HomeMy WebLinkAboutORD 2025-47 - Amending Code in Section 13.04 relating to Electric service rates feesJORDINANCE NO.
AN ORDINANCE OF THE CITY COUNCIL OF THE CITY OF
GEORGETOWN, TEXAS, AMENDING SECTIONS 13.04.015, 13.04.018,
13.04.020, 13.04.025, 13.04.030, 13.04.035, 13.04.040, 13.04.045, 13.04.046,
13.04.050, AND 13.I55 OF THE CODE OR ORDINANCES OF THE CITY
OF GEORGETOWN RELATING TO ELECTRIC SERVICE RATES FOR
VARIOUS CUSTOMER CLASSES; REPEALING CONFLICTING
ORDINANCES AND RESOLUTIONS; PROVIDING A SEVERABILITY
CLAUSE; PROVIDING FOR PUBLICATION; AND ESTABLISHING AN
EFFECTIVE DATE.
WHEREAS, the City of Georgetown periodically reviews and adjusts its electric service
rates; and
I qrii 111 11 111
WHEREAS, the City of Georgetown has completed a cost -of -service study for the electric
utility; and
WHEREAS ' the City Council desires to implement rates which fully recover the cost of
electric service; and
WHEREAS, the City Council of the City of Georgetown wishes to amend the current
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after Oct. 1, 2025.
NOW, THEREFORE9 BE IT ORDAINED BY THE CITY COUNCIL OF THE CITY
OF GEORGETOWN, TEXAS, THAT:
Section 1. The meeting at which this ordinance was approved was in all things conducted
in compliance with the Texas Open Meetings Act, Texas Government Code, Chapter
Section 2. The facts and recitations contained in the preamble of this ordinance are hereby
found and declared to be true and correct and are incorporated by reference herein and expressly
made a part hereof, as if copied verbatim.
Section 3. Sections 13.04.015, 13.04.018, 13 ' 04.020, 13 ' 04.025� 13.04.030, 13.04.0355
13.04 ' 040, 13.04.045, 13.04.046, 13.04.050, andl3.04.055 of the Code of Ordinances are hereby
amended and replaced as shown in Exhibit A.
Section 4. If any provision of this ordinance or application thereof to any person or
circumstance shall be held invalid, such invalidity shall not affect the other provisions, or
application thereof, of this ordinance which can be given effect without the invalid provision or
application, and to this end the provisions of this ordinance are hereby declared to be severable.
Section 5 That all ordinances that are in conflict with the provisions of this ordinan
be, and the same are hereby, repealed and all other ordinances of the City not in conflict with
[provisions of this ordinance shall remain in full force and effect.
Section 6. The Mayor is hereby authorized to sign this ordinance and the CI
Secretary to attest. This Ordinance shall become effective and be in full force and effect on Octob
1, 2025, in accordance with the provisions of the Charter of the City of Georgetowl
PASSED AND APPROVED on First Reading on the &I -day of
2025.
PASSED AND APPROVED on Second Reading on =tire 9-014ay of
.2025.
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A. Availability. This schedule is available to residential customers for all domestic uses in
residences, individual family apartments, and private rooming houses. This schedule is not
available to single metered multi -family dwellings.
Where a portion of a residential unit is used for non-residential purposes, the appropriate
non-residential service schedule is applicable to all uses of electric service. However, this rate
schedule maybe applied to the residential portion of such use provided the customer's wiring is
so arranged that use of the electric service for residential purposes can be metered separately
from the non-residential use. Service rendered under this rate is subject to the City's Rules and
Regulations.
1. Customer Charge: $25.32 per month
2. Energy Charge: $0.0978per kWh
3. Minimum Bill: $25.32 per month
4. Multiple Dwelling Units. Where served under one meter shall be billed under the
applicable commercial rate.
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased
or decreased to reflect the application of a power cost adjustment perk of energy used,
calculated in accordance with Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule
shall be increased or decreased to reflect the application of a transmission delivery cost
adjustment perk of energy used, calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to
the above rates.
F. Residential customers may request a low-income electric discount that is 30 percent below
the current customer charge (base rate) as follows:
1. Request for low-income discount must be made in writing.
2. To qualify for the discount, customer or a permanent resident in the household must
participate in the Medicaid Program and provide verifiable proof of that
participation, such as an award letter or other official documentation.
Sec. 13.04.018. Net energy metering (NEM) service.
A. Availability. Available to residential and small general service customers within the City of
Georgetown (COG) electric service area that own distributed energy resource (DER)
facilities.
The following requirements must be met for customers to be served under NEM:
A
• Customer has executed an interconnection agreement with COG, and COG has approved
their completed net metering service application.
• DER facility is customer owned and powered by a renewable resource, including but not
limited to solar, wind, and geothermal sources.
• For all DER facilities approved by the City after October 1, 2020, the DER facility's
installed capacity must be no greater than ten kW -DC (kilo watts direct current) and
receives service at 600 volts or less.
• DER facility is located at the customer's premises or that is appropriately connected to
COG's electric distribution system, as solely determined by COG.
B. Metering. For DER installations before June 22, 2021, customers served under NEM will
have two electric meters installed by COG at the customer's premises: a DER Meter, which
measures the total amount of generated electricity from the customer's DER facility, and a
bi-directional meter that measures both the volumetric energy and renewable energy -
received, as defined herein. These bi-directional meter readings are used for generating the
NEM customer's monthly bill. For all DER installations for NEM customers after June 22,
202 1, DER meters are not required; only bi-directional meters will be installed.
C. Meter Definitions.
Bi-Directional Meter: An electric meter with separate registers that measures and record
on an interval basis, the flow of electricity from COG to the NEM customer (volumetric
energy) as well as the flow of electricity from the customer's DER facility to COG
(renewable energy - received), as applicable.
DER Meter: The DER meter measures the total amount of energy generated by the
customer's DER facility. The meter records "renewable energy - generated".
Renewable Energy Generate& The total energy produced by the customer's DER facility
for the billing period, as measured and recorded by the DER meter. No charges or credits
are associated with the renewable energy - generated. This information is provided to CO
and is identified on the customer's bill, for informational purposes only. I
Renewable Energy Received: Any excess metered energy generated from the customer's
DER facility that is not used on -site at the customer's premises and flows back to COG
during a billing cycle. The renewable energy - received is measured by the bi-directional
meter and recorded on an interval basis. COG pays NEM customers a credit per kilowatt
hour of the renewable energy - received.
Volunietric Energy: The amount of metered energy delivered by COG to the customer's
premises during a billing cycle. This value is measured by the bi-directional meter and
recorded on an interval basis. NEM customers pay COG per kilowatt hour for volumetric
energy.
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Base Rate: The base rate is the customer charge for the applicable customer class in which
the NEM customer exists. The base rate is a per customer charge on a $/month basis.
Volumetric Energy Charge.� The volumetric energy charge is the energy charge for the
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is applied to the volumetric energy on a $/kWh basis.
Renewable Energy Received Credit: The renewable energy - received credit is an energy
rate ($/kWh) applied to the NEM customer's renewable energy - received. COG pays NEM
customers a credit per kilowatt hour for renewable energy - received. The credit on the
customer's bill is subject to the limitations discussed in item 1.
Power Cost Adjustment (PCA): The PCA charge under this rate schedule shall be increased
or decreased to reflect the application of a PCA per kWh of energy delivered by COG
(volumetric energy) during the billing cycle, as calculated in accordance with Section
13.04.075.
Transmission Delivery Cost Adjustment (TDCA): The TDCA charge under the above rate
schedule shall be increased or decreased to reflect the application of a transmission delive
cost adjustment per kWh of energy delivered by COG (volumetric energy), as calculated i
accordance with Section 13.04.080. 1
1. Base Rate: $25.32 per month
2. Volumetric Energy Charge: $0.0978per kWh
3. Renewable Energy - the received credit shall be calculated on an annual basis
according to the following formula:
Weighted Avg. Market Price $ $
Credit $ (FW—h) + Avg. Transmission Capacity Cost (Ykh)
COI�—)
Where "Weighted Avg. Market Price" represents the previous year's weighted average
Locational Marginal Prices coincident with solar producing hours at the Electric Reliability
Council of Texas (ERCOT) South Load zone. The periods coincident with ERCOT and/or Public
Utility Commission of Texas declared controlled outages and/or grid emergencies are not
included in the Weighted Avg. Market Price calculation. The "Avg. Transmission Capacity
Cost" represents the previous year's average transmission -cost -of -service (TCOS) charges
($/kWh) paid by the Utility for transmission, and "Losses" represents the most recently
calculated value for COG's distribution system losses as a percent.
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1. Base Rate as a COG Electric Customeri $51.05 per month
3. Renewable Energy - the received credit shall be calculated on an annual basis
according to the following formula:
Credit ® Weighted Avg. Market Price ( $ ) + Avg. Transmission Capacity Cost( h)
(kWh) kWh Losses
kW
Where "Weighted Ava� Market Price" represents the previous year's weighted average
1 1 Prices coincidenti producing 1 Reliability
includedCouncil of Texas (ERCOT) South Load zone. The periods coincident with ERCOT and/or Public
Utility Commission of Texas declared controlled outages and/or grid emergencies are not
in the Weighted Avg. Market Price1 . Transmission Capacity
Cost" represents the previous year's average transmission-eost-of-service (TCOS) charges
($/kWh) paid by the Utility for transmission, and "Losses" represents the most recently
calculated value for COG's distribution system losses as a percent.
4. PCA: (as determined in Section 13.04.075)
5.- TCA: (as determined in Section 13.04.080)
H. Renewable Energy - Received Credit - Annual Update. The renewable energy - received
credit will be reviewed and may be adjusted on an annual basis by COG according to the
formula above.
I. Limit on Renewable Energy - Received Credit. For a billing cycle, and for the purposes of
calculating the renewable energy - received credit, the excess renewable energy (kWh)
COG receives from NEM customers cannot be greater than the volumetric energy (kWh)
COG delivers to the customer's premises. Renewable energy - received that is in excess of
the volumetric energy during the billing cycle is not eligible for compensation to the NEM
customer by COG. Such excess energy may not be banked by the NEM customer nor rolled
over to the following or future billing period(s). Further, such excess energy cannot be
utilized to offset other COG charges on the NEM customer bill.
J. Sales Taxes. Sales taxes, where applicable, will be charged to the customer, as appropriate,
in addition to the above rates.
See. 13.04.020. Small general service.
A. Availability. Applicable to all commercial and general service consumers whose demands
for all uses are less than 50 kW and whose uses are not covered by a specific rate schedule
and the metered outdoor lighting of sports fields and arenas in which 85 percent of the
connected electric load is attributable to the lighting as verified by the City, up to 75 kW of
connected load. Service rendered under this rate is subject to the City's Rules and
Regulations.
B. Net Monthly Rate.
1. Customer Charge: $51.05 per month
2. Energy Charge: $0.0921 per kWh
3. Minimum Bill: $51.05 per month
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased
or decreased to reflect the application of a power cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule
shall be increased or decreased to reflect the application of a transmission delivery cost
adjustment per kWh of energy used, calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to
the above rates.
See. 13.04.025. School services.
A. Availability. Available to electric services required by those customers designated as a
school by the City. Service rendered under this rate is subject to the City's Rules and
Regulations.
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1. Customer Charge: $204.02 per month
2. Energy Charge: $0.1174 per kWh
3. Minimum Bill: $204.02 per month
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increase
or decreased to reflect the application of a power cost adjustment per kWh of energy use
calculated in accordance with Section 13.04.075. 1
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedul
shall be increased or decreased to reflect the application of a transmission delivery cost
adjustment per kWh of energy used, calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition t
the above rates. I
See. 13.04.030. Municipal water and wastewater pumping service.
A. Availability. Applicable to City -owned facilities with electric service fumished for water
and wastewater pumping. Service rendered under this rate is subject to the City's Rules and
Regulations.
1. Customer Charge: $199.10 per month
2, Energy Charge: $0.04600 per kWh
3. Demand Charge: $19.99 per kW per month
4. Minimum Bill: $199.10 per month
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased
or decreased to reflect the application of a power cost adjustment per kWh of energy used,
calculated in accordance
D. Transmission Delivery CostAdjustment. The TDCA charge under the above rate schedule
shall be increased or decreased to reflect the application of a transmission delivery cost
adjustment per kWh of energy used, calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition t4
the above rates.
Sec. 13.04.035. Large general service.
A. Availability. Applicable to customers whose design load or actual usage exceeds 50 kW of
peak demand, but does not exceed 500 kW of peak demand, and whose uses are not coverei
by a specific rate schedule. Service rendered under this rate is subject to the City's Rules
and Regulations.
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3. Demand Charge: $11.23 per kW per month, but not ess than $561.50 per mo
Minimum Bill: $740.18 per month.
e C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increas I
or decreased to reflect the application of a power cost adjustment per kWh of energy use
calculated in accordance with Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedulli
shall be increased or decreased to reflect the application of a transmission delivery cost
adjustment per kWh of energy used, calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to
the above rates.
A. Availability. Applicable to customers whose design load or actual usage exceeds 500 kW J1
peak demand, but does not exceed 2,000 kW of peak demand, and whose uses are not
covered by a specific rate schedule. Service rendered under this rate is subject to the City's
Rules and Regulations. I
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1. Customer Charge: $357.35 per month
2. Energy Charge: $0.0577 per kWh
3. Demand Charge: $16.34 per kW per month, but not less than $8,170.00 per month.
4. Minimum Bill: $8,527.35 per month.
Created: 2025-04-23 07:02:37 [EST]
(Supp. No. 31, Update 1)
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increase]
or decreased to reflect the application of a power cost adjustment per kWh of energy use
calculated in accordance with Section 13.04.075.
D. Transmission Deliveg Cost Adjustment. The TDCA charge under the above rate schedule
shall be increased or decreased to reflect the application of a transmission delivery cost
adjustment per kWh of energy used, calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in a ition to
the above rates.
Sec. 13.04.045. Large commercial and industrial (C&I) service
A. Availability. Applicable to large commercial and industrial customers whose installed
capacity is 2,000 kW or greater but less than 10,000 kW and whose uses are not covered b,
another specific rate schedule. Service rendered under this rate is subject to the City's rules
and regulations. "Installed capacity" means the maximum allowed distribution infrastructu. -
capacity designed, installed, and allocated for a customer based on their specified load
requirements, including peak demand and energy needs. This capacity ensures sufficient
distribution infrastructure to meet peak demand under normal operating conditions.
B. Monthly rate.
1. Customer charge: $520.71 per month.
2. Energy charge: $0.0543 per kWh.
3, Demand charge: $19.65 per kW per month but not less than $39,300.00 per mont
4. Minimum bill: $39,820.71 per month.
C. Power cost adjustment. The power cost adjustment charge under the above rate schedule
shall be increased or decreased to reflect the application of a power cost adjustment per
kWh of energy used, calculated in accordance with Section 13.04.075.
D. Transmission delivery cost adjustment. The transmission delivery cost adjustment charge
under this rate schedule shall be increased or decreased to reflect the application of a
transmission delivery cost adjustment per kWh of energy used, calculated in accordance
with Section 13.04.080.
E. Minimum bill. The minimum bill for large commercial and industrial service shall consist of
the customer charge plus the minimum demand charge.
F. Minimum demand. The minimum demand for the large commercial and industrial class is
2,000 kW.
G. Powerfactor. Should the power factor be lower than 0 " 95 lagging, the City may adjust the
billed demand (kW) by the ratio of target power factor in the numerator (0.95) divided by
the actual power factor in the denominator (less than 0.95). If the power factor ratio is
greater than a value of 1.0, it will be multiplied by the billing cycle billed demand
applicable to the customer.
Created: 2025-04-23 07:02:37 [EST]
(Supp. No. 31, Update 1)
1. Applicability. Applicable to large commercial and industrial customers taking servic'l
at primary distribution voltage ("primary voltage customers").
2. Monthly demand discount rate. Primary voltage customers demand rate will b
reduced (credited) by
3. Minimum bill. The minimum bill for primary voltage customers will be based on the
minimum bill for their applicable customer class, as described herein. To the extent
that the minimum bill includes the demand charge, calculation of the demand charge
will reflect the applicable monthly demand discount rate.
4. Primary voltage discount —Update. The primary voltage discount will be reviewed
and may be adjusted on an annual or less frequent basis as determined by the City.
Sales taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the
above rates.
A. A��� Applicable to very large commercial and industrial customers w ose Installed
Capacity is greater than 10 MW but less than 51 MW. Service rendered under this rate is
subject to the City's Rules and Regulations, provided that Section 13.04.230 shall not
apply. All customers eligible for this rate schedule must also enter into an electric service
agreement with the City ("Electric Service Agreement"). "Installed Capacity" means the
maximum allowed distribution infrastructure capacity designed, installed, and allocated for
a customer based on their specified load requirements, including peak demand and energy
needs. This capacity ensures sufficient distribution infrastructure to meet peak demand
under normal operating conditions.
Oth of each month prior to and after beginning service, Customer
must submit to the City an energy forecast of its projected energy usage for the following
6 months. This energy forecast is a projection of the future forecasted energy consumption
by Customer and shall be in the form of an hourly energy profile of expected energy
consumption (kWh) for each hour of the following 6 months.
C. Any Customer who fails to submit an Energy Foreca.
when due shall be subject to interruption or termination of electric service, and any oth
I
remedies available to City under its Rules and Regulations. In addition, the City shall ha
the right to forecast Customer's projected energy load for the Energy Forecast term, subj ell
to other provisions in this Section 13.04.046.
D. �Ijjy2jfge� Invoices are due and payable immediately upon receipt and considered late if not
paid within 7 days after receipt. The City can immediately apply any cash Prepayment
Amount (defiried below) or draw on any letter of credit provided by Customer for any late
or unpaid amounts owed to the City by the Customer, or take any other action provided for
under the City's Rules and Regulations.
E. PropavnientAmount. Prior to activation of electric service, Customer shall provide to the
City a minimum cash prepayment amount ("Prepayment Amount") equal to three (3)
months of the highest projected total cost of energy deliveries pursuant to the Electric
Service Agreement and this rate schedule, including the Customer Charge, Energy Charge,
Billed • Power Cost Adjustment, Energy Rate Rider, Transmission Delivery Cost
Adjustment, and any other authorized charges. The Billed Demand shall be calculated
pursuant to Section 0 below, the applicable Billed Demand multiplied by three (3) months
or such additional period of time as the City may require ("Prepayment Term"). The City
shall apply the Prepayment • monthly to Customer's invoice for electric service,
and Customer shall pay any amounts owed to City in addition to the Prepayment Amount
and replenish the Prepayment Amount each month equal to the amount • the then -current
Prepayment Amount for the then -current Prepayment Term. The City reserves the right to
require additional amounts above the Prepayment Amount based on the creditworthiness
of the Customer, energy market volatility, previous payment defaults, or business history
of the Customer, each as determined by the City in its sole discretion. Any Prepayment
Amounts under this Section 13.04.046 (Very Large Commercial & Industrial Service) shall
not bear interest and shall be applied to each invoice and replenished by Customer in
accordance with this subsection (E).
F C! roe do # S addition to the Prepayment amount in Section E Customer shall also
provide Performance Assurance pursuant to Section G herein in an amount equal to or
greater than 3 months of the projected revenues to City based on the highest three months
of • Energy Forecast
G. Performance Assurance. Customer shall provide to the City either an unconditional
irrevocable letter of credit ("Letter of Credit") or a form of guarantee approved by City
("Parental Guarantee") Letter of Credit and Parental Guarantee are collectively referTed to
as "Performance Assurance.". Both the Letter of Credit and the Parental Guarantee must:
(1) be made payable to the City; (2) require at least 60 days written notice to the City upon
non -renewal or termination; and (3) allow for immediate draw by the City for the non-
payment of any invoice by the due date or any other payment default by Customer. In the
event the City applies all or part of the Performance Assurance related to any late payment
or non-payment by Customer, or any other payment default by the Customer, the City may
immediately request additional Performance Assurance from Customer in order for the
continuance • electric service by the City.
i. The Letter of Credit shall comply with Texas Business and Commerce Code §5.106
issued by a bank or financial institution with a minimal credit rating of A- from
either S&P • Fitch, or a minimal rating • A3 from Moody, and that has a physical
location or address in the United States in which the Letter of Credit can be drawn,
and that is • acceptable to the City in its sole discretion. The City reserves
the right in its sole discretion to • an increase in the amount • the Letter of
Credit, including but not limited to an increase based on market volatility,
creditworthiness of the Customer, previous payment defaults, or business history
• the Customer.
Page 11 of 17
A Customer may • provide a Parental Guarantee if the corporate, • • entit
providing such guarantee has an investment grade rating at least one notch abov
Baa3 by Moody's, BBB- by S&P Global or BBB- by Fitch Ratings. In the eve
that the entity proving the Parental Guarantee drops below investment grad
Customer must replace the Parental Guarantee with a Letter • Credit within tw
(2) business days. The City reserves the right in its sole discretion to require a
increase in the amount of the Parental Guarantee, including but not limited to
increase based on market volatility, creditworthiness of the Customer, previou
payment defaults, • business history of the Customer. I
FA. ��� Customers under this Rate Ordinance shall also be responsible for all the costs
including but not limited to the cost of any and all additional equipment that the City's City
Manager, City's General Manager of Electric Utilities ("General Manager") or each of their
respective designees, determines is needed, including but not limited to advanced metering
equipment, to manage the Customer's energy load and usage to ensure reliable energy
service • all • • the City.
Page 12 of 17
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the Customer Facilities or the ERCOT grid. Subject to the aforementioned notice and
shutdown requirements, City shall have no liability for exercising such right, nor shall
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J Prior to the commencement of service, Customer
shall pay a non-refundable account set-up fee in the amount of $25,645, which may be
updated from time to time by the City, for installation of ERCOT EPS meter(s) and any
other initiation, installation, or other fees levied by ERCOT or otherwise incurred by the
City as a result of providing energy service to the Customer.
K. Monti
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3. Demand Charge: $19.65 per kW per month subject to Billed Demand as outlined
in Section 0 below.
L. The power cost adjustment charge under the above rate schedule
shall be increased or decreased to reflect the application of a power cost adjustment per
kWh of energy used, calculated in accordance with Section 13.04.075.
M. In addition to the charges identified in K and L, Customers shall pay
the Energy Rate Rider ($/kWh) ("ERR") for all energy consumed. The City Manager,
General Manager or their respective designees are responsible for making periodic
adjustments to the ERR, which will be based upon two (2) months of actual power supply
costs and six (6) months of forecasted future costs to serve the customers in the Very Large
Commercial and Industrial Service class and the cumulative ERR account balance.
Changes to the ERR shall have the objective of maintaining a positive cumulative ERR
account balance.
FERR = ([(ER + ERR) x TL]-HG/L - FHC — SMP —FL H - As)+(TAB-AAB))/TL
Where:
FERR = Future Energy Rate Rider rounded to the nearest $. 000 1 /kWh. In no event shall
the FERR be less than zero ($0)
ER = Energy Rate for VLC&I class ($0.5173/kWh) — subject to revision by rate
ordinance
ERR = Energy Rate Rider in effect for the historical load period
n
TL = Total Load =yi=1 Aggregate VLC&I Energy in kWh
adjusted f or distribution and transmisson losses.
Where n = the number of hours in the eight (8) month calculation period.
Page 13 of 17
J=
HG/L = Historical hedge gains or losses = V 1 (HPi * HVi) + (HVi * (HPi — RTPi))
Where HPi = Hedge price for hour i
AU = Actual load for the class for hour i
HVi = Hedge volume for hour i
RTi = Real Time Price for the ERCOT South Load Zone
FHC = Future Hedge Cost = i = 1 FHVi * FHPi
Where:
FHVi = Hedged volume in hour i
FHPi = Hedge price in hour i
SMP = Spot Market Purchases (historic and future) = En 1 SMPi * LMPi
Where:
SMPi = spot market purchases in hour i (can be real-time LMP or day -ahead
LMP)
LMPi = LMP for the ERCOT South Load Zone in hour I
LMP means the Locational Marginal Price
yn
FL H = Future Load Hedges = 'i�l FLHi * FPi
Where:
FLHi = Future forecasted load to be hedged in hour i
FPi = Future Price in hour i (for future prices the imputed real-time LMP
will be used) FL H and SMP are mathematically the same if there are no
future hedge volumes to be traded.
En
AS = Ancillary Service Costs = i=1 ASi * TLi
Where:
ASi = Historical Ancillary Service Costs in hour i and the forecasted
Ancillary Service costs for hour i for future load.
TU = Total Load served, or to be served in hour i-.
TAB = Target Account Balance — the targeted Energy Rate Rider account balance
established by the City Manager, General Manager or their respective designees to stabilize
the cost of wholesale power to the VLC&I rate class.
AA B = Actual Account Balance — the net revenues from the collection of the Energy Rate
Rider
The ERR (and the FERR above) may not be less than zero. The City Manager, General
Manager or their respective designees are responsible for making periodic adjustments to
the ERR.
N. Ratcheted Demand. in the event that the actual monthly peak demand of the Custom
exceeds (i) 80% of the Installed Capacity or (ii) the minimum demand as defined in t
Electric Service Agreement, such new higher peak demand shall be used to determine t
Billed Demand and shall be applicable for a period of 12 consecutive months from t I
month in which the highest peak demand is measured ("Demand Ratchet"). I
Page 14 of 17
*. Billed Demand. The Billed Demand shall be the greater of:
kilowatts (kW) recorded during the billing period, or
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.Vte De-ua-1 A rate -se I .
Billed Demand may be adjusted for power factor if the actual power factor falls below th'i
threshold specified in this tariff.
r". ransimssion Delivict Li The transmission delivery cost adjustment charge
under this rate schedule shall be increased or decreased to reflect the application of a
transmission delivery cost adjustment per kWh of energy used, calculated in accordance
with Section 13.04.080.
•I It I - # I I I I I - . - # I I
IM 1"M COMM •I • I I
Fr`�. If the Customer's power factor during a billing cycle is less than 0.95
lagging, the City may adjust the Billed Demand (M) by applying a multiplier. This
multiplier is calculated by dividing the target power factor (0.95) by the Customer's actual
power factor (which is less than 0.95). -The resulting ratio will be multiplied by the Billed
Demand for that billing cycle.
S. Primar i Volt 1---age Discount.
L ��. Applicable to large commercial and industrial customers taking
service at primary distribution voltage ("Primary Voltage Customers").
t Primary Voltage Customers demand rate will be
reduced (credited) by
T. The monthly minimum bill amount related to any Customer whose lo
capacity is between 10 MW and less than 51 MW shall be an amount equal to the sum
the Customer Charge, Energy Charge, Demand Charge, Power Cost Adjustment, Ener
Rate Rider, Transmission Delivery Cost Adjustment, and any other authorized charges. I
U. $410j:[4X4. Sales taxes, where applicable, will be charged to Customer in addition to the
,?bove rztes.
See. 13.04.050. Electric vehicle (EV) charger service.
A. Availability. Available to electric vehicle charging infrastructure providers whose design
load or actual usage exceeds 500 kW of peak demand, but does not exceed 2,000 kW of
peak demand, within the City of Georgetown electric service area and whose uses are not
Page 15 of 17
covered by a specific rate schedule. Companies must share sub -metered data to qualify for
this rate.
wlmzz���
1. Customer Charge: $357.35 per month
3. Demand Charge: $16.34 per kW per month, **(Billed on greater of Actual demand
OR 500 kW OR 80 percent of peak month demand over previous 12-month period).
I" month demand will be equal to system design demand.
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased
or decreased to reflect the application of a power cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule
shall be increased or decreased to reflect the application of a transmission delivery cost
adjustment per kWh of energy used, calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to
the above rates.
A. Availability. Applicable to City -owned and operated facilities whose uses are not covered
by a specific rate schedule. Service rendered under this rate is subject to the City's Rules
and Regulations.
sw=�
C. Power Cost Adjustment. The PICA charge under the above rate schedule shall be increased
or decreased to reflect the application of a power cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedul
shall be increased or decreased to reflect the application of a transmission delivery cost
adjustment per kWh of energy used, calculated in accordance with Section 13.04.080. 1
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to
the above rates.
Created: 2025-04-23 07:02:37 [EST]
(Supp. No. 31, Update 1)
A. Availability. This schedule is available to residential customers for all domestic uses in residences, individual
family apartments, and private rooming houses. This schedule is not available to single metered multi -family
dwellings.
Where a portion of a residential unit is used for non-residential purposes, the appropriate non-residential
service schedule is applicable to all uses of electric service. However, this rate schedule maybe applied to the
residential portion of such use provided the customer's wiring is so arranged that use of the electric service for
residential purposes can be metered separately from the non-residential use. Service rendered under this rate is
subject to the City's Rules and Regulations.
Net Monthly Rate.
1. Customer Charge: $24.9925.32 per month
2. Energy Charge: $0.09590 0978per kWh
3. Minimum Bill: $244025;per month
4. Multiple Dwelling Units. Where served under one meter shall be billed under the applicable
commercial rate.
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased or decreased to
reflect the application of a power cost adjustment per kWh of energy used, calculated in accordance with
Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule shall be increased or
decreased to reflect the application of a transmission delivery cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
F. Residential customers may request a low-income electric discount that is 30 percent below the current
customer charge (base rate) as follows:
1. Request for low-income discount must be made in writing.
2. To qualify for the discount, customer or a permanent resident in the household must participate in the
Medicaid Program and provide verifiable proof of that participation, such as an award letter or other
official documentation.
Sec. 13.04.01. Net energy metering (NEM) service.
A. Availability. Available to residential and small general service customers within the City of Georgetown (COG)
electric service area that own distributed energy resource (DER) facilities.
The following requirements must be met for customers to be served under NEM:
• Customer has executed an interconnection agreement with COG, and COG has approved their completed
net metering service application.
• DER facility is customer owned and powered by a renewable resource, including but not limited to solar,
wind, and geothermal sources.
• For all DER facilities approved by the City after October 1, 2020, the DER facility's installed capacity must
be no greater than ten kW -DC (kilo watts direct current) and receives service at 600 volts or less.
• DER facility is located at the customer's premises or that is appropriately connected to COG's electric
distribution system, as solely determined by COG.
B,, Metering. For DER installations before June 22, 2021, customers served under NEM will have two electric
meters installed by COG at the customer's premises: a DER Meter, which measures the total amount of
generated electricity from the customer's DER facility, and a bi-directional meter that measures both the
volumetric energy and renewable energy - received, as defined herein. These bi-directional meter readings
are used for generating the NEM customer's monthly bill. For all DER installations for NEM customers after
June 22, 2021, DER meters are not required; only bi-directional meters will be installed.
C. Meter Definitions.
Bi-Directional Meter. An electric meter with separate registers that measures and records, on an interval
basis, the flow of electricity from COG to the NEM customer (volumetric energy) as well as the flow of
electricity from the customer's DER facility to COG (renewable energy - received), as applicable.
DER Meter. The DER meter measures the total amount of energy generated by the customer's DER facility.
The meter records "renewable energy - generated
D Energy Definitions.
Renewable Energy Generated: The total energy produced by the customer's DER facility for the billing period,
as measured and recorded by the DER meter. No charges or credits are associated with the renewable
energy - generated. This information is provided to COG, and is identified on the customer's bill, for
informational purposes only.
Renewable Energy Received: Any excess metered energy generated from the customer's DER facility that is
not used on -site at the customer's premises and flows back to COG during a billing cycle. The renewable
energy - received is measured by the bi-directional meter and recorded on an interval basis. COG pays NEM
customers a credit per kilowatt hour of the renewable energy - received.
Volumetric Energy: The amount of metered energy delivered by COG to the customer's premises during a
billing cycle. This value is measured by the bi-directional meter and recorded on an interval basis. NEM
customers pay COG per kilowatt hour for volumetric energy.
E. Charges for Service Definitions.
Base Rate: The base rate is the customer charge for the applicable customer class in which the NEM
customer exists. The base rate is a per customer charge on a $/month basis.
Volumetric Energy Charge: The volumetric energy charge is the energy charge for the applicable customer
class in which the NEM customer exists. The volumetric energy charge is applied to the volumetric energy on
a $/kWh basis.
Renewable Energy Received Credit: The renewable energy - received credit is an energy rate ($/kWh) applied
to the NEM customer's renewable energy - received. COG pays NEM customers a credit per kilowatt hour for
renewable energy - received. The credit on the customer's bill is subject to the limitations discussed in item I.
Power Cost Adjustment (PCA): The PCA charge under this rate schedule shall be increased or decreased to
reflect the application of a PCA per kWh of energy delivered by COG (volumetric energy) during the billing
cycle, as calculated in accordance with Section 13.04.075.
Transmission Delivery Cost Adjustment (TDCA): The TDCA charge under the above rate schedule shall be
increased or decreased to reflect the application of a transmission delivery cost adjustment per kWh of
energy delivered by COG (volumetric energy), as calculated in accordance with Section 13.04.080.
F 4dyR f j Rrr C i s ii •• r tc li ,..w�f i r � r r n t •. ri l°a rtii
Rrr�r �Ja .1 �s.. :M�o����s-�r .,, , w .. , ��i f t•oa�,-- -# ..` '.
irr', ' i�k�r. rny�.AiTrmSe:�� r : J� �:tt�+�•#e�rra�`��i�a�.t��mty-µi•�rr�w-lir�ay,
Rt�� ��.�rRw,...-ts�i+�r , • „ r��fs•��aaur-it�tae�°..
Page 2 of 12
Reserved
G. Monthly Ratesfor NEM Customers. Rates are subject to change and as described herein.
Residential Service:
l. Base Rate: $24,89J5,32per month
Z. Volumetric Energy Charge: $0.99-59�0978perkWh
~ 3. Renewable Energy - the received credit shall be calculated on an annual basis according to the ^
following formula:
�$
Weighted Avg. Market Price + Avg. Transmission Capacity Cost Credit (TW�)=
Where "Weighted Avg. Market Price" represents the previous year's weighted average Lmcatmna|Marginal Prices
coincident with solar producing hours at the Electric Reliability Council of Texas (ERCOT)South Load zone. The
periods coincident with ERCOT and/or Public Utility Commission of Texas declared controlled outages and/or grid
emergencies are not included in the Weighted Avg. Market Price calculation. The "Avg. Transmission Capacity
Cost" represents the previous year's average transmission -cost -of -service (TCOS) charges ($/kWh) paid by the
Utility for transmission, and "Losses" represents the most recently calculated value for COG's distribution system
losses asa percent.
4. PCA:(as determined inSection I3.04.075)
5. TD[A:(as determined inSection 13.04V8O
Small General Service:
l. Base Rate asaCOG Electric Customer: S&97-0051JD5per month
Z. Volumetric Energy Charge: $0.09P—L09I1 per kWh
3. Renewable Energy the received credit shall becalculated nnanannual basis according tothe
following formula:
Credit $ Weighted Avg. Market Price + Avg. Transmission Capacity Cost (Ywh)
(TWh)
��=
� I — Losses (,u)
Where "Weighted Avg. Market Price" represents the previous year's weighted average Locational Marginal Prices
coincident with solar producing hours at the Electric Reliability Council of Texas (ERCOT) South Load zone. The
periods coincident with ERCOT and/or Public Utility Commission of Texas declared controlled outages and/or grid
emergencies are not included in the Weighted Avg. Market Price calculation. The "Avg. Transmission Capacity
Cost" represents the previous year's average transmission -cost -of -service (TCOS) charges ($/kWh) paid by the
Utility for transmission, and "Losses" represents the most recently calculated value for COG's distribution system
losses as a percent.
4. PCA: (as determined in Section 13.04.075)
5. TDCA: (as determined in Section 13.04.080)
H. Renewable Energy - Received Credit - Annual Update. The renewable energy received credit will be
reviewed and may be adjusted on an annual basis by COG according to the formula above.
I. Limit on Renewable Energy - Received Credit. For a billing cycle, and for the purposes of calculating the
renewable energy - received credit, the excess renewable energy (kWh) COG receives from NEM customers
cannot be greater than the volumetric energy (kWh) COG delivers to the customer's premises. Renewable
energy - received that is in excess of the volumetric energy during the billing cycle is not eligible for
compensation to the NEM customer by COG. Such excess energy may not be banked by the NEM customer
nor rolled over to the following or future billing period(s). Further, such excess energy cannot be utilized to
offset other COG charges on the NEM customer bill.
J. Sales Taxes. Sales taxes, where applicable, will be charged to the customer, as appropriate, in addition to the
above rates.
Sec. 13.04.020. Small general service.
A. Availability. Applicable to all commercial and general service consumers whose demands for all uses are less
than 50 kW and whose uses are not covered by a specific rate schedule and the metered outdoor lighting of
sports fields and arenas in which 85 percent of the connected electric load is attributable to the lighting as
verified by the City, up to 75 kW of connected load. Service rendered under this rate is subject to the City's
Rules and Regulations.
B. Net Monthly Rate.
1. Customer Charge: $ C-,0051.05 per month
2. Energy Charge: $0.092,�X,1 per kWh
3. Minimum Bill: $49,0051..05 per month
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased or decreased to
reflect the application of a power cost adjustment per kWh of energy used, calculated in accordance with
Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule shall be increased or
decreased to reflect the application of a transmission delivery cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
A. Availability. Available to electric services required by those customers designated as a school by the City._
Service rendered under this rate is subject to the City's Rules and Regulations.
B. Net Monthly Rate.
1. Customer Charge: $" 4920 .QZ per month
2. Energy Charge: $0.1 _: . 1.174_per kWh
Page 4 of 12
3. Minimum Bill: $ . 204.02 per month
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased or decreased to
reflect the application of a power cost adjustment per kWh of energy used, calculated in accordance with
Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule shall be increased or
decreased to reflect the application of a transmission delivery cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.080.
Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
Sec. 13.0.030. Municipal water and wastewater pumping service.
A. Availability. Applicable to City -owned facilities with electric service furnished for water and wastewater
pumping. Service rendered under this rate is subject to the City°s Rules and Regulations.
B. Net Monthly Rate.
1. Customer Charge:$ =-.WI2 LO per month
2. Energy Charge: $0. 5 04600_per kWh
3. Demand Charge: $19.45 99 per kW per month
4. Minimum Bill: $445,09199.10 per month
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased or decreased to
reflect the application of a power cost adjustment per kWh of energy used, calculated in accordance with
Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule shall be increased or
decreased to reflect the application of a transmission delivery cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
Sec. 13.04.035. Large general service.
A. Availability. Applicable to customers whose design load or actual usage exceeds 50 kW of peak demand, but
does not exceed 500 kW of peak demand, and whose uses are not covered by a specific rate schedule.
Service rendered under this rate is subject to the City"s Rules and Regulations.
B. Net Monthly Rate.
1. Customer Charge: $4- Z8.68 per month
2. Energy Charge: $0. " 0668 per kWh
3. Demand Charge: $11. 2 per kW per month, but not less than $561.5 per month.
4. Minimum Bill: $744740.1899 per month.
C. Power CostAdjustment. The PCA charge under the above rate schedule shall be increased or decreased to
reflect the application of a power cost adjustment per kWh of energy used, calculated in accordance with
Section 13.04.075.
(Supp. No. 31, Update 1)
Page 5 of 12
Created: 2025-04-23 07:02:37 [EST]
D Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule shall be increased or
decreased to reflect the application of a transmission delivery cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
A. Availability. Applicable to customers whose design load or actual usage exceeds 500 kW of peak demand, but
does not exceed 2,000 kW of peak demand, and whose uses are not covered by a specific rate schedule.
Service rendered under this rate is subject to the City's Rules and Regulations.
B. Net Monthly Rate.
1. Customer Charge: $3- `357:35 per month
2. Energy Charge: $0. 1-0577 per kWh
3. Demand Charge: $16. -34 per kW per month, but not less than $8,170999.00 per month.
4. Minimum Bill: $8,31.. 527.35 per month.
C Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased or decreased to
reflect the application of a power cost adjustment per kWh of energy used, calculated in accordance with
Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule shall be increased or
decreased to reflect the application of a transmission delivery cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.080.
Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
A. Availability. Applicable to large commercial and industrial customers whose installed capacity is 2,000 kW or
greater but less than 10,000 kW and whose uses are not covered by another specific rate schedule. Service
rendered under this rate is subject to the City's rules and regulations. "Installed capacity" means the
maximum allowed distribution infrastructure capacity designed, installed, and allocated for a customer
based on their specified load requirements, including peak demand and energy needs. This capacity ensures
sufficient distribution infrastructure to meet peak demand under normal operating conditions.
B. Monthly rate.
1. Customer charge: $154 52 .71. per month.
2. Energy charge: $0. . 3 0543.per kWh.
3. Demand charge: $19.-2--65_per kW per month but not less than per month.
4. Minimum bill: $39,04 82 .7100 per month.
C. Power cost adjustment. The power cost adjustment charge under the above rate schedule shall be increased
or decreased to reflect the application of a power cost adjustment per kWh of energy used, calculated in
accordance with Section 13.04.075.
D. Transmission delivery cost adjustment. The transmission delivery cost adjustment charge under this rate
schedule shall be increased or decreased to reflect the application of a transmission delivery cost adjustment
per kWh of energy used, calculated in accordance with Section 13.04.080.
Created: 2025-04-23 07:02:37 [EST]
(Sapp. No. 31, Update 1)
Page 6 of 12
E. Minimum bill. The minimum bill for large commercial and industrial service shall consist of the customer
charge plus the minimum demand charge.
F, Minimum demand. The minimum demand for the large commercial and industrial class is 2,000 kW.
G. Power factor. Should the power factor be lower than 0.95 lagging, the City may adjust the billed demand
(kW) by the ratio of target power factor in the numerator (0.95) divided by the actual power factor in the
denominator (less than 0.95). If the power factor ratio is greater than a value of 1.0, it will be multiplied by
the billing cycle billed demand applicable to the customer.
H< Primary voltage discount.
1. Applicability. Applicable to large commercial and industrial customers taking service at primary
distribution voltage ("primary voltage customers").
2. Monthly demand discount rate. Primary voltage customers demand rate will be reduced (credited) by
$2.11JkW.
3. Minimum bill. The minimum bill for primary voltage customers will be based on the minimum bill for
their applicable customer class, as described herein. To the extent that the minimum bill includes the
demand charge, calculation of the demand charge will reflect the applicable monthly demand discount
rate.
4. Primary voltage discount —Update. The primary voltage discount will be reviewed and may be adjusted
on an annual or less frequent basis as determined by the City.
L Sales taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
1� 1' • r1111
A. 4,y� Applicable to very large commercial and industrial customers whose Installed Capacity is
greater than I MW but a rendered ier this rate is subject to and
Regulations, provided that Section 13.04.230 shall not apply. All customers eligible for this rate schedule
must t enter into an electric service agreement"Installed
Capacity"• • distribution infrastructure ca♦ designed, installed,F allocated
for a customer based on their specified load requirements, including peak demand and energy needs. This
capacity ensures sufficient distribution infiastructure to meet peak demand under normal operating
conditions.
forecastBy the I Oth of each month prior to and after beginning service, Customer must submit to
the City an energy of projected • following i months.forecast
.: projection of . future forecasted energy consumption by : of . ♦ shall • _ in the form of an hourly
energy profile of expected energy consumption (kWh) for each hour of the following 6 months.
D. 1p�� Invoices are due and payable immediately upon receipt and considered late if not paid within
days after receipt. The City can immediately apply any cash Prepayment Amount (defined below) or dr
or
thin
on any letter of credit provided by Customer for any late or unpaid amounts owed to the City by the Custome
or take any other action provided for under the City's Rules and Regulations.
ty
E. Prior to activation of electric service, Customer shall provide to the City a mmimu
in
cash prepayment amount ("Prepayment Amount") equal to three (3) months of the highest projected tot
cost of energy deliveries pursuant to the Electric Service Agreement and this rate schedule, including t
Customer Charge, Energy Charge, Billed Demand, Power Cost Adjustment, Energy Rate Ride
Pagel of 12
Transmission Delivery Cost Adjustment, and any other authorized charges. The Billed Demand shall be
,yw4a,&"-t,2,�rment defaults, or business history of the Customer, each as
determined by • - discretion. Any Prepaymentr • i' t' r
_Large Commercial: Industrial Service) shall notbear interest and shall be applied to each invoice
replenished by Customer in accordance with this subsection (E).
FCk��� In addition to the Prepayment amount in Section E, Customer shall also provide Perforinance
Assurance pursuant to Section G herein in an amount equal to or greater than 3 months of the projected
revenues to City based on •hest three months of •Energy Forecast
Customerprovide to the City either an unc• { r • abl of e
of f or • of - approved by `arental Guarantee") Letter of Credit and
Parental Guarantee are collectively referred to as "Perforinance Assurance.". Both the Letter of Credit and
the Parental Guarantee must: (1) be made payable to the City; (2) require at least 60 days written notice to
- City uponi or • and (3) allow fori e draw by - City for• r. -
of any invoice by the due date or any other payment default by Customer. In the event the City applies all or
part of the Performance Assurance related to any late payment or non-payment by Customer, or any other
payment default by the Customer, the City may immediately request additional Performance Assurance from
Customer in order for the continuance of electric service by the City.
The Letter of Credit shall comply with Texas Business and Commerce Code §5,106 issued by a
bank or financial institution with a minimal credit rating of A- from either S&P or Fitch, or a
• t •• and that has a yLpsical location or address in the United
States
in which the Letter of Credit can be drawn, and that is otherwise acceptable to the City in its sole
discretion. The City reserves the right in its sole discretion to require an increase in the amount of
the Letter of Credit, including but not limited to an increase based on market volatility,
creditworthiness of • " previous payment defaults, or business historyof •
. rMile
below investment grade, Customer must replace the Parental Guarantee with a Letter of Credit
City reserves the right in its sole discretion to require an increasX,
in the amount of the Parental Guarantee, including but not limited to an increase based on market
volatility, creditworthiness of ♦ previousor business historyof e
Customer.
limitedH. EqWg�� Customers under this Rate Ordinance shall also be responsible for all the costs including but not
to the costr • •• • -rrManager
of Electric Utilities ("General Manager") or each of their respective designees, determines is needed,
including but not limited to advanced metering equipment, to manage the Customer's energy load and usage
to
ensure reliableto all customersof
Q__L_g_. Customer understands and agrees that it has no guarantee of an uninterrupted supply of
{.•wer� City shall have the right to curtail or • delivery of Y Customerr{ Y.
Forcecurtailment instructions from ERCOT as a result of imminent system reliability need; (ii) during periods of
- (defined during unplanned outages,i of o or
distribution facilities or other equipment, partial or complete forced outage, breakage of or damage to
machinery or equipment, or (iv) during planned outages as agreed by City and Customer ("Curtailment
Event"). "Force Majeure" means an event or circumstance which (i) prevents a party from performing its
Page 8 of 12
libligations under this Rate Ordinance, (ii) which event or circumstance is beyond the reasonable control of
such party, (iii) was not reasonably foreseeable by such party, or if reasonably foreseeable could not have
been overcome with the exercise of due diligence, (iv) is not the result of such Party's negligence or fault,
and (v) which by the exercise of due diligence, such Party is unable to overcome or avoid or cause to be
avoided. If Customer is notified of a Curtailment Event and fails to comply with the Curtailment Event
directives received from City, Customer shall be liable to City for any uplift charges, securitization charges,
penalties, fines or any other ERCOT charges related to a Curtailment Event imposed on City (directly or
indirectly) as a result of Customer's failure to comply with the Curtailment Event notice, which is in addition
to any and all costs and fees for the provision of electric service during the Curtailment Event under this Rate
Ordinance and —any and all related ERCOT fees, settlement costs, sub-QSE fees, ERCOT load ratio share
charges, ERCOT administration fees, Electric Reliability Organization fees, ERCOT uplifts to Load, ERCOT
miscellaneous invoices (collectively, "ERCOT Settlement Amounts"), and any other charges, fees and costs
assessed or implemented by any Governmental Authority. "Governmental Authority" means (i) any federal,
state, local, municipal, or other government or (ii) any other governmental, quasi -governmental, regulatory
or administrative agency, commission, or other authority (including the Texas Attorney General, PUCT,
ERCOT, Federal Energy Regulatory Commission, NERC, or Texas Reliability Entity) lawfully exercising or
entitled to exercise any administrative, executive, judicial, legislative, police, policy, regulatory, or taxing
authority or power. "PUCT" means the Public Utility Commission of Texas. City shall have the right, but
not the obligation, to disconnect the electricity supply to Customer to force compliance with the Curtailment
Event directives, subject to any shutdown requirements designed to protect the Customer Facilities or the
ERCOT grid. Subject to the aforementioned notice and shutdown requirements, City shall have no liability
for exercising such right, nor shall Customer be excused from any damages that may arise in the case that
City fails to do so. For purposes of clarity, all customers served by City are subject to Curtailment Events.
1 Yft� Load AggMfttt&k!h�� Prior to the commencement of service, Customer shall pay a non-
refundable account set-up fee in the amount of $25,645, which may be updated from time to time by the City,
for installation of ERCOT EPS meter(s) and any other initiation, installation, or other fees levied by ERCOT
or otherwise incurred by the City as a result of providing energy service to the Customer.
K. M_onthly Rate.
1. Customer Charge: $5,500-(�1115_,1,'1;11(4, per month
2. Energy Charge: $0.0117,0�41 per kWh
3. Demand Charge: $19.25-65 per kW per month subject to Billed Demand as outlined in Section 0
below.
L. kgwar)(o�AA �� The power cost adjustment charge under the above rate schedule shall be increas
or decreased to reflect the application of a power cost adjustment per kWh of energy used, calculated
accordance with Section 13.04.075. 1
M. Egugekgy��,. Rider. In addition to the charges identified in K and L, Customers shall pay the Energy R
Rider ($/kWh) ("ERR") for all energy consumed. The City Manager, General Manager or their respecti
designees are responsible for making periodic adjustments to the ERR, which will be based upon two Q
months of actual power supply costs and six (6) months of forecasted future costs to serve the customers.
` 11
the Very Large Commercial and Industrial Service class and the cumulative ERR account balance. Chang
to the ERR shall have the objective of maintaining a positive cumulative ERR account balance.
HINW1 Ili•ifflifliff! I . 1 0 . "i is
FERR = ([(ER + ERR) x TL]-HG(L - FHC — SMP —FL H - AS)+(TAB-AAB))/TL
Where:
Page 9 of 12
FERR = Future Energy Rate Rider rounded to the nearest $.0001 /kWh. In no event shall the FERR be less
than zero ($0)
ER = Energy Rate for VLC&I class ($0.5173/kW[i) — subject to revision by rate ordinance
ERR = Energy Rate Rider in effect for the historical load period
'En
TL = Total Load = i=1 Aggregate VLC&I Energy ink
1111 111 pill 1111111111ppill
iii III III III iii !I!!!! U III iii
Where -t = the g tV rtowth calculation neriod.
HG/L = Historical hedge gains or losses = Z
71MOSM
Hedge volume for hour i
I
FHC = Future Hedge Cost FHVi * FHPi
Where:
FHVi = Hedged volume in hour i
FHPi = Hedge price in hour i
x,n
Spot Market Purchases (historic an future) = Zi=l SMPi * LMPi
Where:
SMPi = spot market purchases in hour i (can be real-time LMP or day -ahead LP)
LMP means the Locational Marginal Price
Z
FL H =Future Load Hedges= 7 =,FLHi*FPi
Where°
AS = Ancillary Service Costs =Z7ASi * TU
Where:
costs for hour i for future load.
-M C 11plu
P11rues I" 1P
IMMINOTMEMM
Page 10 of 12
TAB = Target Account Balance — the targeted Energy Rate Rider account balance established by the City
Manager, General Manager or their respective designees to stabilize the cost of wholesale power to the
VLCI rate class.
AAB = Actual Account Balance — the net revenues from the collection of the Energy Rate Rider
The ERR (and the FERR above) may not be less than zero. The City Manager, General Manager or their
respective designees are responsible for making periodic adjustments to the ERR.
i.The measured maximum 15-minute (or 30-minute, as applicable) demand in kilowatts (kW)
recorded during the billing period, or
Billed Demand may be adjusted for power factor if the actual power factor falls below the threshold specified
in this tariff.
P. Transtilission Qeliver C ost A i ttrtcttt. The transmission delivery cost adjustment charge under this rate
schedule shall be increased or decreased to reflect the application of a transmission delivery cost adjustment
per kWh of energy used, calculated in accordance with Section 13.04.080.
Q. lini tturt l emand. The Minimum Demand shall be 80% of the Installed Capacity, or as otherwise provided
in the Electric Service Agreement between Customer and City.
R. tower Factor. If the Customer's power factor during a billing cycle is less than 0.95 lagging, the City may
adjust the Billed Demand (k) by applying a multiplier. This multiplier is calculated by dividing the target
power factor (0.95) by the Customer's actual power factor (which is less than 0.95). -The resulting ratio will
be multiplied by the Billed Demand for that billing cycle.
S. Prituar Volta •c iiscouttl.
ae
Applicable • large • - • f • -
r • •ltage ("Primary Voltage Customers").
Customers2. —Month V Demand Dis ntt tc. Primary Voltage demand rate will be "• d
(credited) 1
T. M . The monthly minimum bill amount related to any Customer whose load capacity is betwe
10 MW and less than 51 MW shall be an amount equal to the sum of the Customer Charge, Energy Char
Demand Charge, Power Cost Adjustment, Energy Rate Rider, Transmission Delivery Cost Adjustment, a]
any other authorized
Page 11 of 12
Sec. 13.0.050. Electric vehicle (EV) charger service.
A. Availability. Available to electric vehicle charging infrastructure providers whose design load or actual usage
exceeds 500 kW of peak demand, but does not exceed 2,000 kW of peak demand, within the City of
Georgetown electric service area and whose uses are not covered by a specific rate schedule. Companies
must share sub -metered data to qualify for this rate.
B. Net Monthly Rate.
1. Customer Charge: $3570.35 per month
2. Energy Charge: $0.4bY4,?,, 3- 057 per kWh
3. Demand Charge: $16.0G M per kW per month, **(Billed on greater of Actual demand OR 500 kW OR
80 percent of peak month demand over previous 12-month period). 15t month demand will be equal to
system design demand.
4. Minimum Bill: $ „ 5aW6 52 .;.fi5;per month.
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased or decreased to
reflect the application of a power cost adjustment per kWh of energy used, calculated in accordance with
Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule shall be increased or
decreased to reflect the application of a transmission delivery cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.080.
Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
Sec.13.04.055. Municipal.
A. Availability. Applicable to City -owned and operated facilities whose uses are not covered by a specific rate
schedule. Service rendered under this rate is subject to the City's Rules and Regulations.
B. Net Monthly Rate.
1. Customer Charge: $ 4 1134.77 per month
2. Energy Charge: $0. 0- 71.5per kWh
3. Minimum Bill: $-1 . , 1.34.i7 per month
C. Power Cost Adjustment. The PCA charge under the above rate schedule shall be increased or decreased to
reflect the application of a power cost adjustment per kWh of energy used, calculated in accordance with
Section 13.04.075.
D. Transmission Delivery Cost Adjustment. The TDCA charge under the above rate schedule shall be increased or
decreased to reflect the application of a transmission delivery cost adjustment per kWh of energy used,
calculated in accordance with Section 13.04.080.
E. Sales Taxes. Sales taxes, where applicable, will be charged to the consumer in addition to the above rates.
.�. Created: 2025-04-23 07:02:37 [EST]
(Supp. No.31, Update 1)
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