
.02
$
1
26
.12
$
11
3.5
1$
50
4$
4
,12
6$
-$
-
$
59
7-$
4
39
$
3,5
93
$
Low
De
nsi
ty/H
igh
Vo
lta
ge
-$
-
$
-$
-
$
-$
Ha
ng
ati
ki6
24
-2
5-1
4
61
46
25
63
-0
-2
15
-1
-13
6
15
53
25
.68
$
1
54
.08
$
13
8.6
7$
9,5
26
$
7
8,0
26
$
24
8-$
7
30
$
1,9
97
-$
9
,36
1$
76
,67
6$
Wh
aka
ma
ru4
50
-1
0-1
0
43
94
54
05
-0
-1
00
-1
-9
43
39
53
1.8
2$
19
0.9
2$
17
1.8
3$
8,5
02
$
6
9,6
41
$
20
9-$
6
0$
1,8
11
-$
8
,28
9$
67
,89
5$
Oh
aku
ne
00
00
00
00
00
00
00
02
0.3
2$
12
1.9
2$
10
9.7
3$
-$
-
$
-$
-
$
-$
-
$
-$
On
ga
rue
33
50
1-1
0
32
63
33
02
00
01
-1
-9
32
29
42
6.7
0$
16
0.2
0$
14
4.1
8$
5,3
17
$
4
3,5
55
$
-$
9
4$
1,4
14
-$
5
,17
4$
42
,37
9$
Na
tio
na
l Pa
rk6
30
0-6
5
76
56
00
00
-1
-6
65
12
5.8
5$
15
5.1
0$
13
9.5
9$
96
0$
7
,86
4$
-$
4
9$
89
3-$
8
68
$
7,1
13
$
To
kaa
nu
34
00
-1
33
33
10
00
0-0
-1
3
30
24
.81
$
1
48
.86
$
13
3.9
7$
50
0$
4
,09
2$
-$
-
$
15
6-$
4
83
$
3,9
53
$
Low
fix
ed
ch
arg
e (
LFC
) to
tals
12
,16
2-3
8
63
-34
7
11
,83
91
,20
41
0,9
58
-4
-34
6
57
-34
-3
13
1
,17
21
0,6
67
19
6,0
69
$
1,6
05
,98
3$
5
,55
3-$
9,2
34
$
5
1,6
89
-$
19
0,8
46
$
1
,56
3,1
98
$
Gra
nd
to
tals
73
,09
1-1
68
2
69
-1,1
21
7
2,0
71
7,2
36
65
,85
5-1
7
-15
2
27
24
2-1
11
-1
,01
0
7,1
35
64
,93
69
38
,87
4$
7,6
90
,23
1$
1
9,9
68
-$
31
,64
4$
1
35
,70
7-$
92
5,3
79
$
7
,57
9,6
96
$
30
-Se
p-1
7
Pri
ce (
Pt-
1)
Po
st-p
rice
re
stru
ctu
re (
Qt-
2×
Pt-
1)
30
-Se
p-1
8
Bill
ed
Qu
an
tity
(Q
t-2×
Pt-
1)
Qu
an
tity
(Q
t-2)
27
Table 16 Standard contract and low fixed charge (LFC) TOU daily
Standard contract and low fixed charge (LFC) daily
pricing code no. of ICPs density load Billed
Billed PPD
not applied
Billed PPD
applied Billed
Billed PPD
not applied
Billed PPD
applied
Daily ($
per day)
Daily ($
per day
net of PPD)
Daily ($ per
day)
Daily ($ per
day net of
PPD)
RT-LFC-HC 4,537 High Controlled 830,271 82,197 748,074 1,656,005 163,944 1,492,061 0.1667$ 0.1500$ 13,702$ 112,211$ 125,913$ 0.1667$ 0.1500$ 27,329$ 223,809$ 251,139$
RT-LFC-LC 996 Low Controlled 182,268 18,045 164,223 363,540 35,990 327,550 0.1667$ 0.1500$ 3,008$ 24,633$ 27,642$ 0.1667$ 0.1500$ 6,000$ 49,133$ 55,132$
RT-LFC-HU 1,146 High Uncontrolled 209,718 20,762 188,956 418,290 41,411 376,879 0.1667$ 0.1500$ 3,461$ 28,343$ 31,804$ 0.1667$ 0.1500$ 6,903$ 56,532$ 63,435$
RT-LFC-LU 340 Low Uncontrolled 62,220 6,160 56,060 124,100 12,286 111,814 0.1667$ 0.1500$ 1,027$ 8,409$ 9,436$ 0.1667$ 0.1500$ 2,048$ 16,772$ 18,820$
RT-STD-HC 2,662 High Controlled 487,146 48,227 438,919 971,630 96,191 875,439 0.8054$ 0.7249$ 38,842$ 318,172$ 357,014$ 0.8054$ 0.7249$ 77,472$ 634,606$ 712,078$
RT-STD-LC 1,063 Low Controlled 194,529 19,258 175,271 387,995 38,412 349,583 1.4889$ 1.3400$ 28,673$ 234,863$ 263,536$ 1.4889$ 1.3400$ 57,192$ 468,441$ 525,633$
RT-STD-HU 578 High Uncontrolled 105,774 10,472 95,302 210,970 20,886 190,084 0.8054$ 0.7249$ 8,434$ 69,084$ 77,519$ 0.8054$ 0.7249$ 16,822$ 137,792$ 154,613$
RT-STD-LU 224 Low Uncontrolled 40,992 4,058 36,934 81,760 8,094 73,666 1.4889$ 1.3400$ 6,042$ 49,492$ 55,534$ 1.4889$ 1.3400$ 12,051$ 98,712$ 110,764$
GT-15-HC 506 High Controlled 92,598 9,167 83,431 184,690 18,284 166,406 1.6667$ 1.5000$ 15,279$ 125,147$ 140,425$ 1.6667$ 1.5000$ 30,474$ 249,609$ 280,083$
GT-15-LC 290 Low Controlled 53,070 5,254 47,816 105,850 10,479 95,371 2.3778$ 2.1400$ 12,493$ 102,326$ 114,819$ 2.3778$ 2.1400$ 24,917$ 204,094$ 229,011$
GT-15-HU 1,789 High Uncontrolled 327,387 32,411 294,976 652,985 64,646 588,339 1.6667$ 1.5000$ 54,019$ 442,464$ 496,483$ 1.6667$ 1.5000$ 107,745$ 882,509$ 990,254$
GT-15-LU 1,677 Low Uncontrolled 306,891 30,382 276,509 612,105 60,598 551,507 2.3778$ 2.1400$ 72,242$ 591,729$ 663,972$ 2.3778$ 2.1400$ 144,090$ 1,180,225$ 1,324,315$
GT-30-HC 60 High Controlled 10,980 1,087 9,893 21,900 2,168 19,732 3.3889$ 3.0500$ 3,684$ 30,174$ 33,857$ 3.3889$ 3.0500$ 7,347$ 60,183$ 67,530$
GT-30-LC 13 Low Controlled 2,379 236 2,143 4,745 470 4,275 4.4444$ 4.0000$ 1,049$ 8,572$ 9,621$ 4.4444$ 4.0000$ 2,089$ 17,100$ 19,189$
GT-30-HU 235 High Uncontrolled 43,005 4,257 38,748 85,775 8,492 77,283 3.3889$ 3.0500$ 14,427$ 118,181$ 132,608$ 3.3889$ 3.0500$ 28,779$ 235,713$ 264,492$
GT-30-LU 51 Low Uncontrolled 9,333 924 8,409 18,615 1,843 16,772 4.4444$ 4.0000$ 4,107$ 33,636$ 37,743$ 4.4444$ 4.0000$ 8,191$ 67,088$ 75,279$
GT-70-H 100 High n/a 18,300 1,812 16,488 36,500 3,614 32,887 7.5000$ 6.7500$ 13,590$ 111,294$ 124,884$ 7.5000$ 6.7500$ 27,105$ 221,987$ 249,092$
GT-70-L 16 Low n/a 2,928 290 2,638 5,840 578 5,262 10.0000$ 9.0000$ 2,900$ 23,742$ 26,642$ 10.0000$ 9.0000$ 5,780$ 47,358$ 53,138$
GT-150-H 28 High n/a 5,124 507 4,617 10,220 1,012 9,208 15.6667$ 14.1000$ 7,943$ 65,100$ 73,043$ 15.6667$ 14.1000$ 15,855$ 129,833$ 145,688$
GT-150-L 3 Low n/a 549 54 495 1,095 108 987 20.5556$ 18.5000$ 1,110$ 9,158$ 10,268$ 20.5556$ 18.5000$ 2,220$ 18,260$ 20,480$
TT-15-HC 2,173 High Controlled 397,659 39,368 358,291 793,145 78,521 714,624 2.1271$ 1.9144$ 83,740$ 685,912$ 769,652$ 2.1271$ 1.9144$ 167,022$ 1,368,076$ 1,535,098$
TT-15-LC 148 Low Controlled 27,084 2,681 24,403 54,020 5,348 48,672 3.0346$ 2.7311$ 8,136$ 66,647$ 74,783$ 3.0346$ 2.7311$ 16,229$ 132,928$ 149,157$
TT-15-HU 966 High Uncontrolled 176,778 17,501 159,277 352,590 34,906 317,684 2.1271$ 1.9144$ 37,226$ 304,920$ 342,146$ 2.1271$ 1.9144$ 74,249$ 608,174$ 682,423$
TT-15-LU 213 Low Uncontrolled 38,979 3,859 35,120 77,745 7,697 70,048 3.0346$ 2.7311$ 11,711$ 95,916$ 107,627$ 3.0346$ 2.7311$ 23,357$ 191,308$ 214,665$
TT-30-HC 51 High Controlled 9,333 924 8,409 18,615 1,843 16,772 4.3249$ 3.8924$ 3,996$ 32,731$ 36,727$ 4.3249$ 3.8924$ 7,971$ 65,283$ 73,254$
TT-30-LC 9 Low Controlled 1,647 163 1,484 3,285 325 2,960 5.6720$ 5.1048$ 925$ 7,576$ 8,500$ 5.6720$ 5.1048$ 1,843$ 15,110$ 16,954$
TT-30-HU 53 High Uncontrolled 9,699 960 8,739 19,345 1,915 17,430 4.3249$ 3.8924$ 4,152$ 34,016$ 38,168$ 4.3249$ 3.8924$ 8,282$ 67,845$ 76,127$
TT-30-LU 17 Low Uncontrolled 3,111 308 2,803 6,205 614 5,591 5.6720$ 5.1048$ 1,747$ 14,309$ 16,056$ 5.6720$ 5.1048$ 3,483$ 28,541$ 32,024$
TT-70-H 36 High n/a 6,588 652 5,936 13,140 1,301 11,839 9.5716$ 8.6144$ 6,241$ 51,135$ 57,376$ 9.5716$ 8.6144$ 12,453$ 101,986$ 114,439$
TT-70-L 29 Low n/a 5,307 525 4,782 10,585 1,048 9,537 12.7621$ 11.4859$ 6,700$ 54,926$ 61,626$ 12.7621$ 11.4859$ 13,375$ 109,541$ 122,916$
TT-150-H 10 High n/a 1,830 181 1,649 3,650 361 3,289 19.9940$ 17.9946$ 3,619$ 29,673$ 33,292$ 19.9940$ 17.9946$ 7,218$ 59,184$ 66,402$
TT-150-L 2 Low n/a 366 36 330 730 72 658 26.2333$ 23.6100$ 944$ 7,791$ 8,736$ 26.2333$ 23.6100$ 1,889$ 15,535$ 17,424$
DT-15-HC 11 High Controlled 2,013 199 1,814 4,015 397 3,618 1.2713$ 1.1442$ 253$ 2,076$ 2,329$ 1.2713$ 1.1442$ 505$ 4,140$ 4,644$
DT-15-LC 4 Low Controlled 732 72 660 1,460 145 1,315 1.8137$ 1.6323$ 131$ 1,077$ 1,208$ 1.8137$ 1.6323$ 263$ 2,146$ 2,409$
DT-15-HU 11 High Uncontrolled 2,013 199 1,814 4,015 397 3,618 1.2713$ 1.1442$ 253$ 2,076$ 2,329$ 1.2713$ 1.1442$ 505$ 4,140$ 4,644$
DT-15-LU 11 Low Uncontrolled 2,013 199 1,814 4,015 397 3,618 1.8137$ 1.6323$ 361$ 2,961$ 3,322$ 1.8137$ 1.6323$ 720$ 5,906$ 6,626$
DT-30-HC 25 High Controlled 4,575 453 4,122 9,125 903 8,222 2.5849$ 2.3264$ 1,171$ 9,589$ 10,760$ 2.5849$ 2.3264$ 2,334$ 19,128$ 21,462$
DT-30-LC 9 Low Controlled 1,647 163 1,484 3,285 325 2,960 3.3900$ 3.0510$ 553$ 4,528$ 5,080$ 3.3900$ 3.0510$ 1,102$ 9,031$ 10,133$
DT-30-HU 29 High Uncontrolled 5,307 525 4,782 10,585 1,048 9,537 2.5849$ 2.3264$ 1,357$ 11,125$ 12,482$ 2.5849$ 2.3264$ 2,709$ 22,187$ 24,896$
DT-30-LU 18 Low Uncontrolled 3,294 326 2,968 6,570 650 5,920 3.3900$ 3.0510$ 1,105$ 9,055$ 10,161$ 3.3900$ 3.0510$ 2,204$ 18,062$ 20,265$
DT-70-H 119 High n/a 21,777 2,156 19,621 43,435 4,300 39,135 5.7208$ 5.1487$ 12,334$ 101,023$ 113,357$ 5.7208$ 5.1487$ 24,599$ 201,494$ 226,094$
DT-70-L 149 Low n/a 27,267 2,699 24,568 54,385 5,384 49,001 7.6277$ 6.8649$ 20,587$ 168,657$ 189,244$ 7.6277$ 6.8649$ 41,068$ 336,387$ 377,455$
DT-150-H 13 High n/a 2,379 236 2,143 4,745 470 4,275 11.9501$ 10.7551$ 2,820$ 23,048$ 25,868$ 11.9501$ 10.7551$ 5,617$ 45,978$ 51,595$
DT-150-L 34 Low n/a 6,222 616 5,606 12,410 1,229 11,181 15.6792$ 14.1113$ 9,658$ 79,108$ 88,766$ 15.6792$ 14.1113$ 19,270$ 157,778$ 177,048$
RN-LFC-HC 642 High Controlled 117,486 11,631 105,855 234,330 23,199 211,131 0.1667$ 0.1500$ 1,939$ 15,878$ 17,817$ 0.1667$ 0.1500$ 3,867$ 31,670$ 35,537$
RN-LFC-LC 161 Low Controlled 29,463 2,917 26,546 58,765 5,818 52,947 0.1667$ 0.1500$ 486$ 3,982$ 4,468$ 0.1667$ 0.1500$ 970$ 7,942$ 8,912$
RN-LFC-HU 94 High Uncontrolled 17,202 1,703 15,499 34,310 3,397 30,913 0.1667$ 0.1500$ 284$ 2,325$ 2,609$ 0.1667$ 0.1500$ 566$ 4,637$ 5,203$
RN-LFC-LU 37 Low Uncontrolled 6,771 670 6,101 13,505 1,337 12,168 0.1667$ 0.1500$ 112$ 915$ 1,027$ 0.1667$ 0.1500$ 223$ 1,825$ 2,048$
RN-STD-HC 416 High Controlled 76,128 7,537 68,591 151,840 15,032 136,808 0.8054$ 0.7249$ 6,070$ 49,722$ 55,792$ 0.8054$ 0.7249$ 12,107$ 99,172$ 111,279$
RN-STD-LC 132 Low Controlled 24,156 2,391 21,765 48,180 4,770 43,410 1.4889$ 1.3400$ 3,560$ 29,165$ 32,725$ 1.4889$ 1.3400$ 7,102$ 58,169$ 65,271$
RN-STD-HU 34 High Uncontrolled 6,222 616 5,606 12,410 1,229 11,181 0.8054$ 0.7249$ 496$ 4,064$ 4,560$ 0.8054$ 0.7249$ 990$ 8,105$ 9,095$
RN-STD-LU 10 Low Uncontrolled 1,830 181 1,649 3,650 361 3,289 1.4889$ 1.3400$ 269$ 2,210$ 2,479$ 1.4889$ 1.3400$ 537$ 4,407$ 4,945$
GN-15-HC 132 High Controlled 24,156 2,391 21,765 48,180 4,770 43,410 1.6667$ 1.5000$ 3,985$ 32,648$ 36,633$ 1.6667$ 1.5000$ 7,950$ 65,115$ 73,065$
GN-15-LC 63 Low Controlled 11,529 1,141 10,388 22,995 2,277 20,718 2.3778$ 2.1400$ 2,713$ 22,230$ 24,943$ 2.3778$ 2.1400$ 5,414$ 44,337$ 49,751$
GN-15-HU 390 High Uncontrolled 71,370 7,066 64,304 142,350 14,093 128,257 1.6667$ 1.5000$ 11,777$ 96,456$ 108,233$ 1.6667$ 1.5000$ 23,489$ 192,386$ 215,874$
GN-15-LU 265 Low Uncontrolled 48,495 4,801 43,694 96,725 9,576 87,149 2.3778$ 2.1400$ 11,416$ 93,505$ 104,921$ 2.3778$ 2.1400$ 22,770$ 186,499$ 209,269$
GN-30-HC 11 High Controlled 2,013 199 1,814 4,015 397 3,618 3.3889$ 3.0500$ 674$ 5,533$ 6,207$ 3.3889$ 3.0500$ 1,345$ 11,035$ 12,380$
GN-30-LC 4 Low Controlled 732 72 660 1,460 145 1,315 4.4444$ 4.0000$ 320$ 2,640$ 2,960$ 4.4444$ 4.0000$ 644$ 5,260$ 5,904$
GN-30-HU 51 High Uncontrolled 9,333 924 8,409 18,615 1,843 16,772 3.3889$ 3.0500$ 3,131$ 25,647$ 28,779$ 3.3889$ 3.0500$ 6,246$ 51,155$ 57,400$
GN-30-LU 14 Low Uncontrolled 2,562 254 2,308 5,110 506 4,604 4.4444$ 4.0000$ 1,129$ 9,232$ 10,361$ 4.4444$ 4.0000$ 2,249$ 18,416$ 20,665$
GN-70-H 41 High n/a 7,503 743 6,760 14,965 1,482 13,483 7.5000$ 6.7500$ 5,573$ 45,630$ 51,203$ 7.5000$ 6.7500$ 11,115$ 91,010$ 102,125$
GN-70-L 2 Low n/a 366 36 330 730 72 658 10.0000$ 9.0000$ 360$ 2,970$ 3,330$ 10.0000$ 9.0000$ 720$ 5,922$ 6,642$
GN-150-H 5 High n/a 915 91 824 1,825 181 1,644 15.6667$ 14.1000$ 1,426$ 11,618$ 13,044$ 15.6667$ 14.1000$ 2,836$ 23,180$ 26,016$
GN-150-L 0 Low n/a 0 0 0 0 0 0 20.5556$ 18.5000$ -$ -$ -$ 20.5556$ 18.5000$ -$ -$ -$
TN-15-HC 157 High Controlled 28,731 2,844 25,887 57,305 5,673 51,632 2.1271$ 1.9144$ 6,049$ 49,558$ 55,608$ 2.1271$ 1.9144$ 12,067$ 98,844$ 110,911$
TN-15-LC 18 Low Controlled 3,294 326 2,968 6,570 650 5,920 3.0346$ 2.7311$ 989$ 8,106$ 9,095$ 3.0346$ 2.7311$ 1,972$ 16,168$ 18,141$
TN-15-HU 42 High Uncontrolled 7,686 761 6,925 15,330 1,518 13,812 2.1271$ 1.9144$ 1,619$ 13,257$ 14,876$ 2.1271$ 1.9144$ 3,229$ 26,442$ 29,671$
TN-15-LU 12 Low Uncontrolled 2,196 217 1,979 4,380 434 3,946 3.0346$ 2.7311$ 659$ 5,405$ 6,063$ 3.0346$ 2.7311$ 1,317$ 10,777$ 12,094$
TN-30-HC 3 High Controlled 549 54 495 1,095 108 987 4.3249$ 3.8924$ 234$ 1,927$ 2,160$ 4.3249$ 3.8924$ 467$ 3,842$ 4,309$
TN-30-LC 0 Low Controlled 0 0 0 0 0 0 5.6720$ 5.1048$ -$ -$ -$ 5.6720$ 5.1048$ -$ -$ -$
TN-30-HU 3 High Uncontrolled 549 54 495 1,095 108 987 4.3249$ 3.8924$ 234$ 1,927$ 2,160$ 4.3249$ 3.8924$ 467$ 3,842$ 4,309$
TN-30-LU 0 Low Uncontrolled 0 0 0 0 0 0 5.6720$ 5.1048$ -$ -$ -$ 5.6720$ 5.1048$ -$ -$ -$
TN-70-H 7 High n/a 1,281 127 1,154 2,555 253 2,302 9.5716$ 8.6144$ 1,216$ 9,941$ 11,157$ 9.5716$ 8.6144$ 2,422$ 19,830$ 22,252$
TN-70-L 5 Low n/a 915 91 824 1,825 181 1,644 12.7621$ 11.4859$ 1,161$ 9,464$ 10,626$ 12.7621$ 11.4859$ 2,310$ 18,883$ 21,193$
TN-150-H 0 High n/a 0 0 0 0 0 0 19.9940$ 17.9946$ -$ -$ -$ 19.9940$ 17.9946$ -$ -$ -$
TN-150-L 0 Low n/a 0 0 0 0 0 0 26.2333$ 23.6100$ -$ -$ -$ 26.2333$ 23.6100$ -$ -$ -$
DN-15-HC 2 High Controlled 366 36 330 730 72 658 1.2713$ 1.1442$ 46$ 378$ 423$ 1.2713$ 1.1442$ 92$ 753$ 844$
DN-15-LC 1 Low Controlled 183 18 165 365 36 329 1.8137$ 1.6323$ 33$ 269$ 302$ 1.8137$ 1.6323$ 65$ 537$ 602$
DN-15-HU 0 High Uncontrolled 0 0 0 0 0 0 1.2713$ 1.1442$ -$ -$ -$ 1.2713$ 1.1442$ -$ -$ -$
DN-15-LU 0 Low Uncontrolled 0 0 0 0 0 0 1.8137$ 1.6323$ -$ -$ -$ 1.8137$ 1.6323$ -$ -$ -$
DN-30-HC 0 High Controlled 0 0 0 0 0 0 2.5849$ 2.3264$ -$ -$ -$ 2.5849$ 2.3264$ -$ -$ -$
DN-30-LC 2 Low Controlled 366 36 330 730 72 658 3.3900$ 3.0510$ 122$ 1,007$ 1,129$ 3.3900$ 3.0510$ 244$ 2,008$ 2,252$
DN-30-HU 0 High Uncontrolled 0 0 0 0 0 0 2.5849$ 2.3264$ -$ -$ -$ 2.5849$ 2.3264$ -$ -$ -$
DN-30-LU 0 Low Uncontrolled 0 0 0 0 0 0 3.3900$ 3.0510$ -$ -$ -$ 3.3900$ 3.0510$ -$ -$ -$
DN-70-H 7 High n/a 1,281 127 1,154 2,555 253 2,302 5.7208$ 5.1487$ 727$ 5,942$ 6,668$ 5.7208$ 5.1487$ 1,447$ 11,852$ 13,300$
DN-70-L 2 Low n/a 366 36 330 730 72 658 7.6277$ 6.8649$ 275$ 2,265$ 2,540$ 7.6277$ 6.8649$ 549$ 4,517$ 5,066$
DN-150-H 0 High n/a 0 0 0 0 0 0 11.9501$ 10.7551$ -$ -$ -$ 11.9501$ 10.7551$ -$ -$ -$
DN-150-L 3 Low n/a 549 54 495 1,095 108 987 15.6792$ 14.1113$ 847$ 6,985$ 7,832$ 15.6792$ 14.1113$ 1,693$ 13,928$ 15,621$
4,249,626 420,706 3,828,920 8,476,030 839,125 7,636,906 595,679$ 4,879,405$ 5,475,085$ 1,188,155$ 9,732,108$ 10,920,263$
31-Mar-18
Quantity (Qt-2)
31-Mar-20
Price (Pt) Notional Revenue (Qt-2×Pt)
31-Mar-19
Price (Pt-1) Allowable Notional Revenue (Qt-2×Pt-1)
28
Table 17 Standard contract and low fixed charge (LFC) TOU peak
pri
cin
g c
od
en
o. o
f IC
Ps
de
nsi
tylo
ad
Bill
ed
Bill
ed
PP
D n
ot
ap
plie
dB
ille
d P
PD
ap
plie
dB
ille
dB
ille
d P
PD
no
t a
pp
lied
Bill
ed
PP
D a
pp
lied
$ p
er
kWh
$ p
er
kWh
(n
et
of
pp
d)
$ p
er
kWh
$ p
er
kWh
(n
et
of
pp
d)
RT
-LFC
-HC
4,5
37
Hig
hC
on
tro
lled
2,6
61
,59
52
63
,49
82
,39
8,0
97
6,3
39
,41
56
27
,60
25
,71
1,8
12
0.1
06
9$
0
.09
62
$
28
,16
8$
23
0,6
97
$
0.1
09
1$
0
.09
82
$
68
,47
1$
5
60
,90
0$
RT
-LFC
-LC
99
6Lo
wC
on
tro
lled
60
6,8
10
60
,07
45
46
,73
51
,35
0,1
57
13
3,6
66
1,2
16
,49
20
.13
80
$
0.1
24
2$
8
,29
0$
67
,90
4$
0.1
40
2$
0
.12
62
$
18
,74
0$
1
53
,52
1$
RT
-LFC
-HU
1,1
46
Hig
hU
nco
ntr
olle
d6
16
,48
76
1,0
32
55
5,4
55
1,4
89
,86
11
47
,49
61
,34
2,3
65
0.1
76
9$
0
.15
92
$
10
,79
7$
88
,42
8$
0.1
79
1$
0
.16
12
$
26
,41
7$
2
16
,38
9$
RT
-LFC
-LU
34
0Lo
wU
nco
ntr
olle
d1
73
,73
61
7,2
00
15
6,5
36
39
5,8
70
39
,19
13
56
,67
90
.20
80
$
0.1
87
2$
3
,57
8$
29
,30
4$
0.2
10
2$
0
.18
92
$
8,2
38
$
6
7,4
84
$
RT
-ST
D-H
C2
,66
2H
igh
Co
ntr
olle
d3
,45
4,5
49
34
2,0
00
3,1
12
,54
88
,58
1,1
66
84
9,5
35
7,7
31
,63
00
.07
78
$
0.0
70
0$
2
6,6
08
$
2
17
,87
8$
0.0
80
0$
0
.07
20
$
67
,96
3$
5
56
,67
7$
RT
-ST
D-L
C1
,06
3Lo
wC
on
tro
lled
1,5
85
,69
01
56
,98
31
,42
8,7
07
3,7
15
,75
23
67
,85
93
,34
7,8
92
0.0
77
8$
0
.07
00
$
12
,21
3$
10
0,0
09
$
0.0
80
0$
0
.07
20
$
29
,42
9$
2
41
,04
8$
RT
-ST
D-H
U5
78
Hig
hU
nco
ntr
olle
d7
31
,91
87
2,4
60
65
9,4
58
1,8
52
,40
51
83
,38
81
,66
9,0
17
0.1
47
8$
0
.13
30
$
10
,71
0$
87
,70
8$
0.1
50
0$
0
.13
50
$
27
,50
8$
2
25
,31
7$
RT
-ST
D-L
U2
24
Low
Un
con
tro
lled
31
6,7
22
31
,35
52
85
,36
67
64
,71
67
5,7
07
68
9,0
09
0.1
47
8$
0
.13
30
$
4,6
34
$
3
7,9
54
$
0
.15
00
$
0.1
35
0$
1
1,3
56
$
93
,01
6$
GT
-15
-HC
50
6H
igh
Co
ntr
olle
d3
42
,63
93
3,9
21
30
8,7
18
80
0,6
34
79
,26
37
21
,37
20
.07
34
$
0.0
66
1$
2
,49
0$
20
,40
6$
0.0
75
6$
0
.06
80
$
5,9
92
$
4
9,0
53
$
GT
-15
-LC
29
0Lo
wC
on
tro
lled
17
7,8
30
17
,60
51
60
,22
53
98
,68
03
9,4
69
35
9,2
10
0.0
73
4$
0
.06
61
$
1,2
92
$
1
0,5
91
$
0
.07
56
$
0.0
68
0$
2
,98
4$
24
,42
6$
GT
-15
-HU
1,7
89
Hig
hU
nco
ntr
olle
d9
73
,48
89
6,3
75
87
7,1
13
2,0
65
,98
12
04
,53
21
,86
1,4
49
0.1
28
9$
0
.11
60
$
12
,42
3$
10
1,7
45
$
0.1
31
1$
0
.11
80
$
26
,81
4$
2
19
,65
1$
GT
-15
-LU
1,6
77
Low
Un
con
tro
lled
90
4,5
96
89
,55
58
15
,04
11
,70
5,3
16
16
8,8
26
1,5
36
,49
00
.12
89
$
0.1
16
0$
1
1,5
44
$
9
4,5
45
$
0
.13
11
$
0.1
18
0$
2
2,1
33
$
18
1,3
06
$
GT
-30
-HC
60
Hig
hC
on
tro
lled
22
8,1
42
22
,58
62
05
,55
64
70
,12
94
6,5
43
42
3,5
86
0.0
87
8$
0
.07
90
$
1,9
83
$
1
6,2
39
$
0
.09
00
$
0.0
81
0$
4
,18
9$
34
,31
0$
GT
-30
-LC
13
Low
Co
ntr
olle
d8
0,2
36
7,9
43
72
,29
31
44
,86
31
4,3
41
13
0,5
22
0.0
87
8$
0
.07
90
$
69
7$
5
,71
1$
0
.09
00
$
0.0
81
0$
1
,29
1$
10
,57
2$
GT
-30
-HU
23
5H
igh
Un
con
tro
lled
80
8,4
14
80
,03
37
28
,38
11
,76
5,8
18
17
4,8
16
1,5
91
,00
20
.10
67
$
0.0
96
0$
8
,54
0$
69
,92
5$
0.1
08
9$
0
.09
80
$
19
,03
7$
1
55
,91
8$
GT
-30
-LU
51
Low
Un
con
tro
lled
15
7,2
62
15
,56
91
41
,69
33
14
,13
43
1,0
99
28
3,0
35
0.1
06
7$
0
.09
60
$
1,6
61
$
1
3,6
03
$
0
.10
89
$
0.0
98
0$
3
,38
7$
27
,73
7$
GT
-70
-H1
00
Hig
hn
/a7
18
,44
77
1,1
26
64
7,3
21
1,5
71
,56
01
55
,58
41
,41
5,9
76
0.0
76
7$
0
.06
90
$
5,4
55
$
4
4,6
65
$
0
.07
89
$
0.0
71
0$
1
2,2
76
$
10
0,5
34
$
GT
-70
-L1
6Lo
wn
/a1
06
,60
81
0,5
54
96
,05
42
30
,36
32
2,8
06
20
7,5
57
0.0
76
7$
0
.06
90
$
80
9$
6
,62
8$
0
.07
89
$
0.0
71
0$
1
,79
9$
14
,73
7$
GT
-15
0-H
28
Hig
hn
/a4
28
,22
14
2,3
94
38
5,8
27
1,0
94
,53
01
08
,35
89
86
,17
10
.06
11
$
0.0
55
0$
2
,59
0$
21
,22
0$
0.0
63
3$
0
.05
70
$
6,8
59
$
5
6,2
12
$
GT
-15
0-L
3Lo
wn
/a5
3,3
00
5,2
77
48
,02
31
17
,45
41
1,6
28
10
5,8
26
0.0
61
1$
0
.05
50
$
32
2$
2
,64
1$
0
.06
33
$
0.0
57
0$
7
36
$
6,0
32
$
TT
-15
-HC
2,1
73
Hig
hC
on
tro
lled
64
3,7
86
63
,73
55
80
,05
11
,49
4,8
17
14
7,9
87
1,3
46
,83
10
.07
34
$
0.0
66
1$
4
,67
8$
38
,34
1$
0.0
75
6$
0
.06
80
$
11
,18
8$
9
1,5
85
$
TT
-15
-LC
14
8Lo
wC
on
tro
lled
74
,91
87
,41
76
7,5
02
16
3,7
09
16
,20
71
47
,50
20
.07
34
$
0.0
66
1$
5
44
$
4,4
62
$
0.0
75
6$
0
.06
80
$
1,2
25
$
1
0,0
30
$
TT
-15
-HU
96
6H
igh
Un
con
tro
lled
27
4,1
17
27
,13
82
46
,98
06
96
,16
46
8,9
20
62
7,2
44
0.1
28
9$
0
.11
60
$
3,4
98
$
2
8,6
50
$
0
.13
11
$
0.1
18
0$
9
,03
5$
74
,01
5$
TT
-15
-LU
21
3Lo
wU
nco
ntr
olle
d5
3,7
72
5,3
23
48
,44
81
10
,58
11
0,9
47
99
,63
30
.12
89
$
0.1
16
0$
6
86
$
5,6
20
$
0.1
31
1$
0
.11
80
$
1,4
35
$
1
1,7
57
$
TT
-30
-HC
51
Hig
hC
on
tro
lled
87
,24
28
,63
77
8,6
05
22
6,7
30
22
,44
62
04
,28
30
.08
78
$
0.0
79
0$
7
58
$
6,2
10
$
0.0
90
0$
0
.08
10
$
2,0
20
$
1
6,5
47
$
TT
-30
-LC
9Lo
wC
on
tro
lled
10
,59
51
,04
99
,54
64
2,4
76
4,2
05
38
,27
10
.08
78
$
0.0
79
0$
9
2$
75
4$
0.0
90
0$
0
.08
10
$
37
8$
3
,10
0$
TT
-30
-HU
53
Hig
hU
nco
ntr
olle
d9
7,3
30
9,6
36
87
,69
42
54
,43
32
5,1
89
22
9,2
44
0.1
06
7$
0
.09
60
$
1,0
28
$
8
,41
9$
0
.10
89
$
0.0
98
0$
2
,74
3$
22
,46
6$
TT
-30
-LU
17
Low
Un
con
tro
lled
22
,12
22
,19
01
9,9
32
84
,10
38
,32
67
5,7
77
0.1
06
7$
0
.09
60
$
23
4$
1
,91
3$
0
.10
89
$
0.0
98
0$
9
07
$
7,4
26
$
TT
-70
-H3
6H
igh
n/a
31
7,5
22
31
,43
52
86
,08
77
65
,41
07
5,7
76
68
9,6
34
0.0
76
7$
0
.06
90
$
2,4
11
$
1
9,7
40
$
0
.07
89
$
0.0
71
0$
5
,97
9$
48
,96
4$
TT
-70
-L2
9Lo
wn
/a6
9,6
95
6,9
00
62
,79
52
88
,40
72
8,5
52
25
9,8
55
0.0
76
7$
0
.06
90
$
52
9$
4
,33
3$
0
.07
89
$
0.0
71
0$
2
,25
3$
18
,45
0$
TT
-15
0-H
10
Hig
hn
/a1
48
,39
81
4,6
91
13
3,7
07
38
6,9
09
38
,30
43
48
,60
50
.06
11
$
0.0
55
0$
8
98
$
7,3
54
$
0.0
63
3$
0
.05
70
$
2,4
25
$
1
9,8
70
$
TT
-15
0-L
2Lo
wn
/a5
7,4
80
5,6
90
51
,78
91
58
,43
91
5,6
85
14
2,7
53
0.0
61
1$
0
.05
50
$
34
8$
2
,84
8$
0
.06
33
$
0.0
57
0$
9
93
$
8,1
37
$
DT
-15
-HC
11
Hig
hC
on
tro
lled
19
,28
01
,90
91
7,3
71
30
,33
93
,00
42
7,3
35
0.0
73
4$
0
.06
61
$
14
0$
1
,14
8$
0
.07
56
$
0.0
68
0$
2
27
$
1,8
59
$
DT
-15
-LC
4Lo
wC
on
tro
lled
14
,74
71
,46
01
3,2
87
24
,51
22
,42
72
2,0
85
0.0
73
4$
0
.06
61
$
10
7$
8
78
$
0
.07
56
$
0.0
68
0$
1
83
$
1,5
02
$
DT
-15
-HU
11
Hig
hU
nco
ntr
olle
d2
7,4
57
2,7
18
24
,73
94
4,1
31
4,3
69
39
,76
20
.12
89
$
0.1
16
0$
3
50
$
2,8
70
$
0.1
31
1$
0
.11
80
$
57
3$
4
,69
2$
DT
-15
-LU
11
Low
Un
con
tro
lled
84
,47
08
,36
27
6,1
07
13
2,9
69
13
,16
41
19
,80
50
.12
89
$
0.1
16
0$
1
,07
8$
8,8
28
$
0.1
31
1$
0
.11
80
$
1,7
26
$
1
4,1
37
$
DT
-30
-HC
25
Hig
hC
on
tro
lled
22
8,9
79
22
,66
92
06
,31
03
53
,30
73
4,9
77
31
8,3
29
0.0
87
8$
0
.07
90
$
1,9
90
$
1
6,2
98
$
0
.09
00
$
0.0
81
0$
3
,14
8$
25
,78
5$
DT
-30
-LC
9Lo
wC
on
tro
lled
80
,01
97
,92
27
2,0
97
12
7,6
93
12
,64
21
15
,05
10
.08
78
$
0.0
79
0$
6
96
$
5,6
96
$
0.0
90
0$
0
.08
10
$
1,1
38
$
9
,31
9$
DT
-30
-HU
29
Hig
hU
nco
ntr
olle
d2
27
,25
02
2,4
98
20
4,7
53
35
2,7
50
34
,92
23
17
,82
80
.10
67
$
0.0
96
0$
2
,40
1$
19
,65
6$
0.1
08
9$
0
.09
80
$
3,8
03
$
3
1,1
47
$
DT
-30
-LU
18
Low
Un
con
tro
lled
17
3,9
75
17
,22
41
56
,75
12
82
,66
62
7,9
84
25
4,6
82
0.1
06
7$
0
.09
60
$
1,8
38
$
1
5,0
48
$
0
.10
89
$
0.0
98
0$
3
,04
7$
24
,95
9$
DT
-70
-H1
19
Hig
hn
/a1
,75
1,0
01
17
3,3
49
1,5
77
,65
22
,77
5,4
93
27
4,7
74
2,5
00
,71
90
.07
67
$
0.0
69
0$
1
3,2
96
$
1
08
,85
8$
0.0
78
9$
0
.07
10
$
21
,68
0$
1
77
,55
1$
DT
-70
-L1
49
Low
n/a
2,5
22
,42
92
49
,72
02
,27
2,7
08
3,9
43
,64
23
90
,42
13
,55
3,2
21
0.0
76
7$
0
.06
90
$
19
,15
4$
15
6,8
17
$
0.0
78
9$
0
.07
10
$
30
,80
4$
2
52
,27
9$
DT
-15
0-H
13
Hig
hn
/a3
36
,02
53
3,2
66
30
2,7
58
54
0,7
33
53
,53
34
87
,20
00
.06
11
$
0.0
55
0$
2
,03
3$
16
,65
2$
0.0
63
3$
0
.05
70
$
3,3
89
$
2
7,7
70
$
DT
-15
0-L
34
Low
n/a
1,0
10
,30
11
00
,02
09
10
,28
11
,65
2,2
18
16
3,5
70
1,4
88
,64
90
.06
11
$
0.0
55
0$
6
,11
1$
50
,06
5$
0.0
63
3$
0
.05
70
$
10
,35
4$
8
4,8
53
$
23
,45
9,5
99
2,3
22
,49
82
1,1
37
,09
75
0,1
01
,43
44
,96
0,0
40
45
,14
1,3
90
21
9,7
02
$
1,7
99
,26
1$
48
6,2
72
$
3
,98
3,0
41
$
Sta
nd
ard
co
ntr
act
an
d l
ow
fix
ed
ch
arg
e (
LF
C)
pe
ak
31
-Ma
r-2
0
Pri
ce (
Pt)
No
tio
na
l Re
ven
ue
(Q
t-2×
Pt)
31
-Ma
r-1
83
1-M
ar-
19
Pri
ce (
Pt-
1)
Allo
wa
ble
No
tio
na
l Re
ven
ue
(Q
t-2×
Pt-
1)
Qu
an
tity
(Q
t-2)
29
Table 18 Standard contract and low fixed charge (LFC) TOU shoulder
pri
cin
g c
od
en
o. o
f IC
Ps
de
nsi
tylo
ad
Bill
ed
Bill
ed
PP
D n
ot
ap
plie
dB
ille
d P
PD
ap
plie
dB
ille
d
Bill
ed
PP
D n
ot
ap
plie
dB
ille
d P
PD
ap
plie
d$
pe
r kW
h$
pe
r kW
h (
ne
t o
f p
pd
)$
pe
r kW
h
$ p
er
kWh
(ne
t o
f
pp
d)
RT
-LFC
-HC
4,5
37
Hig
hC
on
tro
lled
4,9
78
,58
54
92
,88
04
,48
5,7
05
11
,61
6,5
83
1,1
50
,04
21
0,4
66
,54
10
.14
47
$
0.1
30
2$
7
1,3
20
$
58
4,0
39
$
0.1
46
0$
0.1
31
4$
16
7,9
06
$
1
,37
5,3
03
$
RT
-LFC
-LC
99
6Lo
wC
on
tro
lled
1,1
31
,42
91
12
,01
11
,01
9,4
17
2,4
67
,91
62
44
,32
42
,22
3,5
92
0.1
75
8$
0
.15
82
$
19
,69
2$
1
61
,27
2$
0.1
77
1$
0.1
59
4$
43
,27
0$
3
54
,44
1$
RT
-LFC
-HU
1,1
46
Hig
hU
nco
ntr
olle
d1
,16
5,5
52
11
5,3
90
1,0
50
,16
32
,70
1,5
60
26
7,4
54
2,4
34
,10
60
.14
47
$
0.1
30
2$
1
6,6
97
$
13
6,7
31
$
0.1
46
0$
0.1
31
4$
39
,04
8$
3
19
,84
2$
RT
-LFC
-LU
34
0Lo
wU
nco
ntr
olle
d3
23
,46
03
2,0
23
29
1,4
37
71
2,2
41
70
,51
26
41
,73
00
.17
58
$
0.1
58
2$
5
,63
0$
46
,10
5$
0.1
77
1$
0.1
59
4$
12
,48
8$
1
02
,29
2$
RT
-ST
D-H
C2
,66
2H
igh
Co
ntr
olle
d6
,51
2,7
79
64
4,7
65
5,8
68
,01
41
5,8
24
,80
11
,56
6,6
55
14
,25
8,1
46
0.1
15
6$
0
.10
40
$
74
,53
5$
6
10
,27
3$
0.1
16
9$
0.1
05
2$
18
3,1
42
$
1
,49
9,9
57
$
RT
-ST
D-L
C1
,06
3Lo
wC
on
tro
lled
2,9
26
,28
72
89
,70
22
,63
6,5
85
6,7
68
,66
36
70
,09
86
,09
8,5
66
0.1
15
6$
0
.10
40
$
33
,49
0$
2
74
,20
5$
0.1
16
9$
0.1
05
2$
78
,33
4$
6
41
,56
9$
RT
-ST
D-H
U5
78
Hig
hU
nco
ntr
olle
d1
,38
2,8
52
13
6,9
02
1,2
45
,95
03
,39
5,3
31
33
6,1
38
3,0
59
,19
30
.11
56
$
0.1
04
0$
1
5,8
26
$
12
9,5
79
$
0.1
16
9$
0.1
05
2$
39
,29
5$
3
21
,82
7$
RT
-ST
D-L
U2
24
Low
Un
con
tro
lled
58
5,2
41
57
,93
95
27
,30
21
,37
2,8
21
13
5,9
09
1,2
36
,91
20
.11
56
$
0.1
04
0$
6
,69
8$
54
,83
9$
0.1
16
9$
0.1
05
2$
15
,88
8$
1
30
,12
3$
GT
-15
-HC
50
6H
igh
Co
ntr
olle
d7
33
,66
17
2,6
32
66
1,0
28
1,6
56
,85
81
64
,02
91
,49
2,8
29
0.1
15
6$
0
.10
40
$
8,3
96
$
6
8,7
47
$
0.1
16
9$
0.1
05
2$
19
,17
5$
1
57
,04
6$
GT
-15
-LC
29
0Lo
wC
on
tro
lled
34
6,4
42
34
,29
83
12
,14
57
65
,61
27
5,7
96
68
9,8
16
0.1
15
6$
0
.10
40
$
3,9
65
$
3
2,4
63
$
0.1
16
9$
0.1
05
2$
8,8
61
$
72
,56
9$
GT
-15
-HU
1,7
89
Hig
hU
nco
ntr
olle
d2
,34
0,7
69
23
1,7
36
2,1
09
,03
34
,92
7,5
86
48
7,8
31
4,4
39
,75
50
.11
56
$
0.1
04
0$
2
6,7
89
$
21
9,3
39
$
0.1
16
9$
0.1
05
2$
57
,02
7$
4
67
,06
2$
GT
-15
-LU
1,6
77
Low
Un
con
tro
lled
1,9
71
,35
41
95
,16
41
,77
6,1
90
3,7
34
,70
93
69
,73
63
,36
4,9
73
0.1
15
6$
0
.10
40
$
22
,56
1$
1
84
,72
4$
0.1
16
9$
0.1
05
2$
43
,22
2$
3
53
,99
5$
GT
-30
-HC
60
Hig
hC
on
tro
lled
50
3,0
17
49
,79
94
53
,21
91
,03
3,2
15
10
2,2
88
93
0,9
26
0.1
01
1$
0
.09
10
$
5,0
35
$
4
1,2
43
$
0.1
02
4$
0.0
92
2$
10
,47
4$
8
5,8
31
$
GT
-30
-LC
13
Low
Co
ntr
olle
d1
49
,72
01
4,8
22
13
4,8
98
28
4,1
12
28
,12
72
55
,98
50
.10
11
$
0.0
91
0$
1
,49
9$
12
,27
6$
0.1
02
4$
0.0
92
2$
2,8
80
$
23
,60
2$
GT
-30
-HU
23
5H
igh
Un
con
tro
lled
2,0
54
,58
72
03
,40
41
,85
1,1
83
4,3
52
,57
84
30
,90
53
,92
1,6
73
0.1
01
1$
0
.09
10
$
20
,56
4$
1
68
,45
8$
0.1
02
4$
0.0
92
2$
44
,12
5$
3
61
,57
8$
GT
-30
-LU
51
Low
Un
con
tro
lled
35
6,9
17
35
,33
53
21
,58
27
11
,46
67
0,4
35
64
1,0
31
0.1
01
1$
0
.09
10
$
3,5
72
$
2
9,2
64
$
0.1
02
4$
0.0
92
2$
7,2
13
$
59
,10
3$
GT
-70
-H1
00
Hig
hn
/a1
,72
5,5
07
17
0,8
25
1,5
54
,68
23
,70
4,9
30
36
6,7
88
3,3
38
,14
20
.09
00
$
0.0
81
0$
1
5,3
74
$
12
5,9
29
$
0.0
91
3$
0.0
82
2$
33
,48
8$
2
74
,39
5$
GT
-70
-L1
6Lo
wn
/a2
16
,22
92
1,4
07
19
4,8
22
48
0,0
20
47
,52
24
32
,49
80
.09
00
$
0.0
81
0$
1
,92
7$
15
,78
1$
0.0
91
3$
0.0
82
2$
4,3
39
$
35
,55
1$
GT
-15
0-H
28
Hig
hn
/a1
,16
6,4
09
11
5,4
74
1,0
50
,93
42
,66
8,0
85
26
4,1
40
2,4
03
,94
40
.07
89
$
0.0
71
0$
9
,11
1$
74
,61
6$
0.0
80
2$
0.0
72
2$
21
,18
4$
1
73
,56
5$
GT
-15
0-L
3Lo
wn
/a1
16
,72
71
1,5
56
10
5,1
71
25
7,3
27
25
,47
52
31
,85
20
.07
89
$
0.0
71
0$
9
12
$
7,4
67
$
0.0
80
2$
0.0
72
2$
2,0
43
$
16
,74
0$
TT
-15
-HC
2,1
73
Hig
hC
on
tro
lled
1,2
77
,40
91
26
,46
31
,15
0,9
46
2,8
10
,98
92
78
,28
82
,53
2,7
01
0.1
15
6$
0
.10
40
$
14
,61
9$
1
19
,69
8$
0.1
16
9$
0.1
05
2$
32
,53
2$
2
66
,44
0$
TT
-15
-LC
14
8Lo
wC
on
tro
lled
15
0,6
50
14
,91
41
35
,73
63
08
,73
13
0,5
64
27
8,1
67
0.1
15
6$
0
.10
40
$
1,7
24
$
1
4,1
17
$
0.1
16
9$
0.1
05
2$
3,5
73
$
29
,26
3$
TT
-15
-HU
96
6H
igh
Un
con
tro
lled
54
9,5
02
54
,40
14
95
,10
11
,30
1,9
09
12
8,8
89
1,1
73
,02
00
.11
56
$
0.1
04
0$
6
,28
9$
51
,49
1$
0.1
16
9$
0.1
05
2$
15
,06
7$
1
23
,40
2$
TT
-15
-LU
21
3Lo
wU
nco
ntr
olle
d1
10
,59
21
0,9
49
99
,64
32
16
,99
62
1,4
83
19
5,5
13
0.1
15
6$
0
.10
40
$
1,2
66
$
1
0,3
63
$
0.1
16
9$
0.1
05
2$
2,5
11
$
20
,56
8$
TT
-30
-HC
51
Hig
hC
on
tro
lled
16
4,5
63
16
,29
21
48
,27
14
09
,17
84
0,5
09
36
8,6
69
0.1
01
1$
0
.09
10
$
1,6
47
$
1
3,4
93
$
0.1
02
4$
0.0
92
2$
4,1
48
$
33
,99
1$
TT
-30
-LC
9Lo
wC
on
tro
lled
18
,61
51
,84
31
6,7
72
72
,49
57
,17
76
5,3
18
0.1
01
1$
0
.09
10
$
18
6$
1
,52
6$
0
.10
24
$
0
.09
22
$
7
35
$
6,0
22
$
TT
-30
-HU
53
Hig
hU
nco
ntr
olle
d1
82
,57
61
8,0
75
16
4,5
01
45
5,3
01
45
,07
54
10
,22
60
.10
11
$
0.0
91
0$
1
,82
7$
14
,97
0$
0.1
02
4$
0.0
92
2$
4,6
16
$
37
,82
3$
TT
-30
-LU
17
Low
Un
con
tro
lled
38
,54
63
,81
63
4,7
30
14
2,9
77
14
,15
51
28
,82
20
.10
11
$
0.0
91
0$
3
86
$
3,1
60
$
0.1
02
4$
0.0
92
2$
1,4
49
$
11
,87
7$
TT
-70
-H3
6H
igh
n/a
63
1,2
12
62
,49
05
68
,72
21
,48
3,3
75
14
6,8
54
1,3
36
,52
10
.09
00
$
0.0
81
0$
5
,62
4$
46
,06
6$
0.0
91
3$
0.0
82
2$
13
,40
8$
1
09
,86
2$
TT
-70
-L2
9Lo
wn
/a1
30
,49
81
2,9
19
11
7,5
78
51
3,3
12
50
,81
84
62
,49
40
.09
00
$
0.0
81
0$
1
,16
3$
9,5
24
$
0.0
91
3$
0.0
82
2$
4,6
40
$
38
,01
7$
TT
-15
0-H
10
Hig
hn
/a2
76
,39
62
7,3
63
24
9,0
33
71
9,1
39
71
,19
56
47
,94
40
.07
89
$
0.0
71
0$
2
,15
9$
17
,68
1$
0.0
80
2$
0.0
72
2$
5,7
10
$
46
,78
2$
TT
-15
0-L
2Lo
wn
/a9
7,4
17
9,6
44
87
,77
22
58
,45
62
5,5
87
23
2,8
68
0.0
78
9$
0
.07
10
$
76
1$
6
,23
2$
0
.08
02
$
0
.07
22
$
2
,05
2$
16
,81
3$
DT
-15
-HC
11
Hig
hC
on
tro
lled
27
,93
42
,76
52
5,1
68
49
,75
04
,92
54
4,8
25
0.1
15
6$
0
.10
40
$
32
0$
2
,61
7$
0
.11
69
$
0
.10
52
$
5
76
$
4,7
16
$
DT
-15
-LC
4Lo
wC
on
tro
lled
28
,04
42
,77
62
5,2
67
48
,66
44
,81
84
3,8
46
0.1
15
6$
0
.10
40
$
32
1$
2
,62
8$
0
.11
69
$
0
.10
52
$
5
63
$
4,6
13
$
DT
-15
-HU
11
Hig
hU
nco
ntr
olle
d4
1,7
58
4,1
34
37
,62
47
2,3
65
7,1
64
65
,20
10
.11
56
$
0.1
04
0$
4
78
$
3,9
13
$
0.1
16
9$
0.1
05
2$
83
7$
6
,85
9$
DT
-15
-LU
11
Low
Un
con
tro
lled
13
8,2
83
13
,69
01
24
,59
32
27
,05
22
2,4
78
20
4,5
74
0.1
15
6$
0
.10
40
$
1,5
83
$
1
2,9
58
$
0.1
16
9$
0.1
05
2$
2,6
28
$
21
,52
1$
DT
-30
-HC
25
Hig
hC
on
tro
lled
32
4,6
47
32
,14
02
92
,50
75
30
,14
15
2,4
84
47
7,6
57
0.1
01
1$
0
.09
10
$
3,2
49
$
2
6,6
18
$
0.1
02
4$
0.0
92
2$
5,3
74
$
44
,04
0$
DT
-30
-LC
9Lo
wC
on
tro
lled
10
7,3
07
10
,62
39
6,6
83
18
5,5
70
18
,37
11
67
,19
80
.10
11
$
0.0
91
0$
1
,07
4$
8,7
98
$
0.1
02
4$
0.0
92
2$
1,8
81
$
15
,41
6$
DT
-30
-HU
29
Hig
hU
nco
ntr
olle
d3
38
,35
93
3,4
97
30
4,8
61
55
5,4
45
54
,98
95
00
,45
60
.10
11
$
0.0
91
0$
3
,38
7$
27
,74
2$
0.1
02
4$
0.0
92
2$
5,6
31
$
46
,14
2$
DT
-30
-LU
18
Low
Un
con
tro
lled
26
1,1
35
25
,85
22
35
,28
34
42
,48
74
3,8
06
39
8,6
81
0.1
01
1$
0
.09
10
$
2,6
14
$
2
1,4
11
$
0.1
02
4$
0.0
92
2$
4,4
86
$
36
,75
8$
DT
-70
-H1
19
Hig
hn
/a2
,67
7,9
81
26
5,1
20
2,4
12
,86
14
,45
6,7
16
44
1,2
15
4,0
15
,50
10
.09
00
$
0.0
81
0$
2
3,8
61
$
19
5,4
42
$
0.0
91
3$
0.0
82
2$
40
,28
3$
3
30
,07
4$
DT
-70
-L1
49
Low
n/a
4,1
14
,15
24
07
,30
13
,70
6,8
51
6,6
71
,81
16
60
,50
96
,01
1,3
01
0.0
90
0$
0
.08
10
$
36
,65
7$
3
00
,25
5$
0.0
91
3$
0.0
82
2$
60
,30
4$
4
94
,12
9$
DT
-15
0-H
13
Hig
hn
/a5
33
,18
15
2,7
85
48
0,3
96
89
6,0
78
88
,71
28
07
,36
60
.07
89
$
0.0
71
0$
4
,16
5$
34
,10
8$
0.0
80
2$
0.0
72
2$
7,1
15
$
58
,29
2$
DT
-15
0-L
34
Low
n/a
1,7
85
,22
51
76
,73
71
,60
8,4
88
3,0
03
,11
32
97
,30
82
,70
5,8
05
0.0
78
9$
0
.07
10
$
13
,94
5$
1
14
,20
3$
0.0
80
2$
0.0
72
2$
23
,84
4$
1
95
,35
9$
44
,69
3,5
05
4,4
24
,65
34
0,2
68
,84
79
5,2
68
,46
59
,43
1,5
77
85
,83
6,8
84
49
2,8
92
$
4,0
36
,36
4$
1,0
77
,36
4$
8
,82
5,1
70
$
Sta
nd
ard
co
ntr
act
an
d l
ow
fix
ed
ch
arg
e (
LF
C)
sho
uld
er
Pri
ce (
Pt-
1)
31
-Ma
r-1
9
Allo
wa
ble
No
tio
na
l Re
ven
ue
(Q
t-2×
Pt-
1)
31
-Ma
r-2
0
Pri
ce (
Pt)
No
tio
na
l Re
ven
ue
(Q
t-2×
Pt)
31
-Ma
r-1
8
Qu
an
tity
(Q
t-2)
30
Table 19 Standard contract and low fixed charge (LFC) TOU off peak
pri
cin
g c
od
en
o. o
f IC
Ps
de
nsi
tylo
ad
Bill
ed
Bill
ed
PP
D
no
t a
pp
lied
Bill
ed
PP
D
ap
plie
dB
ille
d
Bill
ed
PP
D
no
t a
pp
lied
Bill
ed
PP
D
ap
plie
d$
pe
r kW
h$
pe
r kW
h (
ne
t o
f p
pd
)$
pe
r kW
h
$ p
er
kWh
(ne
t o
f
pp
d)
RT
-LFC
-HC
4,5
37
Hig
hC
on
tro
lled
2,1
93
,52
22
17
,15
91
,97
6,3
63
5,2
43
,01
25
19
,05
84
,72
3,9
54
0.0
90
2$
0
.08
12
$
19
,58
8$
16
0,4
81
$
0
.09
15
$
0.0
82
4$
4
7,4
94
$
3
89
,25
4$
RT
-LFC
-LC
99
6Lo
wC
on
tro
lled
51
4,8
65
50
,97
24
63
,89
31
,13
8,0
65
11
2,6
68
1,0
25
,39
70
.12
13
$
0.1
09
2$
6
,18
3$
50
,65
7$
0
.12
26
$
0.1
10
3$
1
3,8
13
$
1
13
,10
1$
RT
-LFC
-HU
1,1
46
Hig
hU
nco
ntr
olle
d5
37
,45
65
3,2
08
48
4,2
48
1,2
95
,38
91
28
,24
41
,16
7,1
46
0.0
90
2$
0
.08
12
$
4,7
99
$
39
,32
1$
0
.09
15
$
0.0
82
4$
1
1,7
34
$
9
6,1
73
$
RT
-LFC
-LU
34
0Lo
wU
nco
ntr
olle
d1
45
,48
21
4,4
03
13
1,0
79
32
9,7
33
32
,64
42
97
,09
00
.12
13
$
0.1
09
2$
1
,74
7$
14
,31
4$
0
.12
26
$
0.1
10
3$
4
,00
2$
32
,76
9$
RT
-ST
D-H
C2
,66
2H
igh
Co
ntr
olle
d2
,87
3,8
05
28
4,5
07
2,5
89
,29
87
,58
0,8
23
75
0,5
02
6,8
30
,32
20
.06
11
$
0.0
55
0$
1
7,3
83
$
14
2,4
11
$
0
.06
24
$
0.0
56
2$
4
6,8
31
$
3
83
,86
4$
RT
-ST
D-L
C1
,06
3Lo
wC
on
tro
lled
1,3
18
,96
61
30
,57
81
,18
8,3
89
3,2
25
,19
13
19
,29
42
,90
5,8
97
0.0
61
1$
0
.05
50
$
7,9
78
$
65
,36
1$
0
.06
24
$
0.0
56
2$
1
9,9
24
$
1
63
,31
1$
RT
-ST
D-H
U5
78
Hig
hU
nco
ntr
olle
d6
34
,74
96
2,8
40
57
1,9
09
1,7
07
,22
71
69
,01
51
,53
8,2
12
0.0
61
1$
0
.05
50
$
3,8
40
$
31
,45
5$
0
.06
24
$
0.0
56
2$
1
0,5
47
$
8
6,4
48
$
RT
-ST
D-L
U2
24
Low
Un
con
tro
lled
26
5,2
24
26
,25
72
38
,96
76
64
,57
56
5,7
93
59
8,7
82
0.0
61
1$
0
.05
50
$
1,6
04
$
13
,14
3$
0
.06
24
$
0.0
56
2$
4
,10
5$
33
,65
2$
GT
-15
-HC
50
6H
igh
Co
ntr
olle
d3
33
,56
23
3,0
23
30
0,5
39
79
1,6
39
78
,37
27
13
,26
60
.06
11
$
0.0
55
0$
2
,01
8$
16
,53
0$
0
.06
24
$
0.0
56
2$
4
,89
0$
40
,08
6$
GT
-15
-LC
29
0Lo
wC
on
tro
lled
17
3,4
25
17
,16
91
56
,25
63
99
,18
03
9,5
19
35
9,6
61
0.0
61
1$
0
.05
50
$
1,0
49
$
8,5
94
$
0.0
62
4$
0
.05
62
$
2,4
66
$
2
0,2
13
$
GT
-15
-HU
1,7
89
Hig
hU
nco
ntr
olle
d1
,05
8,8
21
10
4,8
23
95
3,9
98
2,2
33
,25
82
21
,09
22
,01
2,1
65
0.0
61
1$
0
.05
50
$
6,4
05
$
52
,47
0$
0
.06
24
$
0.0
56
2$
1
3,7
96
$
1
13
,08
4$
GT
-15
-LU
1,6
77
Low
Un
con
tro
lled
1,0
24
,00
21
01
,37
69
22
,62
61
,97
4,3
81
19
5,4
64
1,7
78
,91
80
.06
11
$
0.0
55
0$
6
,19
4$
50
,74
4$
0
.06
24
$
0.0
56
2$
1
2,1
97
$
9
9,9
75
$
GT
-30
-HC
60
Hig
hC
on
tro
lled
21
6,3
86
21
,42
21
94
,96
44
47
,10
94
4,2
64
40
2,8
45
0.0
50
0$
0
.04
50
$
1,0
71
$
8,7
73
$
0.0
51
3$
0
.04
62
$
2,2
71
$
1
8,6
11
$
GT
-30
-LC
13
Low
Co
ntr
olle
d6
7,5
77
6,6
90
60
,88
71
28
,43
81
2,7
15
11
5,7
23
0.0
50
0$
0
.04
50
$
33
5$
2,7
40
$
0.0
51
3$
0
.04
62
$
65
2$
5
,34
6$
GT
-30
-HU
23
5H
igh
Un
con
tro
lled
80
8,0
27
79
,99
57
28
,03
21
,73
8,3
96
17
2,1
01
1,5
66
,29
50
.05
00
$
0.0
45
0$
4
,00
0$
32
,76
1$
0
.05
13
$
0.0
46
2$
8
,82
9$
72
,36
3$
GT
-30
-LU
51
Low
Un
con
tro
lled
18
3,4
57
18
,16
21
65
,29
53
67
,37
53
6,3
70
33
1,0
04
0.0
50
0$
0
.04
50
$
90
8$
7,4
38
$
0.0
51
3$
0
.04
62
$
1,8
66
$
1
5,2
92
$
GT
-70
-H1
00
Hig
hn
/a6
64
,37
46
5,7
73
59
8,6
01
1,3
77
,64
61
36
,38
71
,24
1,2
59
0.0
50
0$
0
.04
50
$
3,2
89
$
26
,93
7$
0
.05
13
$
0.0
46
2$
6
,99
7$
57
,34
6$
GT
-70
-L1
6Lo
wn
/a1
12
,42
21
1,1
30
10
1,2
92
23
7,7
64
23
,53
92
14
,22
60
.05
00
$
0.0
45
0$
5
57
$
4,5
58
$
0.0
51
3$
0
.04
62
$
1,2
08
$
9
,89
7$
GT
-15
0-H
28
Hig
hn
/a4
26
,28
84
2,2
02
38
4,0
85
94
5,3
13
93
,58
68
51
,72
70
.05
00
$
0.0
45
0$
2
,11
0$
17
,28
4$
0
.05
13
$
0.0
46
2$
4
,80
1$
39
,35
0$
GT
-15
0-L
3Lo
wn
/a7
7,1
10
7,6
34
69
,47
61
72
,25
61
7,0
53
15
5,2
03
0.0
50
0$
0
.04
50
$
38
2$
3,1
26
$
0.0
51
3$
0
.04
62
$
87
5$
7
,17
0$
TT
-15
-HC
2,1
73
Hig
hC
on
tro
lled
60
8,0
52
60
,19
75
47
,85
51
,45
0,6
24
14
3,6
12
1,3
07
,01
20
.06
11
$
0.0
55
0$
3
,67
8$
30
,13
2$
0
.06
24
$
0.0
56
2$
8
,96
1$
73
,45
4$
TT
-15
-LC
14
8Lo
wC
on
tro
lled
69
,04
76
,83
66
2,2
12
15
1,5
26
15
,00
11
36
,52
50
.06
11
$
0.0
55
0$
4
18
$
3,4
22
$
0.0
62
4$
0
.05
62
$
93
6$
7
,67
3$
TT
-15
-HU
96
6H
igh
Un
con
tro
lled
26
4,2
14
26
,15
72
38
,05
76
91
,39
96
8,4
49
62
2,9
51
0.0
61
1$
0
.05
50
$
1,5
98
$
13
,09
3$
0
.06
24
$
0.0
56
2$
4
,27
1$
35
,01
0$
TT
-15
-LU
21
3Lo
wU
nco
ntr
olle
d5
4,0
35
5,3
50
48
,68
61
11
,14
71
1,0
04
10
0,1
43
0.0
61
1$
0
.05
50
$
32
7$
2,6
78
$
0.0
62
4$
0
.05
62
$
68
7$
5
,62
8$
TT
-30
-HC
51
Hig
hC
on
tro
lled
88
,30
78
,74
27
9,5
65
23
7,9
15
23
,55
42
14
,36
20
.05
00
$
0.0
45
0$
4
37
$
3,5
80
$
0.0
51
3$
0
.04
62
$
1,2
08
$
9
,90
4$
TT
-30
-LC
9Lo
wC
on
tro
lled
13
,32
91
,32
01
2,0
10
48
,88
04
,83
94
4,0
41
0.0
50
0$
0
.04
50
$
66
$
5
40
$
0.0
51
3$
0
.04
62
$
24
8$
2
,03
5$
TT
-30
-HU
53
Hig
hU
nco
ntr
olle
d9
5,1
97
9,4
25
85
,77
32
58
,67
52
5,6
09
23
3,0
66
0.0
50
0$
0
.04
50
$
47
1$
3,8
60
$
0.0
51
3$
0
.04
62
$
1,3
14
$
1
0,7
68
$
TT
-30
-LU
17
Low
Un
con
tro
lled
22
,73
92
,25
12
0,4
88
82
,33
08
,15
17
4,1
79
0.0
50
0$
0
.04
50
$
11
3$
92
2$
0
.05
13
$
0.0
46
2$
4
18
$
3,4
27
$
TT
-70
-H3
6H
igh
n/a
30
0,5
12
29
,75
12
70
,76
27
45
,72
57
3,8
27
67
1,8
98
0.0
50
0$
0
.04
50
$
1,4
88
$
12
,18
4$
0
.05
13
$
0.0
46
2$
3
,78
7$
31
,04
2$
TT
-70
-L2
9Lo
wn
/a9
1,9
36
9,1
02
82
,83
53
51
,01
33
4,7
50
31
6,2
63
0.0
50
0$
0
.04
50
$
45
5$
3,7
28
$
0.0
51
3$
0
.04
62
$
1,7
83
$
1
4,6
11
$
TT
-15
0-H
10
Hig
hn
/a1
17
,65
01
1,6
47
10
6,0
03
33
8,4
96
33
,51
13
04
,98
50
.05
00
$
0.0
45
0$
5
82
$
4,7
70
$
0.0
51
3$
0
.04
62
$
1,7
19
$
1
4,0
90
$
TT
-15
0-L
2Lo
wn
/a5
0,7
96
5,0
29
45
,76
71
53
,75
71
5,2
22
13
8,5
35
0.0
50
0$
0
.04
50
$
25
1$
2,0
60
$
0.0
51
3$
0
.04
62
$
78
1$
6
,40
0$
DT
-15
-HC
11
Hig
hC
on
tro
lled
13
,01
51
,28
81
1,7
26
22
,77
32
,25
52
0,5
19
0.0
61
1$
0
.05
50
$
79
$
6
45
$
0.0
62
4$
0
.05
62
$
14
1$
1
,15
3$
DT
-15
-LC
4Lo
wC
on
tro
lled
14
,67
61
,45
31
3,2
23
23
,35
42
,31
22
1,0
42
0.0
61
1$
0
.05
50
$
89
$
7
27
$
0.0
62
4$
0
.05
62
$
14
4$
1
,18
3$
DT
-15
-HU
11
Hig
hU
nco
ntr
olle
d2
1,0
90
2,0
88
19
,00
23
4,9
76
3,4
63
31
,51
30
.06
11
$
0.0
55
0$
1
28
$
1,0
45
$
0.0
62
4$
0
.05
62
$
21
6$
1
,77
1$
DT
-15
-LU
11
Low
Un
con
tro
lled
67
,06
36
,63
96
0,4
24
10
7,7
27
10
,66
59
7,0
62
0.0
61
1$
0
.05
50
$
40
6$
3,3
23
$
0.0
62
4$
0
.05
62
$
66
5$
5
,45
5$
DT
-30
-HC
25
Hig
hC
on
tro
lled
15
2,8
59
15
,13
31
37
,72
62
60
,56
02
5,7
95
23
4,7
65
0.0
50
0$
0
.04
50
$
75
7$
6,1
98
$
0.0
51
3$
0
.04
62
$
1,3
23
$
1
0,8
46
$
DT
-30
-LC
9Lo
wC
on
tro
lled
56
,16
75
,56
05
0,6
06
92
,23
09
,13
18
3,0
99
0.0
50
0$
0
.04
50
$
27
8$
2,2
77
$
0.0
51
3$
0
.04
62
$
46
8$
3
,83
9$
DT
-30
-HU
29
Hig
hU
nco
ntr
olle
d1
75
,00
71
7,3
26
15
7,6
81
29
4,6
01
29
,16
62
65
,43
60
.05
00
$
0.0
45
0$
8
66
$
7,0
96
$
0.0
51
3$
0
.04
62
$
1,4
96
$
1
2,2
63
$
DT
-30
-LU
18
Low
Un
con
tro
lled
13
4,9
45
13
,36
01
21
,58
62
26
,02
92
2,3
77
20
3,6
52
0.0
50
0$
0
.04
50
$
66
8$
5,4
71
$
0.0
51
3$
0
.04
62
$
1,1
48
$
9
,40
9$
DT
-70
-H1
19
Hig
hn
/a1
,41
7,7
57
14
0,3
58
1,2
77
,39
92
,32
2,4
62
22
9,9
24
2,0
92
,53
90
.05
00
$
0.0
45
0$
7
,01
8$
57
,48
3$
0
.05
13
$
0.0
46
2$
1
1,7
95
$
9
6,6
75
$
DT
-70
-L1
49
Low
n/a
1,9
69
,97
21
95
,02
71
,77
4,9
45
3,1
83
,83
83
15
,20
02
,86
8,6
38
0.0
50
0$
0
.04
50
$
9,7
51
$
79
,87
3$
0
.05
13
$
0.0
46
2$
1
6,1
70
$
1
32
,53
1$
DT
-15
0-H
13
Hig
hn
/a3
03
,34
03
0,0
31
27
3,3
10
50
5,8
69
50
,08
14
55
,78
80
.05
00
$
0.0
45
0$
1
,50
2$
12
,29
9$
0
.05
13
$
0.0
46
2$
2
,56
9$
21
,05
7$
DT
-15
0-L
34
Low
n/a
85
3,2
33
84
,47
07
68
,76
31
,40
2,8
39
13
8,8
81
1,2
63
,95
80
.05
00
$
0.0
45
0$
4
,22
4$
34
,59
4$
0
.05
13
$
0.0
46
2$
7
,12
5$
58
,39
5$
20
,58
4,4
60
2,0
37
,86
31
8,5
46
,60
14
5,0
95
,51
74
,46
4,4
59
40
,63
1,0
63
12
7,0
87
$
1,0
41
,10
0$
2
88
,67
3$
2
,36
5,9
24
$
Sta
nd
ard
co
ntr
act
an
d l
ow
fix
ed
ch
arg
e (
LF
C)
off
pe
ak
Pri
ce (
Pt-
1)
Allo
wa
ble
No
tio
na
l Re
ven
ue
31
-Ma
r-1
93
1-M
ar-
20
Pri
ce (
Pt)
No
tio
na
l Re
ven
ue
(Q
t-Q
ua
nti
ty (
Qt-
2)
31
-Ma
r-1
8
31
Table 20 Standard contract and low fixed charge (LFC) non-time of use (anytime)
Table 21 Metering fees
pricing code no. of ICPs density load Billed
Billed PPD
not applied
Billed PPD
applied Billed
Billed PPD
not applied
Billed PPD
applied $ per kWh
$ per kWh
(net of ppd) $ per kWh
$ per kWh
(net of
ppd)
RN-LFC-HC 642 High Controlled 1,312,447 129,932 1,182,514 3,179,242 314,745 2,864,497 0.1294$ 0.1165$ 16,813$ 137,763$ 0.1294$ 0.1165$ 40,728$ 333,714$
RN-LFC-LC 161 Low Controlled 322,503 31,928 290,575 779,601 77,181 702,421 0.1605$ 0.1445$ 5,124$ 41,988$ 0.1605$ 0.1445$ 12,388$ 101,500$
RN-LFC-HU 94 High Uncontrolled 144,904 14,346 130,559 351,869 34,835 317,034 0.1551$ 0.1396$ 2,225$ 18,226$ 0.1551$ 0.1396$ 5,403$ 44,258$
RN-LFC-LU 37 Low Uncontrolled 68,956 6,827 62,130 166,569 16,490 150,079 0.1862$ 0.1676$ 1,271$ 10,413$ 0.1862$ 0.1676$ 3,070$ 25,153$
RN-STD-HC 416 High Controlled 2,222,421 220,020 2,002,402 5,406,882 535,281 4,871,601 0.1003$ 0.0903$ 22,068$ 180,817$ 0.1003$ 0.0903$ 53,689$ 439,906$
RN-STD-LC 132 Low Controlled 746,564 73,910 672,654 1,803,042 178,501 1,624,541 0.1003$ 0.0903$ 7,413$ 60,741$ 0.1003$ 0.0903$ 17,904$ 146,696$
RN-STD-HU 34 High Uncontrolled 185,525 18,367 167,158 462,353 45,773 416,580 0.1260$ 0.1134$ 2,314$ 18,956$ 0.1260$ 0.1134$ 5,767$ 47,240$
RN-STD-LU 10 Low Uncontrolled 57,147 5,658 51,490 136,670 13,530 123,140 0.1260$ 0.1134$ 713$ 5,839$ 0.1260$ 0.1134$ 1,705$ 13,964$
GN-15-HC 132 High Controlled 345,710 34,225 311,485 775,707 76,795 698,912 0.0988$ 0.0889$ 3,381$ 27,691$ 0.0988$ 0.0889$ 7,587$ 62,133$
GN-15-LC 63 Low Controlled 171,963 17,024 154,938 360,691 35,708 324,983 0.0988$ 0.0889$ 1,682$ 13,774$ 0.0988$ 0.0889$ 3,528$ 28,891$
GN-15-HU 390 High Uncontrolled 790,016 78,212 711,804 1,731,364 171,405 1,559,959 0.1191$ 0.1072$ 9,315$ 76,305$ 0.1201$ 0.1081$ 20,586$ 168,632$
GN-15-LU 265 Low Uncontrolled 388,800 38,491 350,309 794,058 78,612 715,446 0.1191$ 0.1072$ 4,584$ 37,553$ 0.1201$ 0.1081$ 9,441$ 77,340$
GN-30-HC 11 High Controlled 216,943 21,477 195,466 464,496 45,985 418,511 0.0947$ 0.0852$ 2,034$ 16,654$ 0.0957$ 0.0861$ 4,401$ 36,034$
GN-30-LC 4 Low Controlled 97,366 9,639 87,727 204,973 20,292 184,681 0.0947$ 0.0852$ 913$ 7,474$ 0.0957$ 0.0861$ 1,942$ 15,901$
GN-30-HU 51 High Uncontrolled 658,116 65,154 592,963 1,409,070 139,498 1,269,572 0.1015$ 0.0914$ 6,613$ 54,197$ 0.1025$ 0.0923$ 14,299$ 117,181$
GN-30-LU 14 Low Uncontrolled 234,917 23,257 211,660 471,267 46,655 424,611 0.1015$ 0.0914$ 2,361$ 19,346$ 0.1025$ 0.0923$ 4,782$ 39,192$
GN-70-H 41 High n/a 1,311,469 129,835 1,181,633 3,003,118 297,309 2,705,809 0.0865$ 0.0779$ 11,231$ 92,049$ 0.0875$ 0.0788$ 26,015$ 213,218$
GN-70-L 2 Low n/a 154,559 15,301 139,257 245,627 24,317 221,310 0.0865$ 0.0779$ 1,324$ 10,848$ 0.0875$ 0.0788$ 2,128$ 17,439$
GN-150-H 5 High n/a 383,965 38,013 345,952 851,736 84,322 767,414 0.0768$ 0.0691$ 2,919$ 23,905$ 0.0778$ 0.0700$ 6,560$ 53,719$
GN-150-L 0 Low n/a 0 0 0 0 0 0 0.0768$ 0.0691$ -$ -$ 0.0778$ 0.0700$ -$ -$
TN-15-HC 157 High Controlled 202,691 20,066 182,625 452,258 44,774 407,484 0.0988$ 0.0889$ 1,983$ 16,235$ 0.0988$ 0.0889$ 4,424$ 36,225$
TN-15-LC 18 Low Controlled 25,416 2,516 22,900 53,335 5,280 48,055 0.0988$ 0.0889$ 249$ 2,036$ 0.0988$ 0.0889$ 522$ 4,272$
TN-15-HU 42 High Uncontrolled 75,641 7,488 68,153 179,367 17,757 161,610 0.1191$ 0.1072$ 892$ 7,306$ 0.1201$ 0.1081$ 2,133$ 17,470$
TN-15-LU 12 Low Uncontrolled 14,051 1,391 12,660 32,206 3,188 29,018 0.1191$ 0.1072$ 166$ 1,357$ 0.1201$ 0.1081$ 383$ 3,137$
TN-30-HC 3 High Controlled 16,871 1,670 15,200 62,069 6,145 55,924 0.0947$ 0.0852$ 158$ 1,295$ 0.0957$ 0.0861$ 588$ 4,815$
TN-30-LC 0 Low Controlled 0 0 0 0 0 0 0.0947$ 0.0852$ -$ -$ 0.0957$ 0.0861$ -$ -$
TN-30-HU 3 High Uncontrolled 17,645 1,747 15,898 53,908 5,337 48,572 0.1015$ 0.0914$ 177$ 1,453$ 0.1025$ 0.0923$ 547$ 4,483$
TN-30-LU 0 Low Uncontrolled 0 0 0 0 0 0 0.1015$ 0.0914$ -$ -$ 0.1025$ 0.0923$ -$ -$
TN-70-H 7 High n/a 168,652 16,697 151,956 381,747 37,793 343,954 0.0865$ 0.0779$ 1,444$ 11,837$ 0.0875$ 0.0788$ 3,307$ 27,104$
TN-70-L 5 Low n/a 44,031 4,359 39,672 179,592 17,780 161,813 0.0865$ 0.0779$ 377$ 3,090$ 0.0875$ 0.0788$ 1,556$ 12,751$
TN-150-H 0 High n/a 0 0 0 0 0 0 0.0768$ 0.0691$ -$ -$ 0.0778$ 0.0700$ -$ -$
TN-150-L 0 Low n/a 0 0 0 0 0 0 0.0768$ 0.0691$ -$ -$ 0.0778$ 0.0700$ -$ -$
DN-15-HC 2 High Controlled 18,928 1,874 17,054 31,858 3,154 28,704 0.0988$ 0.0889$ 185$ 1,516$ 0.0988$ 0.0889$ 312$ 2,552$
DN-15-LC 1 Low Controlled 8,513 843 7,670 14,328 1,419 12,910 0.0988$ 0.0889$ 83$ 682$ 0.0988$ 0.0889$ 140$ 1,148$
DN-15-HU 0 High Uncontrolled 0 0 0 0 0 0 0.1191$ 0.1072$ -$ -$ 0.1201$ 0.1081$ -$ -$
DN-15-LU 0 Low Uncontrolled 0 0 0 0 0 0 0.1191$ 0.1072$ -$ -$ 0.1201$ 0.1081$ -$ -$
DN-30-HC 0 High Controlled 0 0 0 0 0 0 0.0947$ 0.0852$ -$ -$ 0.0957$ 0.0861$ -$ -$
DN-30-LC 2 Low Controlled 50,504 5,000 45,504 84,371 8,353 76,019 0.0947$ 0.0852$ 474$ 3,877$ 0.0957$ 0.0861$ 799$ 6,545$
DN-30-HU 0 High Uncontrolled 0 0 0 0 0 0 0.1015$ 0.0914$ -$ -$ 0.1025$ 0.0923$ -$ -$
DN-30-LU 0 Low Uncontrolled 0 0 0 0 0 0 0.1015$ 0.0914$ -$ -$ 0.1025$ 0.0923$ -$ -$
DN-70-H 7 High n/a 228,848 22,656 206,192 373,727 36,999 336,728 0.0865$ 0.0779$ 1,960$ 16,062$ 0.0875$ 0.0788$ 3,237$ 26,534$
DN-70-L 2 Low n/a 127,571 12,630 114,942 202,792 20,076 182,715 0.0865$ 0.0779$ 1,092$ 8,954$ 0.0875$ 0.0788$ 1,757$ 14,398$
DN-150-H 0 High n/a 0 0 0 0 0 0 0.0768$ 0.0691$ -$ -$ 0.0778$ 0.0700$ -$ -$
DN-150-L 3 Low n/a 289,374 28,648 260,726 478,897 47,411 431,486 0.0768$ 0.0691$ 2,200$ 18,016$ 0.0778$ 0.0700$ 3,689$ 30,204$
11,103,031 1,099,201 10,003,828 25,178,790 2,492,700 22,686,093 115,739$ 948,257$ 265,314$ 2,173,748$
Standard contract and low fixed charge (LFC) non time of use (anytime)
Quantity (Q t-2 ) Price (P t )Price (P t-1 ) Allowable Notional Notional Revenue (Q t-
31-Mar-19 31-Mar-2031-Mar-18
pricing
code
PPD not
applied
PPD
applied
Daily
($/day)
Daily
($/day
distributio
n)
Daily
($/day net
of PPD)
PPD not
appliedPPD applied total
Daily
($/day)
Daily
($/day
distributio
n)
Daily
($/day net
of PPD)
PPD not
appliedPPD applied total
M1T 14,930 5,449,450 539,496 4,909,954 0.2667$ 0.1600$ 0.1440$ 86,319$ 707,033$ 793,353$ 0.2667$ 0.1600$ 0.1440$ 86,319$ 707,033$ 793,353$
M3T 5,500 2,007,500 198,743 1,808,758 0.3556$ 0.2134$ 0.1921$ 42,412$ 347,462$ 389,874$ 0.3556$ 0.2134$ 0.1921$ 42,412$ 347,462$ 389,874$
MN 2,740 1,000,100 99,010 901,090 0.2667$ 0.1600$ 0.1440$ 15,842$ 129,757$ 145,599$ 0.2667$ 0.1600$ 0.1440$ 15,842$ 129,757$ 145,599$
23,170 8,457,050 837,248 7,619,802 144,573$ 1,184,253$ 1,328,825$ 144,573$ 1,184,253$ 1,328,825$
Metering fees
31-Mar-18
Quantity (Qt-2) Price (Pt) Notional Revenue (Qt-2×Pt)
31-Mar-20
Price (Pt) Notional Revenue (Qt-2×Pt)
Billed
31-Mar-19
32
Table 22 Dedicated transformer charge
Table 23 Relay fees
Dedicated transformers (No.) Billed PPD not applied PPD applied monthly yearly net of PPD PPD not applied PPD applied total
5 2,800 277 2,523 27.82$ 166.92$ 150.23$ 46,237$ 379,030$ 425,267$
10 1,079 107 972 46.17$ 277.02$ 249.32$ 29,641$ 242,339$ 271,980$
15 1,797 178 1,619 63.24$ 379.44$ 341.50$ 67,540$ 552,889$ 620,429$
30 219 22 197 83.76$ 502.56$ 452.30$ 11,056$ 89,103$ 100,159$
50 196 19 177 92.82$ 556.92$ 501.23$ 10,581$ 88,718$ 99,299$
75 113 11 102 113.25$ 679.50$ 611.55$ 7,475$ 62,378$ 69,853$
100 51 5 46 126.58$ 759.48$ 683.53$ 3,797$ 31,442$ 35,240$
200 14 1 13 218.13$ 1,308.78$ 1,177.90$ 1,309$ 15,313$ 16,621$
300 5 0 5 263.27$ 1,579.62$ 1,421.66$ -$ 7,108$ 7,108$
500 4 0 4 308.25$ 1,849.50$ 1,664.55$ -$ 6,658$ 6,658$
750 1 0 1 370.04$ 2,220.24$ 1,998.22$ -$ 1,998$ 1,998$
1000 0 0 0 417.20$ 2,503.20$ 2,252.88$ -$ -$ -$
Dedicated Transformer Totals 6,279 620 5,659 177,637$ 1,476,977$ 1,654,613$
31-Mar-18
Quantity (Qt-2) Notional Revenue (Qt-2×Pt-1) Notional Revenue (Qt-2×Pt)
Dedicated transformers (No.) Billed monthly yearly net of PPD total monthly yearly net of PPD total
5 0 27.82$ 333.84$ 300.46$ -$ 27.82$ 333.84$ 300.46$ -$
10 0 46.17$ 554.04$ 498.64$ -$ 46.17$ 554.04$ 498.64$ -$
15 5 63.24$ 758.88$ 682.99$ 3,415$ 63.24$ 758.88$ 682.99$ 3,415$
30 9 83.76$ 1,005.12$ 904.61$ 8,141$ 83.76$ 1,005.12$ 904.61$ 8,141$
50 0 92.82$ 1,113.84$ 1,002.46$ -$ 92.82$ 1,113.84$ 1,002.46$ -$
75 0 113.25$ 1,359.00$ 1,223.10$ -$ 113.25$ 1,359.00$ 1,223.10$ -$
100 9 126.58$ 1,518.96$ 1,367.06$ 12,304$ 126.58$ 1,518.96$ 1,367.06$ 12,304$
200 10 218.13$ 2,617.56$ 2,355.80$ 23,558$ 218.13$ 2,617.56$ 2,355.80$ 23,558$
300 6 263.27$ 3,159.24$ 2,843.32$ 17,060$ 263.27$ 3,159.24$ 2,843.32$ 17,060$
500 16 308.25$ 3,699.00$ 3,329.10$ 53,266$ 308.25$ 3,699.00$ 3,329.10$ 53,266$
750 9 370.04$ 4,440.48$ 3,996.43$ 35,968$ 370.04$ 4,440.48$ 3,996.43$ 35,968$
1000 2 417.20$ 5,006.40$ 4,505.76$ 9,012$ 417.20$ 5,006.40$ 4,505.76$ 9,012$
Dedicated Transformer Totals 66 162,723$ 162,723$
Price (Pt-1) Price (Pt)
31-Mar-19 31-Mar-20
Dedicated transformer charge - Major Customers
Dedicated transformer charge - standard connections
30-Sep-17
Quantity (Qt-2) Price (Pt-1)
30-Sep-18
Notional Revenue (Qt-2×Pt-1)
Relay Fees
BilledPPD not
appliedPPD applied monthly yearly
net of
PPD
PPD not
applied
PPD
appliedtotal
Relay fees (No.) 17,363 1,719 15,644 1.83$ 10.98$ 9.88$ 18,875$ 154,563$ 173,437$
Relay fees Totals 17,363 1,719 15,644 18,875$ 154,563$ 173,437$
Notional Revenue (Qt-2×Pt-1)
30-Sep-1830-Sep-17
Quantity (Qt-2) Price (Pt-1)
33
Table 24 Streetlight charges
31-Mar-18
Quantity (Qt-2) Notional Revenue (Qt-2×Pt-1) Notional Revenue (Qt-2×Pt)
gross net PPD gross net PPD
Assets (value) 554,697$ 554,697$
Mounting Service (No.)
Taupo 0 60.48 54.43 -$ 60.48 54.43 -$
Ruapehu 959 63.00 56.70 54,375$ 63.00 56.70 54,375$
Waitomo 553 50.39 45.35 25,079$ 50.39 45.35 25,079$
Otorohanga 313 63.00 56.70 17,747$ 63.00 56.70 17,747$
Network - Streetlights (kW)
Taupo 76.50 119.39 107.45 8,220$ 119.39 107.45 8,220$
Ruapehu 165 70.37 63.33 10,449$ 70.37 63.33 10,449$
Waitomo 111 121.11 109.00 12,099$ 121.11 109.00 12,099$
Otorohanga 65.85 121.11 109.00 7,178$ 121.11 109.00 7,178$
Under Veranda kW 10.67 81.22 73.10 780$ 81.22 73.10 780$
Load Plant Operation (Load Shifting) (No.)
Taupo 1,460 3.14 2.83 4,132$ 3.14 2.83 4,132$
Ruapehu 2,190 3.14 2.83 6,198$ 3.14 2.83 6,198$
Waitomo 1,460 3.14 2.83 4,132$ 3.14 2.83 4,132$
Otorohanga 730 3.14 2.83 2,066$ 3.14 2.83 2,066$
Private light residual 400 3.85 3.47 1,388$ 3.85 3.47 1,388$
Streetlight Charges Total 708,540$ 708,540$
Streetlight charges
31-Mar-19
Price (Pt-1) Price (Pt)
31-Mar-20
34
Table 25 De-energisation and re-energisation
31-Mar-18
Quantity (Qt-2) Price (Pt-1)
Notional Revenue
(Qt-2×Pt-1) Price (Pt)
Notional Revenue
(Qt-2×Pt)
1. Job request by 2:00 pm and executed next working day by 4:30 pm
1A Urban 490 46.58 22,824$ 46.58 22,824$
1B Rural 219 58.22 12,750$ 58.22 12,750$
1C Remote 107 174.66 18,689$ 174.66 18,689$
1D Special 209 60.00 12,540$ 60.00 12,540$
2. Job request after 2:00 pm executed next working day by 4:30 pm
2A Urban 214 52.40 11,214$ 52.40 11,214$
2B Rural 65 64.05 4,163$ 64.05 4,163$
2C Remote 56 203.77 11,411$ 203.77 11,411$
3. Job request for same working day before 3:00 pm and executed that day
3A Urban 262 69.86 18,303$ 69.86 18,303$
3B Rural 79 81.51 6,439$ 81.51 6,439$
3C Remote 40 261.99 10,480$ 261.99 10,480$
4. Re-energisation request only. From 3:00 pm onwards on any given
weekday, weekend or public holiday before 10:00 pm.
4A Urban 114 116.44 13,274$ 116.44 13,274$
4B Rural 38 174.66 6,637$ 174.66 6,637$
4C Remote 15 349.31 5,240$ 349.31 5,240$
5. Re-energisation request only. After 10:00 pm on any given day including
public holidays.
5A Urban 0 232.88 -$ 232.88 -$
5B Rural 0 291.09 -$ 291.09 -$
5C Remote 0 523.97 -$ 523.97 -$
7. Applies if request 1(a,b,c) is cancelled between 2:00 - 4:00 pm on day prior
to scheduled action. If cancellation after 4:00 pm then full charge applies.
7A Urban 32 36.23 1,159$ 36.23 1,159$
7B Rural 0 47.87 -$ 47.87 -$
7C Remote 0 164.31 -$ 164.31 -$
De-Energisation and Re-Energisation Totals 1,940 155,123$ 155,123$
De-energisation and re-energisation
31-Mar-2031-Mar-19
35
Table 26 Summary pass-through and recoverable revenue and costs 2020
Pass-through and Recoverable Revenue
Standard Customers TOU 4,505,530$
Major Customers 2,041,403$
Generation 44,593$
Streetlights 31,120$
Total Pass-through and Recoverable Revenue 6,622,646$
Pass-through and Recoverable Costs
Recoverable Costs
Transpower for electricity lines services 5,228,777-$
Transpower new investment contract 2,346,531-$
Transpower new investment contract wash-up 67,847-$
Distributed generation allowance 1,642,953-$
Quality incentive adjustment 390,608$
Capex wash-up adjustment 308,654$
Total Recoverable Costs 8,586,846-$
Pass-through Costs
Rates on system fixed assets 340,278-$
Commerce Act levies 92,163-$
Electricity Authority levies 67,357-$
Utilities Disputes levies 26,736-$
Total Pass-through Costs 526,533-$
Total Pass-through and Recoverable Costs 9,113,379-$
Total Pass-through and Recoverable Revenue Less
Total Pass-through and Recoverable Costs -$ 2,490,733
Summary Pass-through and Recoverable Revenue and Costs 2020
36
Table 27 Pass-through and recoverable revenue
Revenue (Qt×Pt)
Standard User and Low Fixed Charge (LFC) Plan Pass-through
and Recoverable Revenue (kW) Billed
PPD not
applied PPD applied monthly net of PPD
Peak 50,979,672 6,525,398 44,454,274 0.0600$ 0.0540$ 2,792,055$
Shoulder 98,295,126 12,581,776 85,713,350 0.0098$ 0.0088$ 877,579$
Off Peak 49,137,173 6,289,558 42,847,615 0.0098$ 0.0088$ 438,697$
Anytime 6,824,263 873,506 5,950,758 0.0239$ 0.0215$ 148,818$
Anytime 11,887,438 1,521,592 10,365,846 0.0229$ 0.0206$ 248,381$
Standard/LFC Pass-through and Recoverable Revenue Total 217,123,672 27,791,830 189,331,843 4,505,530$
Quantity (Qt) Revenue (Qt×Pt)
Major Customer Pass-through and Recoverable Revenue Billed monthly net of PPD
Transmission Connection (kVA)
Hangatiki 28,323 8.30$ 7.47$ 211,570$
National Park 3,478 42.38$ 38.14$ 132,647$
Ohakune 2,500 19.31$ 17.38$ 43,454$
Ongarue 1,330 24.70$ 22.23$ 29,574$
Tokaanu 889 8.73$ 7.86$ 6,988$
Whakamaru 0 -$ -$ -$
Transmission Connection Totals 36,520 424,233$
Transmission Co-Incidental Demand (RCPD) (kVA)
Regional Coincident Peak Demand (RCPD) 14,785 121.53$ 109.38$ 1,617,170$
Transmission Co-incidental demand (RCPD) Totals 14,785 1,617,170$
Major Customer Pass-through and Recoverable Revenue Total 2,041,403$
Generators
Transpower Injection
Ongarue 1 35,674$ 35,674$
Tokaanu 1 8,919$ 8,919$
Generation Total 44,593$
Streetlights
Transmission Demand kW
Taupo 76.50 45.80$ 41.22$ 3,153$
Ruapehu 165 66.74$ 60.06$ 9,910$
Waitomo 111 56.67$ 51.00$ 5,661$
Otorohanga 65.85 56.67$ 51.00$ 3,359$
Under Veranda kW 10.67 77.92$ 70.13$ 748$
Transmission Connection kW
Taupo 76.50 33.71$ 30.34$ 2,321$
Ruapehu 165 14.78$ 13.30$ 2,195$
Waitomo 111 23.70$ 21.33$ 2,368$
Otorohanga 65.85 23.70$ 21.33$ 1,405$
Streetlights Total 31,120$
Pass-through and Recoverable Revenue Total 6,622,646$
Price (Pt)
Pass-through and recoverable revenue
Price (Pt)Quantity (Qt)
31-Mar-20
37
Appendix D Transmission Assets, Transactions and Restructuring of
Prices (Clauses 11.2(d) and 11.6 – 11.8)
Clauses 11.2(d)(i), 11.7 and 11.8 – TLC did undertake a Restructure of its Prices that first applied
during the current or preceding Assessment Period and therefore clauses 8.7 - 8.10 did apply
during the Assessment Period. This Appendix discusses the restructures that occurred and the
methodologies that have been applied.
Introduction
TLC changed business rules for measuring kW load quantities between the 2019 Assessment
Period (t-1) and the 2018 Assessment Period (t-2). TLC has considered and sought advice from
both the Commerce Commission and external industry experts of the approaches being applied
to demonstrate compliance with the 2020 default price-quality price path concerning the business
rule adjustments that led to price restructures.
Background
TLC’s previous Pricing Methodology (a version of demand charging) differed in material aspects to
other approaches within the industry. To support the methodology, TLC changed metering stock
from legacy/standard meters to Time-of-Use (TOU)/Advanced meters (half hour and ten-minute
intervals). Where these changes lead to price restructures, TLC has applied methodologies to
determine demonstrably reasonable estimates of quantities that practicably correspond to each
restructured price.
TLC has identified three changes to business rules that fall under the price restructure provisions
of the DPP Determination. This is a continuation of the price restructures impacting kW
measurements which were identified in the RY2019 annual compliance statement. The numbering
below is consistent with the RY2019 annual compliance statement. Pricing restructures 3 and 4
are not included below, as they do not apply for this Assessment Period.
Price restructures
Price restructure 1: kW load measured using a standard meter (t-2) and TOU half-hour
interval meter (t-1)
This change in business rules (associated with the meter change) is a price restructure because
the change reflects a reallocation of connections between consumer groups, where a consumer
group is defined with reference to different metering types within a pricing class where those
metering types influence how kW quantities are measured. In year t-2 each consumer was charged
on the basis of a profile while in year t-1, each consumer was charged on the basis of their TOU
half-hour interval meter data. The meter change has therefore reallocated connections between
consumer categories for the purpose of setting prices.
We note that these consumers were not subject to the opt back (to a profile) process because they
received a lower quantity and lower total charge from the TOU measurement.
TOU-based kW load data is not available for t-2 (as TOU half-hour interval meters had not been
installed at that time). Therefore, it was necessary to estimate Quantities in t-2 that correspond to
the restructured price. The methodology used for determining these estimated quantities was to
calculate, for each individual connection, the percentage difference between the TOU and profile
38
quantities for year t-2 and year t-1 and apply that percentage difference to the profile quantities
for each individual connection for year t-2 (as profile Quantities are available for these consumers
in year t-2).
TLC considers that this is the most demonstrably reasonable estimate of the t-2 quantities that
correspond to the t-1 prices.
The table in Appendix C – Price and Quantity Schedules, Standard User and Low Fixed Charge (LFC)
Plan kW Load Charge, details the impact of the price restructure and a summary is presented in
the table below. This summary shows the difference from the billed quantities in t-2 to the
estimates of quantities for t-2 which best correspond to prices in year t-1.
Charge Billed
Quantities t-
2 (2018)
Price
Restructure
1
Quantity post-
Price
Restructure 1
Allowable
Notional
Revenue Billed
Quantities
Allowable
Notional
Revenue Price
Restructure 1
Allowable
Notional Revenue
post-Price
Restructure 1
kW load
variable
73,091 -168 72,923 $8,629,105 -$19,968 8,609,138
Table 28 Price restructure 1 – Allowable Notional Revenue (t-2) quantities × (t-1) prices
Price restructure 2: kW measured using TOU half-hour interval meter (t-2) and demand ten-
minute interval meter (t-1)
This restructure of prices applies to consumers where their quantities in year t-2 were determined
from half-hour interval data and were determined from ten-minute interval data in year t-1. This
reflects the metering types that were in place in these years – half-hour TOU meters in t-2 and ten-
minute interval meters in t-1. Ten-minute interval data was not available in t-2 as the relevant
meters with the required firmware were not in place. As such, this change in business rules is a
price restructure because it reflects a reallocation of connections between consumer groups,
where a consumer group is defined with reference to different metering types within a pricing
class, where those metering types influence how kW quantities are measured.
The methodology for determining the Quantities that apply to the restructured price is applying
the aggregate percentage difference from t-2 and t-1 between TOU half-hour and ten-minute
interval data to the billed quantities from t-2.
Charge Billed
Quantities t-
2 (2018)
Price
Restructure
2
Quantity post-
Price
Restructure 2
Allowable
Notional
Revenue Billed
Quantities
Allowable
Notional
Revenue Price
Restructure 2
Allowable
Notional Revenue
post-Price
Restructure 2
kW load
variable
73,091 269 73,360 $8,629,105 $31,644 $8,660,749
Table 29 Price restructure 2 – Allowable Notional Revenue (t-2) quantities × (t-1) prices
Price restructure 5: kW load measured using standard meter (t-2) and TOU ten-minute
interval meter (t-1)
This change in business rules is a price restructure because the change reflects a reallocation of
connections between consumer groups, where a consumer group is defined with reference to
different metering types within a pricing class where those metering types influence how kW
quantities are measured. In t-2 each consumer was charged on the basis of a profile while in t-1,
each consumer was charged on the basis of their TOU ten-minute interval data. The meter change
39
has therefore reallocated connections between consumer categories for the purpose of setting
prices.
We note that these consumers were not subject to the opt back (to a profile) process because they
received a lower quantity and lower total charge from the TOU measurement.
TOU-based kW load data is not available for t-2 (as TOU ten-minute interval meters had not been
installed at that time). Therefore, it was necessary to estimate Quantities in t-2 that correspond to
the restructured price. The methodology used for determining these estimated quantities was to
calculate, for each individual connection, the percentage difference between the TOU and profile
quantities for t-2 and t-1 and apply that percentage difference to the profile quantities for each
individual connection for year t-2 (as profile Quantities are available for these consumers in year
t-2).
TLC considers that this is the most demonstrably reasonable estimate of the t-2 quantities that
correspond to the t-1 prices.
The table in Appendix C – Price and Quantity Schedules, Standard User and Low Fixed Charge (LFC)
Plan kW Load Charge, details the impact of the price restructure and a summary is presented in
the table below. This summary shows the difference from the billed quantities in t-2 to the
estimates of quantities for t-2 which best correspond to prices in year t-1.
Charge Billed
Quantities t-
2 (2018)
Price
Restructure
5
Quantity post-
Price
Restructure 5
Allowable
Notional
Revenue Billed
Quantities
Allowable
Notional
Revenue Price
Restructure 5
Allowable
Notional Revenue
post-Price
Restructure 5
kW load
variable
73,091 kW -1,121 kW 71,970 kW $8,629,105 -$135,707 $8,493,399
Table 30 Price restructure 5 – Allowable Notional Revenue (t-2) quantities × (t-1) prices
Summary of price restructures
Price
restructure
Charge Billed
Quantities
t-2 (2018)
Price
Restructure
Quantity
post-Price
Restructure
Allowable
Notional
Revenue
Billed
Quantities
Allowable
Notional
Revenue
Price
Restructure
Allowable
Notional
Revenue
post-Price
Restructure
1
kW load
variable 73,091
-168 kW 72,923 kW
$8,629,105
-$19,968 $8,609,138
2 269 kW 73,360 kW $31,644 $8,660,749
5 -1,121 kW 71,970 kW -$135,707 $8,493,399
Totals: -1,020 kW 72,071 kW -$124,031 $8,505,075
Table 31 Summary of price restructures – Allowable Notional Revenue (t-2) quantities × (t-1) prices
Reconciliation to Price-Quantity Schedules
Standard User and Low Fixed Charge (LFC) Plan kW Load Charge
Billed Q t-2 Price restructure 1 Price restructure 2 Price restructure 5 Post-price restructures
Q t-1 ANR 73,091 -168 kW 269 kW -1,121 kW 72,071 kW
$ t-1 ANR $8,629,105 -$19,968 $31,644 -$135,707 $8,505,075
Table 32 – Reconciliation of price restructures – Allowable Notional Revenue (t-2) quantities × (t-1) prices
Clause 11.2(d)(ii) – TLC did not receive a transfer of transmission assets from Transpower that
became system fixed assets or transferred system fixed assets to Transpower.
40
Clauses 11.2(d)(iii)-(iv) and 11.6 – TLC did not participate in an Amalgamation, a Merger or Major
Transaction for the Assessment Period. Clauses 10.1 – 10.4, therefore, did not apply for the
Assessment Period.
41
Appendix E Quality Standard Compliance and Incentive (Clause 11.5(c),
(d) and (f))
Quality Standard Compliance Calculations
Table 33 Quality Standard Compliance Calculations
SAIDI and SAIFI Limits
234.182
3.467
10.967
0.144
SAIDI Assessed Values
Raw data Adjusted data
SAIDI B Planned SAIDI 67.490 SAIDI B
Planned SAIDI
multiplied by 0.5 33.745
SAIDI C Unplanned SAIDI 265.441 SAIDI C
Normalised
unplanned SAIDI 237.678
271.423
SAIFI Assessed Values
Raw data Adjusted data
SAIFI B Planned SAIFI 0.393 SAIFI B
Planned SAIFI
multiplied by 0.5 0.197
SAIFI C Unplanned SAIFI 2.804 SAIFI C
Normalised
unplanned SAIFI 2.804
3.001
Days exceeding SAIDI Boundary Value within the 2019/20 Assessment Dataset
DateNormalised
unplanned SAIDI
1-Oct-19 10.967
18-Dec-19 10.967
Prior Period Assessed Values
Assessed SAIDI Value 2018/19
285.548
31 March 2019 Normalised Assessment Dataset
Assessed SAIFI Value 2018/19
4.406
31 March 2019 Normalised Assessment Dataset
Assessed SAIDI Value 2017/18
243.335
31 March 2018 Normalised Assessment Dataset
Assessed SAIFI Value 2017/18
3.747
31 March 2018 Normalised Assessment Dataset
Reliability Limits and Boundary Values
Reliability Assessment Calculations (2020 Assessment Period)
SAIDI Limit 2015-2020 regulatory period
SAIFI Limit 2015-2020 regulatory period
SAIDI Unplanned Boundary Value 2015-2020 regulatory period
SAIFI Unplanned Boundary Value 2015-2020 regulatory period
The sum of daily SAIDI Values in the 1 April 2017 -
The sum of daily SAIFI Values in the 1 April 2017 -
SAIFI Assess (B+C)
SAIDI Assess (B+C)
SAIFI2018/19
The sum of daily SAIDI Values in the 1 April 2018 -
The sum of daily SAIFI Values in the 1 April 2018 -
Normalisation
Pre-Normalised
unplanned SAIDI
35.850
13.850
SAIDI2017/18
SAIFI2017/18
SAIDI2018/19
42
Quality Incentive Calculations
Table 34 Quality Incentive Calculations
Value $
(173,525)
30,761
(142,764)
Value
208.7747
SAIDI Collar 183.3679
234.1815
$34,705,000
$173,525
SAIDI IR $6,830
SAIDI ASSESS 234.182
($173,525)
Value
3.0707
SAIFI Collar 2.6748
3.4667
$34,705,000
$173,525
SAIFI IR $438,194
SAIFI ASSESS 3.001
$30,761
Value $
(173,525)
(173,525)
(347,050)
(390,608)
Value $
(173,525)
(173,525)
(347,050)
(390,608)Recoverable cost 2019/20 S TOTAL 2017/18 adjusted for the time value of money
Term Description
S SAIDI 2017/18 SAIDI incentive 2017/18
S SAIFI 2017/18 SAIFI incentive 2017/18
Recoverable cost 2020/21 S TOTAL 2018/19 adjusted for the time value of money
Quality Incentive Adjustment
2018 Assessment Period
S TOTAL 2017/18 SAIDI incentive plus SAIFI incentive 2017/18
S SAIDI 2018/19 SAIDI incentive 2018/19
S SAIFI 2018/19 SAIFI incentive 2018/19
S TOTAL 2018/19 SAIDI incentive plus SAIFI incentive 2018/19
Quality Incentive Adjustment
Term Description
2019 Assessment Period
Prior Period Quality Incentive Adjustments
0.5 * REV RISK
Maximum allowable revenue for the 2015/16 year
Revenue at risk relating to SAIDI target (equal to 0.5% of MAR)
Starting price MAR
S SAIDI SAIDI incentive
S TOTAL SAIDI incentive plus SAIFI incentive
Quality Incentive Adjustment (2020 Assessment Period)
Starting price MAR Maximum allowable revenue for the 2015/16 year
S SAIFI SAIFI incentive
SAIDI Target
SAIDI Cap
SAIDI target specified in DPP Determination
SAIDI incentive range collar specified in DPP Determination
SAIDI incentive range cap specified in DPP Determination
S SAIDISAIDI incentive adjustment (equal to incentive rate multiplied by SAIDI target
minus Assessed SAIDI value)
Assessed SAIDI value for purpose of incentive
SAIDI incentive rate per unit (equal to revenue at risk divided by Cap minus
Target)
DescriptionTerm
SAIDI Incentive
0.5 * REV RISK Revenue at risk relating to SAIFI target (equal to 0.5% of MAR)
SAIFI incentive rate per unit (equal to revenue at risk divided by Cap minus
Target)
S SAIFISAIFI incentive adjustment (equal to incentive rate multiplied by SAIFI target
minus Assessed SAIFI value)
Assessed SAIFI value for purpose of incentive
SAIFI Cap
SAIFI target specified in DPP Determination
SAIFI incentive range collar specified in DPP Determination
SAIFI incentive range cap specified in DPP Determination
Quality Incentive Adjustment
Term Description
SAIFI Incentive
Term Description
SAIFI Target
43
Major Event Days (MED)
There were two major event days (MED) in RY2020. The cause of each Major Event Day within the
Assessment Period (clause 11.5(f)) is detailed below:
SAIDI
1. 1 October 2019
This MED was a result of car vs pole on the Turangi 33kV feeder and impacted over 2,000
customers initially, 1,500 customers were restored using backup supplies from adjacent
substations, however, 500 customers remained without power for the 11.5-hour repair time.
As noted above and in our 2019 and 2020 Asset Management Plans, security of supply for the
Turangi substation is a key point of focus with an upgrade recently completed increasing
backup capability. A full N-1 backup for Turangi will be commissioned in 2021.
Other risk mitigation works are underway including the physical separation of two key 33kV
feeders to the region, minimising the chance of a single-vehicle accident impacting both. An
investigation into protective barriers around poles has also been completed with these being
cost-prohibitive to effectively mitigate the risk of all roadside exposure.
2. 18 December 2019
Ten outages, contributing a total of 13.85 SAIDI minutes were experienced on 18 December
2019. One outage contributed 10.86 SAIDI minutes. This is the outage noted above and was a
result of forestry plantation trees, outside of the growth limited zone, falling and severely
damaging an 11kV line that has no backfeed options.
A helicopter was deployed to identify the location of the fault per our operating protocol at the
time, and once identified a generator was deployed to restore supply to affected customers.
Removal of the fallen trees required specialist support from the forestry company.
The remaining nine outages contributed 2.98 SAIDI minutes, with a combination of weather-
related vegetation and defective equipment outages.
44
Appendix F Policies and Procedures for Recording SAIDI and SAIFI
(Clause 11.5(e))
The following notes document the procedures used to capture all outages experienced on TLC’s
network and interconnected private networks.
TLC uses a SQL database called BASIX to capture all outages. BASIX has the inter-connectivity of all
equipment on the TLC Network and interconnected private networks programmed into its
Connectivity Model. The 33/11 kV connectivity model is updated by the Network Control Team
when any changes on the TLC Network are made. TLC customer ICP’s are updated by the Customer
Experience Team via CIS software and routinely uploaded in the BASIX Connectivity Model. The
operation of any network equipment is recorded into BASIX, which then calculates and returns an
outage result.
The Network Control Team manages outages and incidents on the network, identifying causes
and outage types. Information gathered is used to update the TLC Daily Control Room Log
spreadsheet. The TLC Engineering team are notified should a major outage or fault requiring
further investigation occur.
The TLC Daily Control Room Log data is obtained from the following:
• The primary source for unplanned outages on automated equipment are reports from the
network Abbey SCADA system.
• The primary source of unplanned outages on non-automated equipment is customer calls
received by the Lines Company Faults Team. Each call is entered directly into BASIX and
automatically allocated a unique number by the BASIX System. The Faults Team dispatches
the outage details to a Faultman to address. All information received from the Faultman is
then updated in BASIX against the same unique number, and the Basix restored time checked
(if applicable).
• Planned Outage applications are subject to approval from the Network Control Team. Each
application is assigned a unique reference, identifying both the request and whom it was
submitted by.
All information captured into the TLC Daily Control Room Log is checked and validated by the
Network Control Team. A spreadsheet is then used to create a Daily Outage Summary which
estimates the effect of the outages before recording in Basix. Supporting documentation in the
form of daily SCADA Auto Recloser printouts, Switching Schedules for planned outages,
Applications to Work on TLC Network and associated documents and Permits issued, along with
the Daily Outage Summary, are scanned as a PDF and electronically filed for each day.
The Network Control Team is then responsible for recording the relevant Daily Control Room Log
details for each outage into BASIX, which allocates a unique sequential tracking number to each
record. The following information is captured in Basix:
• Description of Outage
• Date and Time of Interruption
• Date and Time of Restoration
• Operated Asset
• BASIX Fault Reference (if applicable)
• Outage Type
45
• Primary Cause
• Cause Description
• Switching Operations of all operated equipment
• Any other notes or comments significant to the outage.
The daily PDF of scanned supporting documentation is also linked into BASIX against the record
for the first outage recorded each day.
Once entered into BASIX, the outage is then calculated using the connectivity model data to return
the following details:
• outage minutes
• number of consumers affected
• customer minutes
• affected loads
• affected assets
• outage SAIDI
• outage SAIFI
The calculated figures are checked against the spreadsheet estimate to ensure they materially
align with expectations.
BASIX performs overnight runs to consolidate the initial outage calculations into the Daily, Monthly
and Year-to-date reports.
The BASIX report data is monitored by the Asset Engineer and reviewed by The Lines Company
Management Team. It is included in Network Overview documents and forwarded to the Board of
Directors.
The outage data is audited by an external auditing company before being publicly disclosed to
comply with Commerce Commission DPP requirements.
46
Primary Source for Automated
Equipment on TLC Network -
Outages Reported by SCADA
Daily TLC Control Room Log
Updated as Events are Handled
(Updated Live) in the Control
Room
Create Daily TLC Outage Summary
Spreadsheet - Used to Estimate
Impact of Outages Before Being
Entered into BASIX
Capture All Outages on TLC
Network including Private Line
Faults effecting TLC Network into
BASIX
Public Disclosure and to
Commerce Commission
Major Faults and Outages
Reported to Engineering Team for
Further Investigation and
Rectification
Primary Source for Non
Automated Equipment on TLC
Network- Customer Reports of
Outages Captured on BASIX by
Faults Team
Planned / Unplanned Outages on
TLC Network
Outages for Planned Work on TLC
Network by TLC Contractors
TLC Network Control - Manage
Outage Incidents - Identify Outage
Type and Causes
Check BASIX Calculations against -
Daily TLC Outage Summary
Spreadsheet
Asset Engineer Validates Monthly
SAIDI / SAIFI Performance Report -
Uses Data to Create Annual SAIDI
/SAIFI Performance Report
Monthly SAIDI /SAIFI
Performance Report
Reviewed by TLC
Management Team
Annual SAIDI /SAIFI Performance
Report Reviewed by TLC
Management Team
TLC Board of Directors
Review the Monthly and
Annual SAIDI /SAIFI
Performance Reports
Annual Report is Audited
by External Auditing
Company
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