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[Non-Text]
الهييه السعوديه لتنظيم الكهرباء
Saudi Electricity Regulatory Authority
SERA
Transmission Use
of System Charging
Methodology
الهييه السعوديه لتحريم الكهرباء
Saudi Electricity Regulatory Authority
SERA
مرحبه هذه الوثيقه
في حال وجود اي استفسارات او ملاحظات فان المرجع فيها الي الاداره العامه للشؤون
الاقتصاديه والتعريفه
economic@sera.gov.sa : البريد الالكتروني
00966112019000: هاتف:
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جدول ضبط النسخ
November 2022
Transmission Use of System Charging
Methodology
حقوق النسخ والنشر محفوظه للهييه السعوديه لتنظيم الكهرباء
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Transmission Use of System Charging Methodology
[Non-Text]
هييه السعوديه لتحريه الكريه
Saudi Electricity Regulatory Authority
SERA
Table of Content
<table><tr><td>No</td><td>Title</td><td>Page No</td></tr><tr><td>1</td><td>Introduction</td><td>4</td></tr><tr><td>2</td><td>Costs to be Recovered</td><td>5</td></tr><tr><td>3</td><td>Responsibility for Paying TUoS Charge</td><td>6</td></tr><tr><td>4</td><td>Calculating TUoS Charge</td><td>7</td></tr><tr><td></td><td>4.1 Methods for Computing the Maximum Demand on which Users Pay TUoS Charges</td><td>7</td></tr><tr><td></td><td>4.2 Determining the TUoS Charge</td><td>11</td></tr><tr><td></td><td>4.3 TUoS Payments</td><td>12</td></tr><tr><td></td><td>4.4 Summary of Setting the TUoS Charge</td><td>12</td></tr><tr><td>5</td><td>Energy Wheeling and Balancing</td><td>12</td></tr><tr><td></td><td>Annex A: TUoS Charge Schedule</td><td>15</td></tr><tr><td></td><td>Annex B: Glossary and Abbreviations</td><td>16</td></tr></table>
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Transmission Use of System Charging Methodology
[Non-Text]
الهييه السعوديه للطريق الكهرباء
Saudi Electricity Regulatory Authority
Saudi Electricity Regulatory Authority
SERA
List of Figures
<table><tr><td>No</td><td>Title</td><td>Page No</td></tr><tr><td>1</td><td>Figure 1: Illustration of Methodology to Set the TUoS Charge</td><td>13</td></tr><tr><td>2</td><td>Figure 2: Illustration of Process for Setting TUoS payments and the Key Deadlines</td><td>14</td></tr></table>
List of Tables
<table><tr><td>No</td><td>Title</td><td>Page No</td></tr><tr><td>1</td><td>Table 1: Illustration of Identifying the Hours that Define Maximum Demand</td><td>8</td></tr><tr><td>2</td><td>Table 2: Illustration of Calculating Maximum Demand</td><td>8</td></tr><tr><td>3</td><td>Table 3: Illustration of Identifying the Hours that Define the Surcharge where Net Demand Exceeds Notified Net Demand for 2 hours</td><td>10</td></tr><tr><td>4</td><td>Table 4: Illustration of Identifying the Hours that Define the Surcharge where Net Demand Exceeds Notified Net Demand for 2 hours</td><td>11</td></tr><tr><td>5</td><td>Table 5: Required Format for the Schedule of TUoS Charge</td><td>15</td></tr></table>
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Transmission Use of System Charging Methodology
العربيه السعوديه لتحطيم الكريه
Saudi Electricity Regulatory Authority
SERA
1. Introduction
The Transmission Use of System (TUoS) Charge is an annual regulated charge to recover the costs associated with the transmission network owned and operated by National Grid Saudi Arabia (NG). The TUoS Charge is also set to signal to users how the costs associated with changes to users' decisions to take electricity from the transmission system affect NG's costs of providing and maintaining a reliable transmission grid.
This document describes the TUoS charging methodology, setting out the costs that the TUoS Charge is intended to recover, the responsibility for paying TUoS Charge, the way the TUoS Charge is calculated, and the process for setting TUoS Charge.
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Transmission Use of System Charging Methodology
العربيه سعوديه لتحطيم الكريه
Saudi Electricity Regulatory Authority
SERA
2. Costs to be Recovered
The Allowed Revenue (AR) for NG is determined by Saudi Electricity Regulatory Authority (SERA) in Saudi Arabian Riyals (SAR) per year. The AR for NG is set to recover the costs of the transmission system including the System Services procurement costs. The details for determining the AR are described in the Transmission Revenue Requirement Determination Methodology document. NG recovers its AR by recovering the TUoS Charge on users' demands for electricity at Connection Points to the transmission system.
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Transmission Use of System Charging Methodology
العربيه السعوديه لتحطيم الكريه
Saudi Electricity Regulatory Authority
SERA
3. Responsibility for Paying TUoS Charge
The following users will be responsible for paying the TUoS Charge, based on their share of demands for electricity at each Connection Point to the transmission system owned by NG, expressed in kilowatt-hours per hour, defined by each user's Maximum Demand in accordance with the provisions set out in Section 4:
1. All retail companies.
2. All transmission-connected customers with captive generation, and their other sites (if any) that benefit from wheeling energy through the transmission system, as described in section 5.
4. Calculating TUoS Charge
4-1 Methods for Computing the Maximum Demand on which Users Pay TUoS Charges
4.1.1 Default Method - Gross demand
NG shall levy the TUoS Charge according to the Maximum Demand for electricity at each Connection Point to the transmission system. A Connection Point is a point on the transmission system at which electricity is supplied to a customer with a direct connection to the transmission system or supplied to a user which is licensed to supply electricity to its customers.
The Maximum Demand for a user at a particular Connection Point to the transmission system will be calculated in kilowatt-hours per hour based on the three hours of the year (i.e. using a “triad” method) in which that user’s Gross Demand at that Connection Point is highest, subject to those three hours being separated by at least 168 hours (i.e. seven days) from each other. More specifically, the Maximum Demand for a user at a particular Connection Point to the transmission system will be calculated as the average of that user’s Gross Demand in those three hours of the year. Hence, the Maximum Demand of the user will be determined on an ‘ex post’ basis.
The rationale for allowing the time of Maximum Demand to vary across Connection Points is that the peak requirement for transmission capacity does not necessarily coincide with the single hour when demand across the system as a whole is highest. Instead, the main determinant of transmission system capacity is the ability to serve all users' peak demands for electricity at a particular Connection Point. Therefore, defining each users' liability to pay the TUoS Charge based on their highest demand at a particular Connection Point better reflects the costs that those users' demands impose on the transmission system.
Table 1 and Table 2 below illustrate the process of identifying Maximum Demand for a particular user at a particular Connection Point. Table 1 ranks a particular user's Gross Demand at a particular Connection Point across all hours of the year. The first hour of Gross Demand that feeds into the Maximum Demand calculation is the peak in Gross Demand at the Connection Point (31,403 kilowatt-hours per hour in the example). However, the 2nd and 3rd ranked hours of Gross Demand are excluded, as these hours are within 168 hours from the peak hour. The 4th ranked hour of Gross Demand is included in the Maximum Demand calculation, as it is more than 168 hours from the peak hour. Next, the 5th through to the 10th ranked hours of Gross Demand (inclusively) are excluded as these hours all occur within 168 hours from either the 1st or 4th ranked hours of Gross Demand. The final ranked hour of Gross Demand included in the definition of Maximum Demand is the 11th ranked hour, as it is more than 168 hours from the peak hour and the 4th ranked hour. Table
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Transmission Use of System Charging Methodology
[Non-Text]
الهييه السعوديه للطريق الكهرباء
Saudi Electricity Regulatory Authority
SERA
2 shows that the average of the demand in these three ranked hours (1st, 4th and 11th) defines the Maximum Demand.
Table 1: Illustration of Identifying the Hours that Define Maximum Demand
<table><tr><td>Rank</td><td>Demand (kWh/h)</td><td>Date / Time</td><td>Hours Highest Demand Hour</td><td>Since</td><td>Hours Highest</td><td>Since</td><td>2nd Demand</td></tr><tr><td>1</td><td>31,404</td><td>22/08/2017 14:00</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>2</td><td>31,247</td><td>22/08/2017 13:00</td><td>-1</td><td></td><td></td><td></td><td></td></tr><tr><td>3</td><td>31,236</td><td>21/08/2017 13:00</td><td>-25</td><td></td><td></td><td></td><td></td></tr><tr><td>4</td><td>31,215</td><td>15/08/2017 14:00</td><td>-168</td><td></td><td></td><td></td><td></td></tr><tr><td>5</td><td>31,162</td><td>23/08/2017 13:00</td><td>23</td><td></td><td>191</td><td></td><td></td></tr><tr><td>6</td><td>31,130</td><td>20/08/2017 14:00</td><td>-48</td><td></td><td>120</td><td></td><td></td></tr><tr><td>7</td><td>31,121</td><td>23/08/2017 14:00</td><td>24</td><td></td><td>192</td><td></td><td></td></tr><tr><td>8</td><td>31,044</td><td>21/08/2017 14:00</td><td>-24</td><td></td><td>144</td><td></td><td></td></tr><tr><td>9</td><td>30,024</td><td>20/08/2017 13:00</td><td>-49</td><td></td><td>119</td><td></td><td></td></tr><tr><td>10</td><td>29,806</td><td>22/08/2017 12:00</td><td>-2</td><td></td><td>166</td><td></td><td></td></tr><tr><td>11</td><td>29,787</td><td>06/08/2017 13:00</td><td>-385</td><td></td><td>-217</td><td></td><td></td></tr></table>
Table 2: Illustration of Calculating Maximum Demand
<table><tr><td></td><td>Demand (kWh/h)</td></tr><tr><td>Highest Demand Hour</td><td>31,404</td></tr><tr><td>2nd Highest Demand Hour</td><td>31,215</td></tr><tr><td>3rd Highest Demand Hour</td><td>29,787</td></tr><tr><td>Maximum Demand (as per triad method)</td><td>30,802</td></tr></table>
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Transmission Use of System Charging Methodology
الهييه السعوديه لتحطيم الكريه
Saudi Electricity Regulatory Authority
SERA
For the purpose of this calculation, the Gross Demand of the user shall be the metered volume (in kilowatt-hours per hour) at the Connection Point that is attributed to that user during the relevant hour \( ^{1} \) , plus the metered on-site generation located within the user's site served by that Connection Point during the relevant hour.
In cases where the user's demand is fed from multiple Connection Points to the transmission system, the Maximum Demand of this user shall be determined by the sum of all metered volume (in kilowatt-hours per hour) across these Connection Points as if they were a single Connection Point.
4.1.2 Alternative Method - Net Demand
Alternatively, each user may opt to have its Maximum Demand at a Connection Point to the transmission system determined using a different approach linked to its Net Demand.
A user that opts to have its Maximum Demand at a Connection Point defined with reference to its Net Demand rather than its Gross Demand must provide written notice to NG that it opts to do so, at least 180 calendar days before the start of the year in which the user opts to have its Maximum Demand defined with reference to its Net Demand. A user's Notified Net Demand is its declaration of their Net Demand for the upcoming calendar year. Hence, the Maximum Demand of the user will be determined on an 'ex ante' basis because it is implied by the user's Notified Net Demand. Each user's Notified Net Demand may not be lower than the maximum value of that user's Maximum Metered Volume (in kilowatt-hours per hour) at the Connection Point, calculated on the basis of Net Demand rather than Gross Demand, during the preceding three calendar years using the "triad" method similar to that described in Tables 1 and 2. For the purpose of this calculation, the Net Demand of the user shall be the metered volume (in kilowatt-hours per hour) at the Connection Point that is attributed to that user during the relevant hour.
Users which elect to pay the TUoS Charge on the basis of their Notified Net Demand will be liable to pay a Surcharge if their outturn Maximum Metered Volume exceeds their Notified Net Demand. A user may not know its Maximum Metered Volume, because on-site production varies unpredictably, e.g. because of forced outages. Hence, by how much it declares Notified Net Demand below its Gross Demand will depend on a trade-off between its assessment of the following:
- the surcharge it will pay if Maximum Metered Volume is higher than Notified Net Demand; and
- the saving in TUoS Charge from declaring Notified Net Demand below Gross Demand.
Given this incentive, the surcharge should ideally be linked to the transmission investment process, i.e. to promote efficiency, users should only have an incentive to pay the TUoS Charge on the basis of their Net Demand rather than their Gross Demand when the likelihood of exceeding their Notified Net Demand is sufficiently low that NG would itself ignore the extra demand in the transmission planning process. However, linking this surcharge to the transmission costs caused by users exceeding their Notified Net Demand is difficult in practice.
1 If the energy is injected to the system, will be applied with negative sign.
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Transmission Use of System Charging Methodology
الهييه السعوديه للطيران
Saudi Electricity Regulatory Authority
SERA
Keeping the above issues in mind, SERA has determined the Surcharge (in SAR per kilowatt-hours per hour) will be ten times the TUoS Charge, and shall be payable (for one year) if the user's outturn Maximum Metered Volume exceeds its Notified Net Demand.
If the user's outturn Net Demand exceeds the Notified Net Demand, the Surcharge shall apply to the difference between Notified Net Demand and an unweighted average of the following values:
1. the user's Maximum Metered Volume;
2. the user's Net Demand in the hour when its Net Demand was next-highest, subject to being separated from the hour defined by the user's Maximum Metered Volume (In 1 above) by at least 168 hours and subject to it being more than the user's Notified Net Demand. If it is not more than the user's Notified Net Demand, the user's Notified Net Demand shall be used as this value; and
3. the user's Net Demand in the hour when its Net Demand was next-highest, subject to being separated from the hours defined in 1 and 2 above by at least 168 hours each and subject to it being more than the user's Notified Net Demand. If it is not more than the user's Notified Net Demand, the user's Notified Net Demand shall be used as this value.
This unweighted average value will be treated as a floor value for Net Notified Demand for the three years immediately following the year in which the outturn Net Demand exceeded the Notified Net Demand.
Tables 3 and 4 below illustrate this methodology.
Table 3: Illustration of Identifying the Hours that Define the Surcharge where Net Demand Exceeds Notified Net Demand for 2 hours
Notified Net Demand = 30,000 kWh/h
<table><tr><td>Rank</td><td>Net Demand (kWh/h)</td><td>Date / Time</td><td>Hours Since Hour Demand Hour</td><td>Hours Since 2nd Hour Demand Hour</td></tr><tr><td>1</td><td>31,404</td><td>22/08/2017 14:00</td><td></td><td></td></tr><tr><td>2</td><td>31,247</td><td>22/08/2017 13:00</td><td>-1</td><td></td></tr><tr><td>3</td><td>31,236</td><td>21/08/2017 13:00</td><td>-25</td><td></td></tr><tr><td>4</td><td>31,215</td><td>15/08/2017 14:00</td><td>-168</td><td></td></tr><tr><td>5</td><td>31,162</td><td>23/08/2017 13:00</td><td>23</td><td>191</td></tr><tr><td>6</td><td>31,130</td><td>20/08/2017 14:00</td><td>-48</td><td>120</td></tr><tr><td>7</td><td>31,121</td><td>23/08/2017 14:00</td><td>24</td><td>192</td></tr><tr><td>8</td><td>31,044</td><td>21/08/2017 14:00</td><td>-24</td><td>144</td></tr><tr><td>9</td><td>30,024</td><td>20/08/2017 13:00</td><td>-49</td><td>119</td></tr><tr><td>10</td><td>29,806</td><td>22/08/2017 12:00</td><td>-2</td><td>166</td></tr><tr><td>11</td><td>29,787</td><td>06/08/2017 13:00</td><td>-385</td><td>-217</td></tr></table>
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Transmission Use of System Charging Methodology
[Non-Text]
الهييه السعوديه لتحريم الكهرباء
Saudi Electricity Regulatory Authority
Saudi Electricity Regulatory Authority
SERA
Table 4: Illustration of Identifying the Hours that Define the Surcharge where Net Demand Exceeds Notified Net Demand for 2 hours
<table><tr><td></td><td>Net Demand (kWh/h)</td></tr><tr><td>Highest Demand Hour</td><td>31,404</td></tr><tr><td>2nd Highest Demand Hour</td><td>31,215</td></tr><tr><td>3rd Highest Demand Hour</td><td>30,000 (deemed by Notified Net Demand)</td></tr><tr><td>Average</td><td>30,873</td></tr><tr><td colspan="2">Excess over Notified Net Demand = (30,873 - 30,000) = 873</td></tr><tr><td colspan="2">Surcharge (SAR) = 873 * 10 * TUoS Charge</td></tr></table>
In cases where the user's demand is fed from multiple Connection Points to the transmission system, the user will be required to declare its Notified Net Demand on aggregate across all such Connection Points. Maximum Demand of this user shall be determined by summing the metered volumes (in kilowatt-hours per hour) across these Connection Points, and any surcharges shall be applied in a way that treats all such Connection Points as if they were a single Connection Point. In all instances where a user's outturn Metered Volume overshoots due to a NG system event or a force majeure event, the Metered Volume will be reset to a value that would have prevailed if such events had not taken place.
Any user that updates its Notified Net Demand must provide written notice to NG, at least 180 calendar days before the start of the year in which the user updates its Notified Net Demand. In case the user opts to increase its Notified Net Demand, the user shall acquire approval from NG to do so, and if NG chose not to accept the user's request, it shall provide its reason in writing to the user.
4-2 Determining the TUoS Charge
The TUoS Charge shall be calculated, in SAR per kilowatt-hours per hour, by dividing NG's AR by:
- The sum of all users' Notified Net Demand in kilowatt-hours per hour across all Connection Points to the transmission system, for those users electing not to pay the TUoS Charge on the basis of their Gross Demand; plus
- The sum of all other users' Gross Demand in kilowatt-hours per hour across all Connection Points to the transmission system, as forecast by NG when setting the TUoS Charge.
NG shall publish the TUoS Charge at least 30 days prior to the start of the calendar year on which it is due to take effect in the format shown in Table 5 in Annex A.
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Transmission Use of System Charging Methodology
العربيه السعوديه لتحطيم الكريه
Saudi Electricity Regulatory Authority
SERA
4-3 TUoS Payments
Each user shall make a TUoS Payment on a monthly basis equal to one-12th of the TUoS Charge, multiplied by the user's Maximum Demand (determined as appropriate by its forecast2 Gross Demand or its Notified Net Demand if the user elects to pay TUoS charge on that basis, as described in Section 4.1). NG shall send invoices to users pertaining to each user's TUoS Payment for any given month within 30 days of months end.
NG shall adjust the TUoS Payment billed to each user in December of each year to ensure that, over the course of the whole year, each user electing to pay the TUoS Charge on the basis of its Gross Demand pays an annual amount based on its actual outturn Maximum Demand. However, if the actual outturn Maximum Demand exceeds the forecast Maximum Demand during the year, NG may adjust the TUoS Payment earlier than December on the basis of the revised outturn Maximum Demand.
For other users electing to pay the TUoS Charge according to their Notified Net Demand, NG shall adjust the TUoS Payment made by each user in December of each year to include any Surcharge that applies as a consequence of a user having an outturn Maximum Metered Volume that exceeds its Notified Net Demand, calculated as set out in Section 4.1.2. However, if the actual outturn Maximum Metered Volume exceeds the Notified Net Demand early in the year, NG will have the right to revise the monthly TUoS charges to reflect the surcharge payable by the user as a consequence. This will help to avoid accumulation of large unbilled dues from the user to NG and smooth the payment schedule.
4-4 Summary of Setting the TUoS Charge
The methodology for setting the TUoS Charge is summarised in Figure 1.
The process for setting the TUoS Charge and the key deadlines are summarised in Figure 2.
5. Energy Wheeling and Balancing
Users in category (2), defined in section (3) above, may use NG's transmission system for wheeling excess energy from their captive generation to their other sites. Those users are liable to pay all associated TUoS charges for each of their sites in the way described above.
The wheeled energy from export sites shall be adjusted for the allowed transmission Loss Factor (LF), which is annually specified by SERA based on the proportion of energy lost in NG's transmission system.
Customers using the transmission system for wheeling, or with embedded generation may spill energy to the grid or draw energy from the grid. The details for remuneration of such cases are described in the Bulk Supply Charging Methodology document.
\( ^{2} \) Forecast gross demand will be based on the historical demand unless it is provided by the users.
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Transmission Use of System Charging Methodology
[Non-Text]
هييه السعوديه لتنظيم الكهرباء
Saudi Electricity Regulatory Authority
SERÁ
Figure 1: Illustration of Methodology to Set the TUoS Charge
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Transmission Use of System Charging Methodology
[Non-Text]
الهييه السعوديه لتحريم الكهرباء
Saudi Electricity Regulatory Authority
SERA
Figure 2: Illustration of Process for Setting TUoS payments and the Key Deadlines
<table><tr><td>Action</td><td>05 - Jul</td><td>01 - Dec</td><td>01 - Jan</td><td>01 - Feb</td><td>01 - Mar</td><td>01 - Apr</td><td>01 - May</td><td>01 - Jun</td><td>01 - Jul</td><td>01 - Aug</td><td>01 - Sep</td><td>01 - Oct</td><td>01 - Nov</td><td>01 - Dec</td></tr><tr><td>Deadline for users to notify NG whether they elect to be charged on a Net or Gross Demand basis</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Deadline for users who elect to pay TUoS Charge on a Net Demand basis to notify NG of their Notified Net Demand</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Deadline fo NG to publish the TUoS Charge for the following year</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>TUoS Charge takes effect</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>NG adjusts TUoS payment to reconcile user payments to actual outturn Maximum Demand</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr></table>
Annex A: TUoS Charge Schedule
Table 5: Required Format for the Schedule of TUoS Charge
SAR per kilowatt-hours per hour of Maximum Demand
TUoS Charge
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Transmission Use of System Charging Methodology
[Non-Text]
هييه سعوديه لتنظيم الكهرباء
Saudi Electricity Regulatory Authority
Saudi Electricity Regulatory Authority
SERA
Annex B: Glossary and Abbreviations
<table><tr><td>Term</td><td>Definition</td></tr><tr><td>TUoS Charge</td><td>The Transmission Network Use of System Charge is an annual fee in SAR per kilowatt-hours per hour that defines the amount payable by users for their use of the transmission system, and to contribute to transmission system costs</td></tr><tr><td>AR</td><td>Allowed Revenue, as determined by SERA to cover NG's costs</td></tr><tr><td>Captive generation</td><td>A power generation facility owned and managed by a transmission-connected customer, and intended primarily to meet the energy requirements of that customer at that site, or to provide back-up capacity.</td></tr><tr><td>SERA</td><td>Saudi Electricity Regulatory Authority</td></tr><tr><td>Connection Point</td><td>Has the meaning given in the Grid Code.</td></tr><tr><td>Force majeure</td><td>Unforeseeable circumstances that are outside the reasonable control of any party that cannot be anticipated or reasonably avoided, it cannot be mitigated if it occurs, and it is not caused by a mistake, negligence, or deliberate act.</td></tr><tr><td>Gross Demand</td><td>Net demand in respect of metered volume at a Connection Point during a particular hour, plus the metered volume of electricity produced by the user in kilowatt-hours during the same one-hour period, and at the site served by the relevant Connection Point</td></tr><tr><td>Maximum Demand</td><td>A value in kilowatt-hours per hour, defining users' responsibility to pay the TUoS Charge</td></tr><tr><td>Maximum Metered Volume:</td><td>A user's Net Demand in kilowatt-hours in the clock hour of the year when its metered Net Demand is the highest.</td></tr><tr><td>Net Demand</td><td>The metered volume of electricity in kilowatt-hours taken from the transmission system at a Connection Point over a one hour period</td></tr><tr><td>NG</td><td>National Grid of Saudi Arabia</td></tr><tr><td>Notified Net Demand</td><td>An amount in kilowatt-hours per hour that defines the Maximum Demand notified by a user opting to pay TUoS charge on the basis of its Net Demand</td></tr><tr><td>SAR</td><td>Saudi Arabian Riyals</td></tr><tr><td>Surcharge</td><td>A surcharge levied on users electing to pay TUoS on the basis of their Net Demand, applicable only in cases where the user's Maximum Metered Volume exceeds its Notified Net Demand</td></tr><tr><td>Wheeled Energy</td><td>Wheeled energy means cases involving a user transferring energy it produced at one site using a captive generation facility to serve its own demand at another site(s), by transferring such energy through the transmission system of NG.</td></tr><tr><td>(calendar) Year</td><td>Gregorian year, starting from 1st January</td></tr></table>
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