CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
16 Effective Date: January 1, 2026
6. Temporary Discontinuance of Service
Where the use of energy is seasonal or intermittent, no adjustments will be made for a temporary discontinuance of service. Any Customer, prior to resuming service within twelve (12) months after such service was discontinued, will be required to pay all charges which would have been billed if service had not been discontinued.
7. Customer-Owned Electrical Generating Facilities
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
8. Customer Responsibilities
The customer will be responsible for all costs associated with the primary point-of- delivery installation, including the metering and primary voltage physical disconnect necessary to isolate the customer's facilities from the utility's facilities.
The cust omer will be responsible to own, operate and maintain all electrical distribution facilities on the customer side of the primary point -of-delivery (typically established at the primary meter).
9. Contracts
An initial three -year facilities contract may be required where Applicant requires new or added serving capacity exceeding 2,000 kVA.
10. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], kilovar [kVa], etc.).
11. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
12. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
13. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
17 Effective Date: January 1, 2026
STREET LIGHTING
A. Applicability
Applicable to meter for the lighting of streets, and publicly -owned and publicly -operated automobile parking lots which are opened to the general public where the City owns and maintains the street lighting equipment and associated facilities included under this Schedule.
B. Territory
Within the entire territory served.
C. Rates
Light Emitting Diode (LED) Lamps – All Night Service
Street Lighting
Energy Charge - $/kWh/Lamp 0.066990.07282
Lamp Charge - $/Lamp/Month 2.50
Safety
Energy Charge - $/kWh/Lamp 0.066990.07282
D. Special Conditions
1. The Applicant shall install streetlights that will be served by the Utility. These streetlights must be installed in accordance with the Utility’s specifications and the developer will deed such facilities to the City.
2. Requirements and Restrictions
a. The Applicant for street light service shall specify the type of service, lamp size, and location of street lights.
b. Service shall not be furnished under this Schedule where location, mounting height, and/or other considerations are unacceptable to the Utility. c. The installation of street lighting equipment and facilities hereunder is contingent upon the utility obtaining easements, and rights of way, as may be required, satisfactory to the Utility for the required poles, lines, equipment, and facilities.
d. Should the Applicant not commence using the street lighting in a bona fide manner within ninety (90) days after date of completion and installation of a street light or street lighting system requested by the Applicant, the Utility will bill, and the Applicant shall pay, the applicable lamp charges(s).
3. Hours of Service
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
18 Effective Date: January 1, 2026
Under the Utility’s standard all night operating schedule, approximately 4,140 hours of service per year will be furnished.
Kilowatt hours for Lamp Type and Size: The kilowatt hours for lamp types and sizes served under this Schedule used to determine the Energy Charge are shown below:
Light Emitting Diode
(LED) Lamps
Lamp Watts
Including
Driver Loss
Lamp Watts
Including
Driver Loss
Mid-Point
Range
kWh per Lamp per
Month
All Night Service
0-5 2.50 0.9
5.01-10 7.50 2.6
10.01-15 12.50 4.3
15.01-20 17.50 6.0
20.01-25 22.50 7.8
25.01-30 27.50 9.5
30.01-35 32.50 11.2
35.01-40 37.50 12.9
40.01-45 42.50 14.7
45.01-50 47.50 16.4
50.01-55 52.50 18.1
55.01-60 57.50 19.8
60.01-65 62.50 21.6
65.01-70 67.50 23.3
70.01-75 72.50 25.0
75.01-80 77.50 26.7
80.01-85 82.50 28.5
85.01-90 87.50 30.2
90.01-95 92.50 31.9
95.01-100 97.50 33.6
100.01-105 102.50 35.4
105.01-110 107.50 37.1
110.01-115 112.50 38.8
115.01-120 117.50 40.5
120.01-125 122.50 42.3
125.01-130 127.50 44.0
130.01-135 132.50 45.7
135.01-140 137.50 47.4
140.01-145 142.50 49.2
145.01-150 147.50 50.9
150.01-155 152.50 52.6
155.01-160 157.50 54.3
160.01-165 162.50 56.1
165.01-170 167.50 57.8
170.01-175 172.50 59.5
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
19 Effective Date: January 1, 2026
4. Maintenance
The Utility shall exercise reasonable care and diligence in maintaining its street light facilities or Utility-owned attachments thereto. Where the Utility experiences, or expects to experience, maintenance costs exceeding its normal maintenance expense resulting from, but not limited to, vandalism, the Utility may require the customer to pay the excess maintenance expense.
5. Liability of the Utility
The Utility shall not, by taking action pursuant to its tariffs, be liable for any loss, damage, or injury, established or alleged, which may result, or be claimed to result, therefrom.
6. Removal, Relocation or Modification of Facilities
Where street lighting service and facilities are ordered removed by a customer, the customer shall pay to the Utility a nonrefundable amount equal to the total estimated cost installed less any Customer contribution, plus the estimated cost of removal less the estimated net salvage value of the facilities.
Where street lighting service and facilities were ordered removed by a Customer and such service and facilities, or their equivalent are ordered reinstalled within thirty-six (36) months from the date of the order to remove, the Customer shall pay to the Utility in advance of reinstallation a nonrefundable amount equal to the cost of removal of the prior facilities and the estimated cost of such reinstallation.
Where street lighting facilities are ordered modified and /or relocated by a Customer, the Customer shall pay to the Utility, in advance of such modification and/or relocation, a nonrefundable amount equal to the estimated cost of such modification and/or relocation. This includes facilities that now serve street light load only, but that may have been installed originally to serve other than street light load.
Utility-owned facilities removed or installed remain the sole property of the Utility.
7. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above.
8. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
9. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
10. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
20 Effective Date: January 1, 2026
TRAFFIC CONTROL
A. Applicability
Applicable to single and three -phase service for traffic directional signs or traffic signal systems located on streets, highways and other public thoroughfares and to railway crossing and track signals; for public thoroughfare lighting that is utilized twenty-four (24) hours per day or is not controlled by switching equipment, such as tunnel or underpass lighting; and, to public authorities for the illumination of bus stop shelters located in the dedicated road right -of-way where such service is combined with other traffic control service as defined above.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh 0.112980.11941
Customer Charge - $/Day 0.60
D. Special Conditions
1. Voltage
Service will be supplied at one (1) standard voltage not in excess of 240 volts or, at the option of the Utility, at 240/480 volts, three wire, single-phase.
2. Billing Calculation
A Customer’s bill is calculated according to the rate and conditions above.
3. Power Cost Adjustment Factor (PCAF)
The rate above is subject to an adjustment as provided in Rule 12, Section E.
4. Change of Law Adjustment Factor (CLAF)
The rate above is subject to an adjustment as provided in Rule 12, Section F.
5. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
21 Effective Date: January 1, 2026
OUTDOOR AREA LIGHTING
A. Applicability
Applicable to single -phase service for metered outdoor area lighting load, controlled for dusk to dawn operation and used for purposes other than street and highway lighting such as, but not limited to parking lots, pedestrian walkways, billboards, building exteriors, security, sports and recreation areas, monuments, decorative areas, and bus shelters.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh/Meter/Month 0.064290.06923
Customer Charge- $/Meter/Month 15.25
D. Special Conditions
1. Voltage
Service will be provided at one (1) standard voltage.
2. Three-Phase Service
Where, in the sole opinion of the Utility, it is impractical to provide single -phase service under this Schedule, three-phase service will be provided.
3. Separate Point of Delivery
When requested by the Applicant or Customer, and agreed upon by the Utility, an additional Point of Delivery may be provided, separate from any other Point of Delivery provided under any other applicable Rate Schedule. Customers so served shall not be per mitted to have an electrical interconnection beyond the Utility’s Point of Delivery between the separately metered loads except upon written approval of the Utility.
A change from this Schedule to any other Rate Schedule will be permitted if the additional Point of Delivery is removed. Any such removal shall be at the Customer's expense.
Any rearrangement of facilities required to provide the additional Point of Delivery shall be at the expense of the requesting Applicant or Customer.
4. Controlled Operation
Service under this Schedule requires the control of lamps in a manner acceptable to the Utility so that lamps will not be lighted daily from dawn to dusk. Customer shall install, own, operate, and maintain the control device. The Utility shall have
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
22 Effective Date: January 1, 2026
the right to periodically inspect the control device to ensure its correct operation and maintenance.
5. Distribution Line Extension
Distribution Line Extensions to reach an outdoor area light or area lighting system shall be in accordance with Rule 15.
6. Services
Services shall be installed and maintained as provided in Rule 16.
7. Incidental Loads
Incidental, non-lighting loads may be served under this Schedule only where such Connected Loads do not exceed fifteen percent (15) of the Customer’s total Connected Load. Incidental Loads must also be controlled for dusk to dawn operation exclusively.
8. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], etc.).
9. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
10. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
11. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
23 Effective Date: January 1, 2026
IRRIGATION SYSTEMS
A. Applicability
Applicable where the Utility determines that 100% of the customer’s electrical usage is for limited irrigation service except for the Customer whose monthly Maximum Demand, in the opinion of the Utility, is expected to exceed 20 kW or has exceeded 20 kW in any three (3) months during the preceding twelve (12) mo nths is ineligible for service under this Schedule. Effective with the date of ineligibility of any Customer served under this Schedule, the Customer’s account shall be transferred to another applicable Rate Schedule.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh 0.184590.18142
Customer Charge - $/Day 0.757000.80
D. Special Condition
1. Voltage
Service will be supplied at one (1) standard voltage not in excess of 240 volts or, at the option of the Utility, at 240/480 volts, three wire, single-phase.
2. Billing Calculation
A Customer’s bill is calculated according to the rate and conditions above.
3. Power Cost Adjustment Factor (PCAF)
The rate above is subject to an adjustment as provided in Rule 12, Section E.
4. Change of Law Adjustment Factor (CLAF)
The rate above is subject to an adjustment as provided in Rule 12, Section F.
5. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
24 Effective Date: January 1, 2026
WIRELESS TECHNOLOGY
A. Applicability
Applicable to single-phase service for wireless technology industries that require electric service to operate radio repeaters or similar devices (wireless communication devices) that are mounted on existing City facilities, or other facilities approved by the Utility and are unmetered. This Schedule excludes Wi-Fi devices on “looped” (served by 120/240 volts) streetlight facilities. Customers must execute an application/contract with the Utility for service under this Schedule and must execute an applicable agreement when devices are attached to City facilities. The monthly kilowatt -hour (kWh) usage of each device shall not exceed 500 kWh. Effective with the date of ineligibility of any Customer served under this Schedule, the Customer's account shall be transferred to another applicable Rate Schedule. If the Customer’s account cannot be transferred to another applicable Rate Schedule, the account will be closed, the Utility’s service will be removed, and the Customer must remove its device and equipment form the applicable City facility.
B. Territory
Within the entire territory served
C. Rates
Fixed Energy Charge - $/Device/Month 61.20
Customer Charge - $/Month 17.2918.52
Inspection Charge - $/Device/Month 12.60
Three-Phase Service - $/Day 0.03
Initialization of Service Charge 6.79
D. Special Conditions
1. Contract
An approved City contract is required for service under this Rate Schedule.
2. Voltage
Service will be supplied at one (1) standard voltage not in excess of 240 volts.
3. Three-Phase Service
Where the Utility provides three-phase service, the billing will be increased by the amount shown in the Rates section above.
4. Maximum Wattage
The maximum watts/connected load/name plate is 746 watts.
5. Installation
The device(s) shall be installed on City facilities or other facilities approved by the Utility. When the devices are installed on City facilities, the installation and
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
25 Effective Date: January 1, 2026
removal of such device(s) will be performed by the Customer, and at the Customer’s expense. Device installation shall not be performed under this Rate Schedule, where location, mounting height, and/or other considerations are not acceptable to the Utility . Unless approved by the Utility, all wireless communication devices must be visible to the Utility.
7. Modification of Facilities
No modifications can be made to the Customer -owned wireless communications devices unless approved by the Utility. Where the Customer requests a modification of City facilities, and such modifications are acceptable to the City, the City will perform the requested modifications at the Customer’s expense.
8. Maintenance
The Utility shall exercise reasonable care and diligence in maintaining its facilities.
Upon installation of the device(s), where the Utility experiences, or expects to experience, maintenance costs exceeding its normal maintenance expense resulting from, but not limited to, vandalism, the Utility may require the Customer to pay the excess maintenance expense.
9. Liability of the Utility
The Utility shall not, by taking action pursuant to its tariffs, be liable for any loss, damage, or injury, established or alleged, which may result, or be claimed to result, there from.
10. Initialization of Service Charge
A one-time charge, as shown in the Rates section of this Rate Schedule, is applied to each service account provided service under this Rate Schedule to recover the costs of a lock and spare fuse which are required with the initialization of service.
11. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
12. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
13. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
26 Effective Date: January 1, 2026
NET ENERGY METERING
A. Applicability
Applicable to a customer who operates a renewable electrical generation facility that is located on the customer’s premises with a capacity of not more than 1 MW that is interconnected and operates in parallel with the City’s electric system, intended prim arily to offset part or all of the customer’s own electrical requirements, and meets all the applicable safety and performance standards.
B. Territory
Within the entire territory served.
C. Net Surplus Compensation Rate
For customer accounts established on or after December 1, 2018: The net surplus compensation rate shall be $0.0500 per kWh applied to any net surplus energy remaining at the end of the customer’s twelve (12) monthly billing period (“relevant period”).
Grandfathered Provision: For customer accounts established before December 1, 2018:
The net surplus compensation rate shall be equivalent to the highest hourly rate that was charged for consumption in their OAT during the year prior to the Customer’s Annua l Billing Date. This provision will remain in effect for fifteen (15) years from the Customer’s original year in which the generating facility was interconnected to RCMU’s grid. After that period expires, the Customer will receive the current net surplus compensation that is being offered at that time.
D. Rates
1. All rates charged under this schedule will be in accordance with the Eligible Customer-Generator’s otherwise applicable tariff (OAT) or rate schedule. An Eligible Customer -Generator served under this schedule is responsible for all charges in its OA T including the monthly or annual minimum charges (including service, customer, reliability and demand charges, when applicable) regardless of the Customer’s monthly or annual net generation.
Eligible Customers under this schedule are subject to any new or additional charge(s) that may be imposed by the Utility on the other customer in the rate class to which Customer would otherwise be assigned.
2. As determined in each billing period, when a customer consumes more energy than generated at the premises (net consumer), the net consumed energy will be used in the calculation of all applicable energy charges, calculated by multiplying the net amount consumed by the applicable energy rate components of the customer’s OAT.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
27 Effective Date: January 1, 2026
3. As determined in each billing period, when a customer generates more energy than is consumed by the customer (net generator), the resulting net produced energy will be calculated by multiplying the net produced kWh by the applicable energy rate component of the Customer’s OAT (including TOU periods) and be a credit on the bill. Any net kilowatt -hours of production credit that exceeds the net consumed energy, will be carried forward into the next billing period.
If the Customer’s OAT includes “time of use” (TOU) rates, any net energy consumed monthly shall be calculated according to the terms of the OAT. When the customer is a net generator during any TOU period, the net kilowatt -hours generated shall be valued at the same price per kilowatt -hour as the Utility would charge during that same TOU period.
4. Customers who are Net Surplus Electricity producers at the Customer’s Annual True-Up Date, may elect to either carry over annual Net Surplus Energy production (in kilowatt hours) as a credit that will be applied to kilowatt hours consumed by the Customer or Customer may elect to receive payment to cash out the remaining Net Surplus Energy.
D. Special Condition
1. An executed Net Energy Metering and Generating Facility Interconnection Agreement is required prior to receiving service under this Schedule.
2. Metering Requirements: If the customer’s existing meter is not capable of measuring the flow of energy in two directions, an appropriate meter shall be provided at the expense of the customer. The City may elect to install an additional meter or meter s, at the City’s expense to provide the information necessary to accurately bill or credit the customer.
3. To be eligible for service under this Schedule, the customer’s generating facilities must be sized to offset part or all of the customer’s own electrical requirements and cannot be oversized. This means that the estimated output of the generating facility, using the CEC -AC nameplate rating for inverter -based generating facilities must not exceed the customer’s previous annual usage in kWh.
4. A new customer of record who owns, leases, or rents a premise that includes an existing generating facility with a capacity under 30 kW that was approved by RCMU for operation prior to the new customer moving in and/or taking electric service with RCMU will take service under this Tariff as long as the requirements of this Tariff are met and will not have to sign a new Interconnection Agreement.
This provision also applies to premises where the developer/contractor establishes the interconnection.
A new customer of record who owns, leases, or rents a premise that includes an existing generating facility with a capacity over 30 kW that was approved by RCMU for operation prior to the new customer moving in and/or taking electric service with RCMU will take service under this Tariff and will need to sign a new Interconnection Agreement.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
28 Effective Date: January 1, 2026
5. RCMU shall retain any net surplus energy generated by the NEM Customer including any associated environmental attributes or renewable energy credits (RECs).
6. Net Metering Aggregation (NMA): Customers served under this Tariff with a Generating Facility on a property owned by the Customer, may elect to aggregate electric services to additional properties that are solely owned by the Customer and are located on parcels adjacent or contiguous to the Generating Facility. Generation not used where the Generating Facility is located, is transferred to adjacent properties and equally distributed to the other properties by a percentage determined upon entering into t he Interconnection Agreement. NMA does not allow for Net Surplus Compensation for excess generation.
E. Billing
1. City shall provide all customers served under this Schedule with net energy consumption information and/or net energy export information with each monthly bill.
2. Customers served under this Schedule shall pay both energy and non -energy charges on a monthly basis, in accordance with the customer’s OAT except as otherwise allowed by State law. The value of net energy production will be used to offset only energy related charges in subsequent billing periods.
F. Definitions
1. Net energy metering measures the difference between the electricity supplied through the electric grid and the electricity generated on the customer’s premises and fed back to the electric grid over a Twelve-Month Period.
2. Otherwise Applicable Tariff (OAT) is the customer’s regularly filed rate schedule under which service is rendered.
3. Net Surplus Electricity is the electricity generated by an eligible customer - generator measured in kilowatt hours over a 12 -month period that exceeds the amount of electricity consumed by that eligible customer-generator.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
29 Effective Date: January 1, 2026
ECONOMIC DEVELOPMENT
A. Applicability
Commercial or industrial end -use Customers that would otherwise receive service under the Large Commercial or Large Industrial Electric Rate Schedule and meet certain criteria as established and adopted by resolution of the City Council of the City of Ranc ho Cucamonga may take advantage of the Economic Development (ED) rate as a New Customer or Expanded Load Customer. This ED rate is applicable to all or part of the services provided to New Customers and Expanded Load Customers, as such terms are defined herein.
1. A New Customer shall be a Customer seeking to locate a new business or relocate an existing business (not currently located within the territory served by the Rancho Cucamonga Municipal Utility (RCMU)) within RCMU’s service territory. a. A New Customer shall meet both of the following criteria in order to qualify for Schedule ED:
i. Projected minimum monthly electric demand of at least 200 kW. ii. Job Creation
1. Tier 1 Discount Rate 100 – 249 jobs
2. Tier 2 Discount Rate 250 – 500 jobs
3. Tier 3 Discount Rate greater than 500 jobs
2. An Expanded Load Customer shall be an existing RCMU Large Commercial or Large Industrial customer that is adding new load to RCMU by a minimum monthly electric demand of 200 kW based upon the Customer’s past electrical demand as determined by RCMU. The expanded load can be at the customer’s current site, or at a new site within the RCMU servic e territory. The Tier 1 ED rate will only be applied to the expanded load as determined in Section 6 below.
B. Territory
Within the entire territory served.
C. Character of Service
The service provided hereunder shall be alternating current with regulated frequency of 60 hertz, three-phase, or a combination single and three-phase served through one meter, at a standard voltage specified by RCMU. To be eligible to participate all customers must have a demand meter.
D. Rates
Except as provided herein, or in the Economic Development Rate Agreement, all charges and provisions of the Customer’s otherwise applicable rate schedule shall apply. The applicable Energy Charge and Demand Charge under the Customer’s otherwise applicable rate schedule will be reduced as follows:
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
30 Effective Date: January 1, 2026
Tier 1 Tier 2 Tier 3
Years 1 - 2 20% 20% 20%
Years 3 - 4 15% 17% 20%
Year 5 10% 12% 15%
E. Special Conditions
1. Term: Economic Development Rate Agreements entered into under this Schedule shall be for a single five-year term.
2. Approval: Application of this Rate Schedule shall be subject to the approval of the City Manager or his/her designee, based on meeting the eligibility criteria outlined herein.
3. Agreement: The Customer must sign a standard Rancho Cucamonga Economic Development Rate Agreement in order for the rates under this Schedule to be applicable. In addition to the other terms of this Schedule, the Economic Development Rate Agreement shall require th e Customer to reimburse Rancho Cucamonga for all rate reductions received under this Schedule, if the Customer fails to maintain the required minimum load during the five -year term of the Agreement.
4. Minimum Load: Customers qualifying under this Schedule as a New Customer with a projected minimum monthly electric demand of at least 200 kW or as an Expanded Load Customer under Applicability Sections 1 and 2 above, respectively, must agree to maintain a minimum lev el of load for five years from the date service is first rendered under this Schedule and to document compliance with all applicable requirements, as set forth in the Economic Development Rate Agreement.
5. Job Creation / Retention : Customers qualifying under this Schedule as a New Customer with a projected minimum monthly electric demand of at least 200 kW under Applicability Section 1a (ii), respectively, must agree to create and retain a minimum level of full -time equivalent jobs for five years from the date service is first rendered under this Schedule and to document compliance with all applicable requirements, as set forth in the Economic Development Rate Agreement.
6. Base Period Usage : Base Period Usage shall be established and agreed to in the Economic Development Rate Agreement for Expanded Load Customers. Base Period Usage shall be the average monthly energy use and demand for the Customer during the last three years of service to the Customer, from the date ending the last payment period before the date of the Agreement. Expanded Load qualifying for the rate under this Schedule shall be measured as the difference between the new monthly, metered documented energy use and demand, and the Base Period Usage.
7. State Mandated Public Purpose Program Charge: All bills rendered under this Schedule shall be subject to the Public Purpose Program Charge as established by the City Council.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
31 Effective Date: January 1, 2026
8. Miscellaneous Fees and Charges : Rates charged pursuant to this Schedule shall be subject to any Energy Users Taxes, Utility Users Taxes, and any other governmental taxes, duties, or fees which are applicable to Electric Service provided to Customer by the City of Rancho Cucamonga. Rates are also subject to adjustment, as established by the City of Rancho Cucamonga’s City Council, in its sole discretion, in response to federal or state climate change laws, renewable portfolio standard or other mandated legis lation. These adjustments may include but are not limited to charges to mitigate the impacts of greenhouse gas emissions or “green power” premiums.
9. Expanded Load: Expanded Load customers applying for this rate must demonstrate to the satisfaction of the Utility that the expanded load is new to the Rancho Cucamonga Municipal Utility.
10. Effective Date: The effective date of the Economic Development Rate Agreement shall commence within 12 months from the date of the City’s approval, or the Agreement becomes null and void. The Agreement becomes effective upon execution by the parties, and the Economic De velopment Rate commences upon written notice by Customer and coincides with the Customer’s normal billing cycle.
11. Reapplication: Customers who have received service under the Economic Development Rate are eligible to reapply for the rate as an Expanded Load Customer, if they meet the criteria therefore.
12. Restrictions: Residential customers and federal, state or local government agencies are not eligible to apply for service under this Schedule.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
32 Effective Date: January 1, 2026
STANDBY DEMAND CAPACITY RESERVATION CHARGE
(SELF GENERATION)
A. Applicability
Applicable to Large Commercial and Large Industrial customers who operates a non -net metered, non -utility generating facility rated at 1000 kW or less, interconnected on the Customer’s premises and operates in parallel with the City’s electric system. The generating facility is intended primarily to offset part or all of the customer’s own electrical requirements and meets all the applicable safety and performance standards.
Standby service customers have unique electric demands, due to their on -site generation assets, that are often quite different from those of full requirement customers. These customers pay standby rates so that they may, in the event of a planned or unplanned outage of their non-utility generating system, take service from the City electric system. The City bears an “obligation to serve” and must configure their system to allow every customer reliable access to the grid. The standby charge is designed to re cover the costs of transmission and distribution facilities, as well as substation and transformers dedicated to the customer’s use that do not vary with usage in maintaining sufficient capacity (through operating reserves) in order to serve an unplanned o utage, even if such an outage never occurs. The standby charge also includes appropriate service voltage level distinctions:
secondary and primary.
B. Territory
The entire territory served.
C. Rates
1. Rates for this service shall be the same as for the schedule under which the customer’s otherwise applicable rate schedule shall apply.
2. Standby Demand Capacity Reservation Charge (CRC): A CRC shall be a flat $/kW amount applied to the Standby Demand in kW, which represents the entire reserved capacity needed for the City to serve the self -generation customer’s load, which would have been regularly served by the customer’s generating facility when such facility experiences a partial or complete outage. The level of Standby Demand shall be provided by the customer and shall not exceed the nameplate capacity of the customer’s generating facility.
Standby Charge – Secondary ($/kW) Standby Charge – Primary ($/kW) $8.61 $7.61
3. Demand Charge: As determined in each billing period, a Standby Service customer’s billing demand shall be the kilowatts of Maximum Demand indicated or recorded by instruments, determined to the nearest kW of the absolute net power
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that the customer received from the City’s electric system. The Demand Charge for each time period shall be based on the Maximum Demand for that time period occurring during the respective monthly billing period.
4. Energy Charge: As determined in each billing period, when a Standby Service customer consumes more energy than generated at the premises, the net consumed energy will be used in the calculation of all applicable energy charges. All Energy shall be billed in accordance with the customer’s Otherwise Applicable Tariff rate schedule which wou ld otherwise apply if the customer had no generating equipment.
5. Other charges: All other specific rate components, including the Power Factor Adjustment Charge, Customer Charge and the State Electric SurTax will not vary based on registered usage or demand of the customer’s generating facility.
D. Special Conditions
1. Contract Required - Customer shall sign an Interconnection Agreement contract for this service, which shall state the number of kW of standby capacity required. "Standby capacity" shall not exceed the nameplate rating of the customer’s generating equipment.
2. Metering Requirements - If the customer’s existing meter is not capable of measuring the flow of energy in two directions, an appropriate meter shall be provided at the expense of the customer. The City may elect to install an additional meter or meters, at the customer’s expense to provide the information necessary to accurately bill or credit the customer.
3. The CRC tariff is only applicable to Standby Service customers who require electric capacity and energy supplied by the City on a regular basis to supplement the Customer’s power requirement in addition to that ordinarily supplied by the on-site non-utility generation facilities. If a customer has a planned generator outage with prior notification given to RCMU for an entire billing period the standby charge will not be applicable.
4. Customers exempted from the CRC tariff:
(a) Customers with backup on -site generation that is used exclusively when service from the utility is not available in the event of an interruption in utility service and which are not used to offset Customer electricity purchases. (b) The applicability of these exemptions shall be determined at the discretion of the Utilities Manager.
5. Standby Demand in kW represents the entire reserved capacity needed for the City to serve the customer’s load, regularly served by the customer’s generating facility when such facility experiences a partial or complete outage. The level of Standby Demand, which shall not exceed the nameplate capacity of the customer’s
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generating facility, is initially designated by the customer and is set forth in the generation interconnection agreement. Once a customer’s designated Standby Demand has been set, it shall remain at such level for a minimum of 12 months unless, in the Cit y’s determination, the Standby Demand needs to be adjusted to more accurately represent the customer’s actual reserve capacity needs. Upon the City’s determination that the customer’s designated Standby Demand does not reflect the actual level of needed re serve capacity, over any 15 -minute period or through on-site verification, the City shall adjust the Standby Demand to reflect the actual needed reserve capacity. When the Standby Demand is adjusted by the City as provided above, a qualified change in the Standby Demand shall not be made for 12 months from the last adjustment. The customer is responsible for notifying the City of permanent or material changes in their generation facilities (size, type and operations) for future adjustments to the Standby Demand.
6. Diversity Factor - a statistical assumption that a certain percentage of standby load will be utilizing substation and distribution service between each class’ peak demand and the system peak demand. This factor was determined using the diversity factors calculated in the ut ility’s most recent cost of service study and is embedded in the current CRC tariff. A percentage difference was identified as the diversity factor and the distribution and substation portion of the standby rates were reduced accordingly reflecting a reduction in those infrastructure requirements.
E. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges on the customer’s applicable nameplate generation capacity for the generating unit at the customer’s facility. All other usage provided by RCMU will be based on the applicable rate tariff, including any riders or additional charges.
Customers served under this Schedule shall pay both energy and non -energy charges on a monthly basis, in accordance with the customer’s Otherwise Applicable Tariff except as otherwise allowed by State law.
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ELECTRIC VEHICLE CHARGING
A. Applicability
Applicable solely for the charging of electric vehicles, on a premises or public right of way where a separate RCMU meter to serve electric vehicle (EV) charging facilities is requested.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh/Meter/Month
Summer Season – On-Peak 0.23654
Mid-Peak 0.103950.10738
Off-Peak 0.04273
Winter Season – On-Peak 0.087860.09129
Mid-Peak 0.07932
Off-Peak 0.049830.05326
Customer Charge - $/Meter/Month Under 20 kW 30.00 Over 20 kW 185.00
Demand Charge - $/kW of Billing Demand/Meter/Month
Facilities Related 12.00
Power Factor Adjustment - $/KVA 0.30
D. Special Conditions
1. Time periods are defined as follows:
On-Peak: Noon to 6:00 p.m. weekdays except holidays
Mid-Peak: 8:00 a.m. to noon and 6:00 p.m. to 11:00 p.m. weekdays except holidays.
Off-Peak: All other hours.
Holidays are New Year’s Day (January 1), Washington’s Birthday (third Monday in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Veteran’s Day (November 11), Thanksgiving Day (fourth Thursday in November), and Christmas (December 25).
When any holiday listed above falls on Sunday, the following Monday will be recognized as an off-peak period. No change will be made for holidays falling on Saturday.
The Summer Season shall commence at 12:00 a.m. on June 1 st and continue until 12:00 a.m. on October 1 st of each year. The Winter Season shall commence at 12:00 a.m. on October 1st of each year and continue until 12:00 a.m. on June 1st of
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the following year. A pro rata computation will be made for seasonal billing purposes.
2. Voltage Service will be supplied at one (1) standard voltage.
3. Metering
Only EV charging facilities and related equipment shall be separately metered and served under this Schedule. Where RCMU determines that the operation of the EV charging facilities may interfere with service to that customer or other customers, RCMU will install a load management device at customer’s expense to control when EV charging will occur. For purposes of monitoring customer load, RCMU may install at its expense, load research metering. The customer shall provide, at no expense to RCMU, a suitable location for meters and associated equipment.
4. Billing Demand
The Billing Demand shall be the kilowatts (kW) of Maximum Demand, determined to the nearest kW. The Demand Charge may include the following billing components. The Time Related Component shall be for the kilowatts of Maximum Demand recorded during (or es tablished for) the monthly billing period. The Facilities Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period. However, when the Utility determines the Customer's Meter will recor d little or no energy use for extended periods of time or when the Customer's Meter has not recorded a Maximum Demand in the preceding eleven (11) months, the Facilities Related Component of the Demand Charge may be established at fifty percent (50%) of the Customer's Connected Load.
5. Maximum Demand
The Maximum Demand in any month shall be the measured maximum kilowatt input, indicated or recorded by instruments, during any 15-minute metered interval in the month.
6. Power Factor Adjustment
The Customer’s bill will be increased each month for power factor by the amount shown in the Rates section above for service metered and delivered at the applicable voltage level, based on the per kilovar of maximum reactive demand imposed by the Utility.
The maximum reactive demand shall be the highest measured maximum average kilovar demand indicated or recorded by metering during any 15-minute interval in the month. The kilovars shall be determined to the nearest unit. A device will be installed on each kilovar meter to prevent reverse operation of the meter.
7. Interconnection
Customers taking service under this Schedule shall have no electrical interconnection beyond the RCMU’s Point of Delivery between electrical loads eligible for service under this Schedule and any other electrical loads.
8. Temporary Discontinuance of Service.
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Where the use of energy is seasonal or intermittent, no adjustments will be made for a temporary discontinuance of service. Any Customer resuming service within twelve (12) months after such service was discontinued will be required to pay all charges which would have been billed if service had not been discontinued.
9. Customer-Owned Electrical Generating Facilities.
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
10. Billing Calculation.
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], kilovar [kVa], etc.).
11. Power Cost Adjustment Factor (PCAF).
The rates above are subject to an adjustment as provided in Rule 12, Section E.
12. Change of Law Adjustment Factor (CLAF).
The rates above are subject to an adjustment as provided in Rule 12, Section F.
12. State Mandated Public Purpose Programs Charge.
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
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POWER COST ADJUSTMENT FACTOR
A. Applicability
The Power Cost Adjustment Factor (PCAF) is a charge per kWh which is used to adjust the Utility’s electric rates for the actual cost of purchasing and generating electric power and energy to service the Utility’s customers and to minimize fluctuations in rates.
The energy charge per kWh in each Rate Schedule recovers the costs of purchasing and delivering power and energy from all suppliers of power and energy, other suppliers and the cost of power from the Utility’s owned generating resources.
B. Territory
Within the entire territory served.
C. Calculation
The PCAF will be calculated using the most recent six (6) month’s actual power cost and applied to each customer’s following monthly billed energy (kWh).
The Adjustment shall be calculated according to the following formula:
PCAF = ((P/S) + L) – B
P = Wholesale power supplier cost*
S = Number of kilowatt-hours sold during the same time period as factor “P” L = System annual average losses
B = The average cost of power per kilowatt -hour sold and recovered through base retail rates
*Power Supplier Costs shall include all costs of power supply including but not limited to costs of power production, power purchases, transmission and wheeling payments, losses, CAISO, capacity, REC’s, environmental allowances and scheduling and dispatching.
D. Special Conditions
1. The PCAF, which may be either positive or negative, will be reviewed and revised monthly to reflect actual changes.
2. Should the PCAF ever exceed the base retail rate, the Utility will cap the PCAF for the billing month at the base retail rate and charge each customer the difference between the PCAF and the base retail rate in the next available subsequent billing month.
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SERVICE ESTABLISHMENT CHARGE
A. Applicability
Applicable to General Service and Domestic Service customers.
B. Territory
Within the entire territory served.
C. Rates
For each establishment of electric service…………… $15.00
D. Special Conditions
1. The service establishment charge provided for herein is in addition to the charges calculated in accordance with the applicable schedule and may be made each time an account is established. As used herein, establishment means each time an account is opened, including a turn on of electric service or a change of name which requires a meter reading.
2. In case the customer requests that electric service be established on the day of his request or outside of regular hours, an additional charge of $11.00 may be made.
Table of Contents
Electric Rates and Tariffs
RESIDENTIAL 1
SMALL COMMERCIAL 4
MEDIUM COMMERCIAL 6
MEDIUM COMMERCIAL (TIME-OF-USE) 9
LARGE COMMERCIAL 12
LARGE INDUSTRIAL 15
STREET LIGHTING 18
TRAFFIC CONTROL 21
OUTDOOR AREA LIGHTING 22
IRRIGATION SYSTEMS 24
WIRELESS TECHNOLOGY 25
NET ENERGY METERING 27
ECONOMIC DEVELOPMENT 30
STANDBY DEMAND CHARGE 33
ELECTRIC VEHICLE CHARGING 36
POWER COST ADJUSTMENT FACTOR 38
SERVICE ESTABLISHMENT CHARGE 39
ATTACHMENT 3
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RESIDENTIAL
A. Applicability
Applicable to individual accommodations devoted primarily to domestic purposes where service includes lighting, appliances, heating, cooking and power consuming appliances or combination thereof in a residential accommodation.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge $/kWh/Meter
Summer and Winter
Tier 1 – Baseline Quantities 0.11910
Tier 2 – 101% to 130% of Baseline 0.14000
Tier 3 – Over 131% of Baseline 0.25686
Customer Charge - $/Meter/Day
Single-Family Residence 0.400.52
Multi-Family Residence 0.370.49
D. Special Conditions
1. Summer and Winter Seasons are defined as follows:
The Summer Season shall commence at 12:00 a.m. on June 1st and continue until 12:00 a.m. on October 1st of each year. The Winter Season shall commence at 12:00 a.m. on October 1st of each year and continue until 12:00 a.m. on June 1st of the following year . A pro rata computation will be made for seasonal billing purposes.
2. Customer Charge: For purposes of applying the Customer Charge, the following definitions shall be used:
Single-Family Residence: A building of single occupancy, which does not share common walls, floors, or ceiling with other residential dwelling units.
Multi-Family Residence: Apartments, mobile homes, condominiums, townhouses or a building of multiple occupancy which shares common walls and/or floors and ceilings with other residential dwelling units.
3. Voltage. Service will be supplied at one (1) standard voltage.
4. Baseline Quantities: The residential allocation shall be 16.1 kWhs per day in Summer Season and 10.6 kWhs per day in the Winter Season.
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5. Customer-Owned Electrical Generating Facilities.
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
6. Medical Support Assistance
Eligible customers under this schedule upon application and certification from a medical doctor shall receive a monthly discount to assist customers with doctor - prescribed life support equipment. To qualify, a customer must submit an application and satisf actory proof that a full -time occupant of the customer’s residence requires a life support device. A qualifying life support device may be any one of the following or such other equipment as the Utility may deem eligible:
aerosol tents, apnea monitors, co mpressors or concentrators, electrostatic or ultrasonic nebulizers, electric nerve stimulators, hemodialysis machines, kidney dialysis machines, intermittent positive pressure breathing machines, iron lungs, pressure pads, pressure pumps, respirators, or s uction machines. Customers must reapply annually to demonstrate eligibility for the discount.
The monthly discount applies to energy charges only. All other charges and taxes are calculated at the standard rates. Program qualifications and rules are subject to change and are based on funding availability. In the event the Utility becomes aware of any false or fraudulent statements or information submitted in writing or verbally by the Customer, the Utility reserves the right to back bill the Customer for services rendered under this program.
7. Low Income Assistance
A low -income assistance program is available under this schedule for income qualified customers. To be considered for this discount, an application must be filled out with supporting documentation of proof of income. Total combined gross annual household income, both taxable and nontaxable, must meet the current income levels of the San Bernardino County (Very Low) Income Limits Documentation System. Customers must reapply annually to demonstrate eligibility for the discount.
The monthly discount applies to energy charges only. All other charges and taxes are calculated at the standard rates. Program qualifications and rules are subject to change and are based on funding availability. In the event the Utility becomes aware of any false or fraudulent statements or information submitted in writing or verbally by the Customer, the Utility reserves the right to back bill the Customer for services rendered under this program.
8. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh]).
9. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
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10. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
11. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
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SMALL COMMERCIAL
A. Applicability
Applicable to single and three -phase general service including lighting and power Customers, except for the Customer whose monthly Maximum Demand, in the opinion of the Utility, is expected to exceed 20 kW or has exceeded 20 kW in any three (3) months during the preceding twelve (12) months is ineligible for service under this Schedule.
Effective with the date of ineligibility of any Customer served under this Schedule, the Customer's account shall be transferred to another applicable Rate Schedule.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge $/kWh/Meter/Month
Summer 0.189070.19053
Winter 0.131150.13261
Customer Charge- $/Meter/Day
Single Phase 1.101.20
Three Phase 1.251.35
D. Special Conditions
1. Summer and Winter Seasons are defined as follows:
The Summer Season shall commence at 12:00 a.m. on June 1 st and continue until 12:00 a.m. on October 1 st of each year. The Winter Season shall commence at 12:00 a.m. on October 1st of each year and continue until 12:00 a.m. on June 1st of the following year. A pro rata computation will be made for seasonal billing purposes.
2. Voltage. Service will be supplied at one (1) standard voltage
3. Temporary Discontinuance of Service
Where the use of energy is seasonal or intermittent, no adjustments will be made for a temporary discontinuance of service. Any Customer, prior to resuming service within twelve (12) months after such service was discontinued, will be required to pay all charges which would have been billed if service had not been discontinued.
4. Customer-Owned Electrical Generating Facilities
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
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5. Installation of Demand Meters
Where a Customer's usage exceeds an average of 4,500 kWh per month in the preceding 12 -month period, the Utility may, at its sole option, install a demand Meter on the account at the Utility’s expense.
6. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], etc.).
7. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
8. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
9. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
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6 Effective Date: January 1, 2027
MEDIUM COMMERCIAL
A. Applicability
Applicable to single and three -phase service including lighting and power Customers whose monthly Maximum Demand registers, or in the opinion of the Utility is expected to register, above 20 kW and below 200 kW. The Customer whose monthly Maximum Demand, in the opinion of the Utility, is expected to reach 200 kW or has reached 200 kW for any three (3) months during the preceding twelve (12) months is ineligible for service under this Schedule. Effective with the date of ineligibility, such Customer’s account shall be transferred to another applicable Rate Schedule. Further, any Customer served under this Schedule whose monthly Maximum Demand has registered 20 kW or less for twelve (12) consecutive months is eligible for service under another applicable Rate Schedule.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh/Meter/Month
Summer Season 0.086470.08941
Winter Season 0.070130.07307
Customer Charge - $/Meter/Month 145.00
Demand Charge - $/kW of Billing Demand/Meter/Month
Facilities Related 14.00
Time Related (Summer) 16.50
D. Special Conditions
1. Summer and Winter Seasons are defined as follows:
The Summer Season shall commence at 12:00 a.m. on June 1 st and continue until 12:00 a.m. on October 1 st of each year. The Winter Season shall commence at 12:00 a.m. on October 1st of each year and continue until 12:00 a.m. on June 1st of the following year. A pro rata computation will be made for seasonal billing purposes.
2. 3. Voltage
Service will be supplied at one (1) standard voltage.
4. Billing Demand
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The Billing Demand shall be the kilowatts of Maximum Demand, determined to the nearest kW. The Demand Charge shall include the following billing components. The Time Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period. The Facilities Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period. However, when the Utility determines the Customer's Meter will record little or no energy use for extended periods of time or when the Customer's Meter has not recorded a Maximum Demand in the preceding eleven (11) mo nths, the Facilities Related Component of the Demand Charge may be established at fifty percent (50%) of the Customer's Connected Load.
5. Maximum Demand
The Maximum Demand in any month shall be the measured maximum average kilowatt input, indicated or recorded by instruments, during any 15-minute metered interval in the month, but, where applicable, shall not be less than the diversified resistance welder load computed in accordance with the section designated Welder Service in Rule 2. Where the demand is intermittent or subject to violent fluctuations, a 5-minute interval may be used.
6. Temporary Discontinuance of Service
Where the use of energy is seasonal or intermittent, no adjustments will be made for a temporary discontinuance of service. Any Customer resuming service within twelve (12) months after such service was discontinued will be required to pay all charges which would have been billed if service had not been discontinued.
7. Customer-Owned Electrical Generating Facilities
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
8. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], etc.).
9. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
10. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
11. State Mandated Public Purpose Programs Charge State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
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8 Effective Date: January 1, 2027
MEDIUM COMMERCIAL (TIME-OF-USE)
A. Applicability
Applicable to single and three -phase service including lighting and power Customers whose monthly Maximum Demand registers, or in the opinion of the Utility is expected to register 200 kW through 500 kW. The customer whose monthly Maximum Demand, in the opinion of the Utility, is expected to exceed 500 kW or has exceeded 500 kW for any three (3) months during the preceding twelve (12) months is ineligible for service under this Schedule and effective with the date of ineligibility, such Customer’s account shall be transferred to Large Commercial. Further, any Customer served under this Schedule whose monthly Maximum Demand has registered below 200 kW for twelve (12) consecutive months is ineligible for service under this Rate Schedule and shall be transferred to another applicable Rate Schedule.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh/Meter/Month
Summer Season – On-Peak 0.119150.12004
Mid-Peak 0.086150.08704
Off-Peak 0.058650.05954
Winter Season – Mid-Peak 0.062650.06354
Off-Peak 0.046150.04704
Customer Charge - $/Meter/Month 400.00
Demand Charge - $/kW of Billing Demand/Meter/Month
Facilities Related 14.25
Time Related Summer – On-Peak 13.50 Summer – Mid-Peak 3.50
Power Factor Adjustment - $/KVA 0.27
D. Special Conditions
1. Time periods are defined as follows:
On-Peak: Noon to 6:00 p.m. summer weekdays except holidays.
Mid-Peak: 8:00 a.m. to noon and 6:00 p.m. to 11:00 p.m. summer weekdays except holidays.
8:00 a.m. to 9:00 p.m. winter weekdays except holidays.
Off-Peak: All other hours.
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Holidays are New Year's Day (January 1), Washington's Birthday (third Monday in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Veteran’s Day (November 11), Thanksgiving Day (fourth Thursday in November), and Christmas (December 25).
When any holiday listed above falls on Sunday, the following Monday will be recognized as an off-peak period. No change will be made for holidays falling on Saturday.
The Summer Season shall commence at 12:00 a.m. on June 1 st and continue until 12:00 a.m. on October 1 st of each year. The Winter Season shall commence at 12:00 a.m. on October 1st of each year and continue until 12:00 a.m. on June 1st of the following year. A pro rata computation will be made for seasonal billing purposes.
2. Voltage
Service will be supplied at one (1) standard voltage.
3. Billing Demand
The Billing Demand shall be the kilowatts of Maximum Demand, determined to the nearest kW. The Demand Charge shall include the following billing components. The Time Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period. The Facilities Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period. However, when the Utility determines the Customer's Meter will record little or no energy use for extended periods of time or when the Customer's Meter has not recorded a Maximum Demand in the preceding eleven (11) months, the Facilities Related Component of the Demand Charge may be established at fifty percent (50%) of the Customer's Connected Load.
4. Maximum Demand
Maximum Demand shall be established for the On -Peak, Mid-Peak, and Off-Peak periods. The Maximum Demand in any month shall be the measured maximum average kilowatt input, indicated or recorded by instruments, during any 15-minute metered interval in the m onth, but, where applicable, shall not be less than the diversified resistance welder load computed in accordance with the section designated Welder Service in Rule 2. Where the demand is intermittent or subject to violent fluctuations, a 5-minute interval may be used.
5. Power Factor Adjustment
The Customer’s bill will be increased each month for power factor by the amount shown in the Rates section above for service metered and delivered at the applicable voltage level, based on the per kilovar of maximum reactive demand imposed by the Utility.
The maximum reactive demand shall be the highest measured maximum average kilovar demand indicated or recorded by metering during any 15-minute interval in
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the month. The kilovars shall be determined to the nearest unit. A device will be installed on each kilovar meter to prevent reverse operation of the meter.
6. Temporary Discontinuance of Service
Where the use of energy is seasonal or intermittent, no adjustments will be made for a temporary discontinuance of service. Any Customer resuming service within twelve (12) months after such service was discontinued will be required to pay all charges which would have been billed if service had not been discontinued.
7. Customer-Owned Electrical Generating Facilities
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
8. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], kilovar [kVa], etc.).
9. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
10. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
11. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
11 Effective Date: January 1, 2027
LARGE COMMERCIAL
A. Applicability
Applicable to general services including lighting and power Customers. This Schedule is applicable to and mandatory for all Customers whose monthly Maximum Demand, in the opinion of the Utility, is expected to exceed 500 kW or has exceeded 500 kW in any three (3) months during the preceding twelve (12) months. Any existing Customer on this Schedule whose monthly Maximum Demand has registered 500 kW or less for twelve (12) consecutive months is ineligible for service under this Schedule and shall be transferred to another applicable Rate Schedule. Service under this Schedule is subject to Meter availability.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh/Meter/Month
Summer Season – On-Peak 0.129270.13121
Mid-Peak 0.082210.08415
Off-Peak 0.052860.05480
Winter Season – Mid-Peak 0.072720.07466
Off-Peak 0.049400.05134
Customer Charge - $/Meter/Month 515.00
Demand Charge - $/kW of Billing Demand/Meter/Month
Facilities Related 15.00
Time Related Summer – On-Peak 17.00 Summer – Mid-Peak 5.00
Power Factor Adjustment - $/KVA 0.27
D. Special Conditions
1. Time periods are defined as follows:
On-Peak: Noon to 6:00 p.m. summer weekdays except holidays.
Mid-Peak: 8:00 a.m. to noon and 6:00 p.m. to 11:00 p.m. summer weekdays except holidays.
8:00 a.m. to 9:00 p.m. winter weekdays except holidays.
Off-Peak: All other hours.
Holidays are New Year's Day (January 1), Washington's Birthday (third Monday in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Veteran’s Day (November 11), Thanksgiving Day (fourth Thursday in November), and Christmas (December 25).
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
12 Effective Date: January 1, 2027
When any holiday listed above falls on Sunday, the following Monday will be recognized as an off-peak period. No change will be made for holidays falling on Saturday.
The Summer Season shall commence at 12:00 a.m. on June 1 st and continue until 12:00 a.m. on October 1 st of each year. The Winter Season shall commence at 12:00 a.m. on October 1st of each year and continue until 12:00 a.m. on June 1st of the following year. A pro rata computation will be made for seasonal billing purposes.
2. Voltage
Service will be supplied at one standard voltage.
3. Maximum Demand
Maximum Demands shall be established for the On-Peak, Mid-Peak, and Off-Peak periods. The Maximum Demand for each period shall be the measured maximum average kilowatt input indicated or recorded by instruments, during any 15-minute metered interval, but, where applicable, not less than the diversified resistance welder load computed in accordance with the section designated Welder Service in Rule 2. Where the demand is intermittent or subject to violent fluctuations, a 5 - minute interval may be used.
4. Billing Demand
The Billing Demand shall be the kilowatts of Maximum Demand, determined to the nearest kW. The Demand Charge shall include the following billing components. The Time Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period for each of the On -Peak, Mid -Peak, and Off -Peak Time Periods. The Facilities Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period. However, when the Utility determines the Customer's Meter will record little or no energy use for extended periods of time or when the Customer's Meter has not recorded a Maximum Demand in the preceding eleven (11) months, the Facilities Related Component of the Dem and Charge may be established at fifty percent (50%) of the Customer's Connected Load. Separate Demand Charge(s) for the On-Peak, Mid-Peak, and Off-Peak Time Periods shall be established for each monthly billing period. The Demand Charge for each time period shall be based on the Maximum Demand for that time period occurring during the respective monthly billing period.
5. Power Factor Adjustment
The Customer’s bill will be increased each month for power factor by the amount shown in the Rates section above for service metered and delivered at the applicable voltage level, based on the per kilovar of maximum reactive demand imposed by the Utility.
The maximum reactive demand shall be the highest measured maximum average kilovar demand indicated or recorded by metering during any 15 -minute metered interval in the month. The kilovars shall be determined to the nearest unit. A device will be installed on each kilovar Meter to prevent reverse operation of the Meter.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
13 Effective Date: January 1, 2027
6. Temporary Discontinuance of Service
Where the use of energy is seasonal or intermittent, no adjustments will be made for a temporary discontinuance of service. Any Customer, prior to resuming service within twelve (12) months after such service was discontinued, will be required to pay all charges which would have been billed if service had not been discontinued.
7. Customer-Owned Electrical Generating Facilities
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
8. Contracts
An initial three -year facilities contract may be required where Applicant requires new or added serving capacity exceeding 2,000 kVA.
9. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], kilovar [kVa], etc.).
10. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
11. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
12. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
14 Effective Date: January 1, 2027
LARGE INDUSTRIAL
A. Applicability
Applicable to general services including lighting and power Customers delivered at the utility’s primary distribution voltage level of 12 kV. This Schedule is applicable to and mandatory for all Customers whose monthly Maximum Demand, in the opinion of the Utility, is expected to exceed 500 kW or has exceeded 500 kW in any three (3) months during the preceding twelve (12) months. Any existing Customer on this Schedule whose monthly Maximum Demand has registered 500 kW or less for twelve (12) consecutive months is ineligible for service under this Schedule and shall be transferred to another applicable Rate Schedule. Service under this Schedule is subject to Meter availability.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh/Meter/Month
Summer Season – On-Peak 0.105590.10750
Mid-Peak 0.082880.08479
Off-Peak 0.056070.05798
Winter Season – Mid-Peak 0.077310.07922
Off-Peak 0.051760.05367
Customer Charge - $/Meter/Month 515.00
Demand Charge - $/kW of Billing Demand/Meter/Month
Facilities Related 13.50
Time Related Summer – On-Peak 20.00 Summer – Mid-Peak 5.00
Power Factor Adjustment - $/KVA 0.27
D. Special Conditions
1. Time periods are defined as follows:
On-Peak: Noon to 6:00 p.m. summer weekdays except holidays.
Mid-Peak: 8:00 a.m. to noon and 6:00 p.m. to 11:00 p.m. summer weekdays except holidays.
8:00 a.m. to 9:00 p.m. winter weekdays except holidays.
Off-Peak: All other hours.
Holidays are New Year's Day (January 1), Washington's Birthday (third Monday in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Veteran’s Day (November 11), Thanksgiving Day (fourth Thursday in November), and Christmas (December 25).
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
15 Effective Date: January 1, 2027
When any holiday listed above falls on Sunday, the following Monday will be recognized as an off-peak period. No change will be made for holidays falling on Saturday.
The Summer Season shall commence at 12:00 a.m. on June 1 st and continue until 12:00 a.m. on October 1 st of each year. The Winter Season shall commence at 12:00 a.m. on October 1st of each year and continue until 12:00 a.m. on June 1st of the following year. A pro rata computation will be made for seasonal billing purposes.
2. Voltage
Service will be supplied at one standard voltage.
3. Maximum Demand
Maximum Demands shall be established for the On-Peak, Mid-Peak, and Off-Peak periods. The Maximum Demand for each period shall be the measured maximum average kilowatt input indicated or recorded by instruments, during any 15-minute metered interval, but, where applicable, not less than the diversified resistance welder load computed in accordance with the section designated Welder Service in Rule 2. Where the demand is intermittent or subject to violent fluctuations, a 5 - minute interval may be used.
4. Billing Demand
The Billing Demand shall be the kilowatts of Maximum Demand, determined to the nearest kW. The Demand Charge shall include the following billing components. The Time Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period for each of the On -Peak, Mid -Peak, and Off -Peak Time Periods. The Facilities Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period. However, when the Utility determines the Customer's Meter will record little or no energy use for extended periods of time or when the Customer's Meter has not recorded a Maximum Demand in the preceding eleven (11) months, the Facilities Related Component of the Dem and Charge may be established at fifty percent (50%) of the Customer's Connected Load. Separate Demand Charge(s) for the On-Peak, Mid-Peak, and Off-Peak Time Periods shall be established for each monthly billing period. The Demand Charge for each time period shall be based on the Maximum Demand for that time period occurring during the respective monthly billing period.
5. Power Factor Adjustment
The Customer’s bill will be increased each month for power factor by the amount shown in the Rates section above for service metered and delivered at the applicable voltage level, based on the per kilovar of maximum reactive demand imposed by the Utility.
The maximum reactive demand shall be the highest measured maximum average kilovar demand indicated or recorded by metering during any 15 -minute metered interval in the month. The kilovars shall be determined to the nearest unit. A device will be installed on each kilovar Meter to prevent reverse operation of the Meter.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
16 Effective Date: January 1, 2027
6. Temporary Discontinuance of Service
Where the use of energy is seasonal or intermittent, no adjustments will be made for a temporary discontinuance of service. Any Customer, prior to resuming service within twelve (12) months after such service was discontinued, will be required to pay all charges which would have been billed if service had not been discontinued.
7. Customer-Owned Electrical Generating Facilities
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
8. Customer Responsibilities
The customer will be responsible for all costs associated with the primary point-of- delivery installation, including the metering and primary voltage physical disconnect necessary to isolate the customer's facilities from the utility's facilities.
The cust omer will be responsible to own, operate and maintain all electrical distribution facilities on the customer side of the primary point -of-delivery (typically established at the primary meter).
9. Contracts
An initial three -year facilities contract may be required where Applicant requires new or added serving capacity exceeding 2,000 kVA.
10. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], kilovar [kVa], etc.).
11. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
12. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
13. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
17 Effective Date: January 1, 2027
STREET LIGHTING
A. Applicability
Applicable to meter for the lighting of streets, and publicly -owned and publicly -operated automobile parking lots which are opened to the general public where the City owns and maintains the street lighting equipment and associated facilities included under this Schedule.
B. Territory
Within the entire territory served.
C. Rates
Light Emitting Diode (LED) Lamps – All Night Service
Street Lighting
Energy Charge - $/kWh/Lamp 0.072820.07889
Lamp Charge - $/Lamp/Month 2.50
Safety
Energy Charge - $/kWh/Lamp 0.072820.07889
D. Special Conditions
1. The Applicant shall install streetlights that will be served by the Utility. These streetlights must be installed in accordance with the Utility’s specifications and the developer will deed such facilities to the City.
2. Requirements and Restrictions
a. The Applicant for street light service shall specify the type of service, lamp size, and location of street lights.
b. Service shall not be furnished under this Schedule where location, mounting height, and/or other considerations are unacceptable to the Utility. c. The installation of street lighting equipment and facilities hereunder is contingent upon the utility obtaining easements, and rights of way, as may be required, satisfactory to the Utility for the required poles, lines, equipment, and facilities.
d. Should the Applicant not commence using the street lighting in a bona fide manner within ninety (90) days after date of completion and installation of a street light or street lighting system requested by the Applicant, the Utility will bill, and the Applicant shall pay, the applicable lamp charges(s).
3. Hours of Service
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
18 Effective Date: January 1, 2027
Under the Utility’s standard all night operating schedule, approximately 4,140 hours of service per year will be furnished.
Kilowatt hours for Lamp Type and Size: The kilowatt hours for lamp types and sizes served under this Schedule used to determine the Energy Charge are shown below:
Light Emitting Diode
(LED) Lamps
Lamp Watts
Including
Driver Loss
Lamp Watts
Including
Driver Loss
Mid-Point
Range
kWh per Lamp per
Month
All Night Service
0-5 2.50 0.9
5.01-10 7.50 2.6
10.01-15 12.50 4.3
15.01-20 17.50 6.0
20.01-25 22.50 7.8
25.01-30 27.50 9.5
30.01-35 32.50 11.2
35.01-40 37.50 12.9
40.01-45 42.50 14.7
45.01-50 47.50 16.4
50.01-55 52.50 18.1
55.01-60 57.50 19.8
60.01-65 62.50 21.6
65.01-70 67.50 23.3
70.01-75 72.50 25.0
75.01-80 77.50 26.7
80.01-85 82.50 28.5
85.01-90 87.50 30.2
90.01-95 92.50 31.9
95.01-100 97.50 33.6
100.01-105 102.50 35.4
105.01-110 107.50 37.1
110.01-115 112.50 38.8
115.01-120 117.50 40.5
120.01-125 122.50 42.3
125.01-130 127.50 44.0
130.01-135 132.50 45.7
135.01-140 137.50 47.4
140.01-145 142.50 49.2
145.01-150 147.50 50.9
150.01-155 152.50 52.6
155.01-160 157.50 54.3
160.01-165 162.50 56.1
165.01-170 167.50 57.8
170.01-175 172.50 59.5
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
19 Effective Date: January 1, 2027
4. Maintenance
The Utility shall exercise reasonable care and diligence in maintaining its street light facilities or Utility-owned attachments thereto. Where the Utility experiences, or expects to experience, maintenance costs exceeding its normal maintenance expense resulting from, but not limited to, vandalism, the Utility may require the customer to pay the excess maintenance expense.
5. Liability of the Utility
The Utility shall not, by taking action pursuant to its tariffs, be liable for any loss, damage, or injury, established or alleged, which may result, or be claimed to result, therefrom.
6. Removal, Relocation or Modification of Facilities
Where street lighting service and facilities are ordered removed by a customer, the customer shall pay to the Utility a nonrefundable amount equal to the total estimated cost installed less any Customer contribution, plus the estimated cost of removal less the estimated net salvage value of the facilities.
Where street lighting service and facilities were ordered removed by a Customer and such service and facilities, or their equivalent are ordered reinstalled within thirty-six (36) months from the date of the order to remove, the Customer shall pay to the Utility in advance of reinstallation a nonrefundable amount equal to the cost of removal of the prior facilities and the estimated cost of such reinstallation.
Where street lighting facilities are ordered modified and /or relocated by a Customer, the Customer shall pay to the Utility, in advance of such modification and/or relocation, a nonrefundable amount equal to the estimated cost of such modification and/or relocation. This includes facilities that now serve street light load only, but that may have been installed originally to serve other than street light load.
Utility-owned facilities removed or installed remain the sole property of the Utility.
7. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above.
8. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
9. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
10. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
20 Effective Date: January 1, 2027
TRAFFIC CONTROL
A. Applicability
Applicable to single and three -phase service for traffic directional signs or traffic signal systems located on streets, highways and other public thoroughfares and to railway crossing and track signals; for public thoroughfare lighting that is utilized twenty-four (24) hours per day or is not controlled by switching equipment, such as tunnel or underpass lighting; and, to public authorities for the illumination of bus stop shelters located in the dedicated road right -of-way where such service is combined with other traffic control service as defined above.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh 0.119410.12610
Customer Charge - $/Day 0.60
D. Special Conditions
1. Voltage
Service will be supplied at one (1) standard voltage not in excess of 240 volts or, at the option of the Utility, at 240/480 volts, three wire, single-phase.
2. Billing Calculation
A Customer’s bill is calculated according to the rate and conditions above.
3. Power Cost Adjustment Factor (PCAF)
The rate above is subject to an adjustment as provided in Rule 12, Section E.
4. Change of Law Adjustment Factor (CLAF)
The rate above is subject to an adjustment as provided in Rule 12, Section F.
5. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
21 Effective Date: January 1, 2027
OUTDOOR AREA LIGHTING
A. Applicability
Applicable to single -phase service for metered outdoor area lighting load, controlled for dusk to dawn operation and used for purposes other than street and highway lighting such as, but not limited to parking lots, pedestrian walkways, billboards, building exteriors, security, sports and recreation areas, monuments, decorative areas, and bus shelters.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh/Meter/Month 0.069230.07437
Customer Charge- $/Meter/Month 15.25
D. Special Conditions
1. Voltage
Service will be provided at one (1) standard voltage.
2. Three-Phase Service
Where, in the sole opinion of the Utility, it is impractical to provide single -phase service under this Schedule, three-phase service will be provided.
3. Separate Point of Delivery
When requested by the Applicant or Customer, and agreed upon by the Utility, an additional Point of Delivery may be provided, separate from any other Point of Delivery provided under any other applicable Rate Schedule. Customers so served shall not be per mitted to have an electrical interconnection beyond the Utility’s Point of Delivery between the separately metered loads except upon written approval of the Utility.
A change from this Schedule to any other Rate Schedule will be permitted if the additional Point of Delivery is removed. Any such removal shall be at the Customer's expense.
Any rearrangement of facilities required to provide the additional Point of Delivery shall be at the expense of the requesting Applicant or Customer.
4. Controlled Operation
Service under this Schedule requires the control of lamps in a manner acceptable to the Utility so that lamps will not be lighted daily from dawn to dusk. Customer shall install, own, operate, and maintain the control device. The Utility shall have
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
22 Effective Date: January 1, 2027
the right to periodically inspect the control device to ensure its correct operation and maintenance.
5. Distribution Line Extension
Distribution Line Extensions to reach an outdoor area light or area lighting system shall be in accordance with Rule 15.
6. Services
Services shall be installed and maintained as provided in Rule 16.
7. Incidental Loads
Incidental, non-lighting loads may be served under this Schedule only where such Connected Loads do not exceed fifteen percent (15) of the Customer’s total Connected Load. Incidental Loads must also be controlled for dusk to dawn operation exclusively.
8. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], etc.).
9. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
10. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
11. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
23 Effective Date: January 1, 2027
IRRIGATION SYSTEMS
A. Applicability
Applicable where the Utility determines that 100% of the customer’s electrical usage is for limited irrigation service except for the Customer whose monthly Maximum Demand, in the opinion of the Utility, is expected to exceed 20 kW or has exceeded 20 kW in any three (3) months during the preceding twelve (12) mo nths is ineligible for service under this Schedule. Effective with the date of ineligibility of any Customer served under this Schedule, the Customer’s account shall be transferred to another applicable Rate Schedule.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh 0.181420.17676
Customer Charge - $/Day 0.800.85
D. Special Condition
1. Voltage
Service will be supplied at one (1) standard voltage not in excess of 240 volts or, at the option of the Utility, at 240/480 volts, three wire, single-phase.
2. Billing Calculation
A Customer’s bill is calculated according to the rate and conditions above.
3. Power Cost Adjustment Factor (PCAF)
The rate above is subject to an adjustment as provided in Rule 12, Section E.
4. Change of Law Adjustment Factor (CLAF)
The rate above is subject to an adjustment as provided in Rule 12, Section F.
5. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
24 Effective Date: January 1, 2027
WIRELESS TECHNOLOGY
A. Applicability
Applicable to single-phase service for wireless technology industries that require electric service to operate radio repeaters or similar devices (wireless communication devices) that are mounted on existing City facilities, or other facilities approved by the Utility and are unmetered. This Schedule excludes Wi-Fi devices on “looped” (served by 120/240 volts) streetlight facilities. Customers must execute an application/contract with the Utility for service under this Schedule and must execute an applicable agreement when devices are attached to City facilities. The monthly kilowatt -hour (kWh) usage of each device shall not exceed 500 kWh. Effective with the date of ineligibility of any Customer served under this Schedule, the Customer's account shall be transferred to another applicable Rate Schedule. If the Customer’s account cannot be transferred to another applicable Rate Schedule, the account will be closed, the Utility’s service will be removed, and the Customer must remove its device and equipment form the applicable City facility.
B. Territory
Within the entire territory served
C. Rates
Fixed Energy Charge - $/Device/Month 61.20
Customer Charge - $/Month 18.5219.76
Inspection Charge - $/Device/Month 12.60
Three-Phase Service - $/Day 0.03
Initialization of Service Charge 6.79
D. Special Conditions
1. Contract
An approved City contract is required for service under this Rate Schedule.
2. Voltage
Service will be supplied at one (1) standard voltage not in excess of 240 volts.
3. Three-Phase Service
Where the Utility provides three-phase service, the billing will be increased by the amount shown in the Rates section above.
4. Maximum Wattage
The maximum watts/connected load/name plate is 746 watts.
5. Installation
The device(s) shall be installed on City facilities or other facilities approved by the Utility. When the devices are installed on City facilities, the installation and
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
25 Effective Date: January 1, 2027
removal of such device(s) will be performed by the Customer, and at the Customer’s expense. Device installation shall not be performed under this Rate Schedule, where location, mounting height, and/or other considerations are not acceptable to the Utility . Unless approved by the Utility, all wireless communication devices must be visible to the Utility.
7. Modification of Facilities
No modifications can be made to the Customer -owned wireless communications devices unless approved by the Utility. Where the Customer requests a modification of City facilities, and such modifications are acceptable to the City, the City will perform the requested modifications at the Customer’s expense.
8. Maintenance
The Utility shall exercise reasonable care and diligence in maintaining its facilities.
Upon installation of the device(s), where the Utility experiences, or expects to experience, maintenance costs exceeding its normal maintenance expense resulting from, but not limited to, vandalism, the Utility may require the Customer to pay the excess maintenance expense.
9. Liability of the Utility
The Utility shall not, by taking action pursuant to its tariffs, be liable for any loss, damage, or injury, established or alleged, which may result, or be claimed to result, there from.
10. Initialization of Service Charge
A one-time charge, as shown in the Rates section of this Rate Schedule, is applied to each service account provided service under this Rate Schedule to recover the costs of a lock and spare fuse which are required with the initialization of service.
11. Power Cost Adjustment Factor (PCAF)
The rates above are subject to an adjustment as provided in Rule 12, Section E.
12. Change of Law Adjustment Factor (CLAF)
The rates above are subject to an adjustment as provided in Rule 12, Section F.
13. State Mandated Public Purpose Programs Charge
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
CITY OF RANCHO CUCAMONGA MUNICIPAL UTILITY
ELECTRIC RATES & TARIFFS
26 Effective Date: January 1, 2027
NET ENERGY METERING
A. Applicability
Applicable to a customer who operates a renewable electrical generation facility that is located on the customer’s premises with a capacity of not more than 1 MW that is interconnected and operates in parallel with the City’s electric system, intended prim arily to offset part or all of the customer’s own electrical requirements, and meets all the applicable safety and performance standards.
B. Territory
Within the entire territory served.
C. Net Surplus Compensation Rate
For customer accounts established on or after December 1, 2018: The net surplus compensation rate shall be $0.0500 per kWh applied to any net surplus energy remaining at the end of the customer’s twelve (12) monthly billing period (“relevant period”).
Grandfathered Provision: For customer accounts established before December 1, 2018:
The net surplus compensation rate shall be equivalent to the highest hourly rate that was charged for consumption in their OAT during the year prior to the Customer’s Annua l Billing Date. This provision will remain in effect for fifteen (15) years from the Customer’s original year in which the generating facility was interconnected to RCMU’s grid. After that period expires, the Customer will receive the current net surplus compensation that is being offered at that time.
D. Rates
1. All rates charged under this schedule will be in accordance with the Eligible Customer-Generator’s otherwise applicable tariff (OAT) or rate schedule. An Eligible Customer -Generator served under this schedule is responsible for all charges in its OA T including the monthly or annual minimum charges (including service, customer, reliability and demand charges, when applicable) regardless of the Customer’s monthly or annual net generation.
Eligible Customers under this schedule are subject to any new or additional charge(s) that may be imposed by the Utility on the other customer in the rate class to which Customer would otherwise be assigned.
2. As determined in each billing period, when a customer consumes more energy than generated at the premises (net consumer), the net consumed energy will be used in the calculation of all applicable energy charges, calculated by multiplying the net amount consumed by the applicable energy rate components of the customer’s OAT.
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3. As determined in each billing period, when a customer generates more energy than is consumed by the customer (net generator), the resulting net produced energy will be calculated by multiplying the net produced kWh by the applicable energy rate component of the Customer’s OAT (including TOU periods) and be a credit on the bill. Any net kilowatt -hours of production credit that exceeds the net consumed energy, will be carried forward into the next billing period.
If the Customer’s OAT includes “time of use” (TOU) rates, any net energy consumed monthly shall be calculated according to the terms of the OAT. When the customer is a net generator during any TOU period, the net kilowatt -hours generated shall be valued at the same price per kilowatt -hour as the Utility would charge during that same TOU period.
4. Customers who are Net Surplus Electricity producers at the Customer’s Annual True-Up Date, may elect to either carry over annual Net Surplus Energy production (in kilowatt hours) as a credit that will be applied to kilowatt hours consumed by the Customer or Customer may elect to receive payment to cash out the remaining Net Surplus Energy.
D. Special Condition
1. An executed Net Energy Metering and Generating Facility Interconnection Agreement is required prior to receiving service under this Schedule.
2. Metering Requirements: If the customer’s existing meter is not capable of measuring the flow of energy in two directions, an appropriate meter shall be provided at the expense of the customer. The City may elect to install an additional meter or meter s, at the City’s expense to provide the information necessary to accurately bill or credit the customer.
3. To be eligible for service under this Schedule, the customer’s generating facilities must be sized to offset part or all of the customer’s own electrical requirements and cannot be oversized. This means that the estimated output of the generating facility, using the CEC -AC nameplate rating for inverter -based generating facilities must not exceed the customer’s previous annual usage in kWh.
4. A new customer of record who owns, leases, or rents a premise that includes an existing generating facility with a capacity under 30 kW that was approved by RCMU for operation prior to the new customer moving in and/or taking electric service with RCMU will take service under this Tariff as long as the requirements of this Tariff are met and will not have to sign a new Interconnection Agreement.
This provision also applies to premises where the developer/contractor establishes the interconnection.
A new customer of record who owns, leases, or rents a premise that includes an existing generating facility with a capacity over 30 kW that was approved by RCMU for operation prior to the new customer moving in and/or taking electric service with RCMU will take service under this Tariff and will need to sign a new Interconnection Agreement.
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5. RCMU shall retain any net surplus energy generated by the NEM Customer including any associated environmental attributes or renewable energy credits (RECs).
6. Net Metering Aggregation (NMA): Customers served under this Tariff with a Generating Facility on a property owned by the Customer, may elect to aggregate electric services to additional properties that are solely owned by the Customer and are located on parcels adjacent or contiguous to the Generating Facility. Generation not used where the Generating Facility is located, is transferred to adjacent properties and equally distributed to the other properties by a percentage determined upon entering into t he Interconnection Agreement. NMA does not allow for Net Surplus Compensation for excess generation.
E. Billing
1. City shall provide all customers served under this Schedule with net energy consumption information and/or net energy export information with each monthly bill.
2. Customers served under this Schedule shall pay both energy and non -energy charges on a monthly basis, in accordance with the customer’s OAT except as otherwise allowed by State law. The value of net energy production will be used to offset only energy related charges in subsequent billing periods.
F. Definitions
1. Net energy metering measures the difference between the electricity supplied through the electric grid and the electricity generated on the customer’s premises and fed back to the electric grid over a Twelve-Month Period.
2. Otherwise Applicable Tariff (OAT) is the customer’s regularly filed rate schedule under which service is rendered.
3. Net Surplus Electricity is the electricity generated by an eligible customer - generator measured in kilowatt hours over a 12 -month period that exceeds the amount of electricity consumed by that eligible customer-generator.
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ECONOMIC DEVELOPMENT
A. Applicability
Commercial or industrial end -use Customers that would otherwise receive service under the Large Commercial or Large Industrial Electric Rate Schedule and meet certain criteria as established and adopted by resolution of the City Council of the City of Ranc ho Cucamonga may take advantage of the Economic Development (ED) rate as a New Customer or Expanded Load Customer. This ED rate is applicable to all or part of the services provided to New Customers and Expanded Load Customers, as such terms are defined herein.
1. A New Customer shall be a Customer seeking to locate a new business or relocate an existing business (not currently located within the territory served by the Rancho Cucamonga Municipal Utility (RCMU)) within RCMU’s service territory. a. A New Customer shall meet both of the following criteria in order to qualify for Schedule ED:
i. Projected minimum monthly electric demand of at least 200 kW. ii. Job Creation
1. Tier 1 Discount Rate 100 – 249 jobs
2. Tier 2 Discount Rate 250 – 500 jobs
3. Tier 3 Discount Rate greater than 500 jobs
2. An Expanded Load Customer shall be an existing RCMU Large Commercial or Large Industrial customer that is adding new load to RCMU by a minimum monthly electric demand of 200 kW based upon the Customer’s past electrical demand as determined by RCMU. The expanded load can be at the customer’s current site, or at a new site within the RCMU servic e territory. The Tier 1 ED rate will only be applied to the expanded load as determined in Section 6 below.
B. Territory
Within the entire territory served.
C. Character of Service
The service provided hereunder shall be alternating current with regulated frequency of 60 hertz, three-phase, or a combination single and three-phase served through one meter, at a standard voltage specified by RCMU. To be eligible to participate all customers must have a demand meter.
D. Rates
Except as provided herein, or in the Economic Development Rate Agreement, all charges and provisions of the Customer’s otherwise applicable rate schedule shall apply. The applicable Energy Charge and Demand Charge under the Customer’s otherwise applicable rate schedule will be reduced as follows:
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Tier 1 Tier 2 Tier 3
Years 1 - 2 20% 20% 20%
Years 3 - 4 15% 17% 20%
Year 5 10% 12% 15%
E. Special Conditions
1. Term: Economic Development Rate Agreements entered into under this Schedule shall be for a single five-year term.
2. Approval: Application of this Rate Schedule shall be subject to the approval of the City Manager or his/her designee, based on meeting the eligibility criteria outlined herein.
3. Agreement: The Customer must sign a standard Rancho Cucamonga Economic Development Rate Agreement in order for the rates under this Schedule to be applicable. In addition to the other terms of this Schedule, the Economic Development Rate Agreement shall require th e Customer to reimburse Rancho Cucamonga for all rate reductions received under this Schedule, if the Customer fails to maintain the required minimum load during the five -year term of the Agreement.
4. Minimum Load: Customers qualifying under this Schedule as a New Customer with a projected minimum monthly electric demand of at least 200 kW or as an Expanded Load Customer under Applicability Sections 1 and 2 above, respectively, must agree to maintain a minimum lev el of load for five years from the date service is first rendered under this Schedule and to document compliance with all applicable requirements, as set forth in the Economic Development Rate Agreement.
5. Job Creation / Retention : Customers qualifying under this Schedule as a New Customer with a projected minimum monthly electric demand of at least 200 kW under Applicability Section 1a (ii), respectively, must agree to create and retain a minimum level of full -time equivalent jobs for five years from the date service is first rendered under this Schedule and to document compliance with all applicable requirements, as set forth in the Economic Development Rate Agreement.
6. Base Period Usage : Base Period Usage shall be established and agreed to in the Economic Development Rate Agreement for Expanded Load Customers. Base Period Usage shall be the average monthly energy use and demand for the Customer during the last three years of service to the Customer, from the date ending the last payment period before the date of the Agreement. Expanded Load qualifying for the rate under this Schedule shall be measured as the difference between the new monthly, metered documented energy use and demand, and the Base Period Usage.
7. State Mandated Public Purpose Program Charge: All bills rendered under this Schedule shall be subject to the Public Purpose Program Charge as established by the City Council.
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8. Miscellaneous Fees and Charges : Rates charged pursuant to this Schedule shall be subject to any Energy Users Taxes, Utility Users Taxes, and any other governmental taxes, duties, or fees which are applicable to Electric Service provided to Customer by the City of Rancho Cucamonga. Rates are also subject to adjustment, as established by the City of Rancho Cucamonga’s City Council, in its sole discretion, in response to federal or state climate change laws, renewable portfolio standard or other mandated legis lation. These adjustments may include but are not limited to charges to mitigate the impacts of greenhouse gas emissions or “green power” premiums.
9. Expanded Load: Expanded Load customers applying for this rate must demonstrate to the satisfaction of the Utility that the expanded load is new to the Rancho Cucamonga Municipal Utility.
10. Effective Date: The effective date of the Economic Development Rate Agreement shall commence within 12 months from the date of the City’s approval, or the Agreement becomes null and void. The Agreement becomes effective upon execution by the parties, and the Economic De velopment Rate commences upon written notice by Customer and coincides with the Customer’s normal billing cycle.
11. Reapplication: Customers who have received service under the Economic Development Rate are eligible to reapply for the rate as an Expanded Load Customer, if they meet the criteria therefore.
12. Restrictions: Residential customers and federal, state or local government agencies are not eligible to apply for service under this Schedule.
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STANDBY DEMAND CAPACITY RESERVATION CHARGE
(SELF GENERATION)
A. Applicability
Applicable to Large Commercial and Large Industrial customers who operates a non -net metered, non -utility generating facility rated at 1000 kW or less, interconnected on the Customer’s premises and operates in parallel with the City’s electric system. The generating facility is intended primarily to offset part or all of the customer’s own electrical requirements and meets all the applicable safety and performance standards.
Standby service customers have unique electric demands, due to their on -site generation assets, that are often quite different from those of full requirement customers. These customers pay standby rates so that they may, in the event of a planned or unplanned outage of their non-utility generating system, take service from the City electric system. The City bears an “obligation to serve” and must configure their system to allow every customer reliable access to the grid. The standby charge is designed to re cover the costs of transmission and distribution facilities, as well as substation and transformers dedicated to the customer’s use that do not vary with usage in maintaining sufficient capacity (through operating reserves) in order to serve an unplanned o utage, even if such an outage never occurs. The standby charge also includes appropriate service voltage level distinctions:
secondary and primary.
B. Territory
The entire territory served.
C. Rates
1. Rates for this service shall be the same as for the schedule under which the customer’s otherwise applicable rate schedule shall apply.
2. Standby Demand Capacity Reservation Charge (CRC): A CRC shall be a flat $/kW amount applied to the Standby Demand in kW, which represents the entire reserved capacity needed for the City to serve the self -generation customer’s load, which would have been regularly served by the customer’s generating facility when such facility experiences a partial or complete outage. The level of Standby Demand shall be provided by the customer and shall not exceed the nameplate capacity of the customer’s generating facility.
Standby Charge – Secondary ($/kW) Standby Charge – Primary ($/kW) $8.61 $7.61
3. Demand Charge: As determined in each billing period, a Standby Service customer’s billing demand shall be the kilowatts of Maximum Demand indicated or recorded by instruments, determined to the nearest kW of the absolute net power
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that the customer received from the City’s electric system. The Demand Charge for each time period shall be based on the Maximum Demand for that time period occurring during the respective monthly billing period.
4. Energy Charge: As determined in each billing period, when a Standby Service customer consumes more energy than generated at the premises, the net consumed energy will be used in the calculation of all applicable energy charges. All Energy shall be billed in accordance with the customer’s Otherwise Applicable Tariff rate schedule which wou ld otherwise apply if the customer had no generating equipment.
5. Other charges: All other specific rate components, including the Power Factor Adjustment Charge, Customer Charge and the State Electric SurTax will not vary based on registered usage or demand of the customer’s generating facility.
D. Special Conditions
1. Contract Required - Customer shall sign an Interconnection Agreement contract for this service, which shall state the number of kW of standby capacity required. "Standby capacity" shall not exceed the nameplate rating of the customer’s generating equipment.
2. Metering Requirements - If the customer’s existing meter is not capable of measuring the flow of energy in two directions, an appropriate meter shall be provided at the expense of the customer. The City may elect to install an additional meter or meters, at the customer’s expense to provide the information necessary to accurately bill or credit the customer.
3. The CRC tariff is only applicable to Standby Service customers who require electric capacity and energy supplied by the City on a regular basis to supplement the Customer’s power requirement in addition to that ordinarily supplied by the on-site non-utility generation facilities. If a customer has a planned generator outage with prior notification given to RCMU for an entire billing period the standby charge will not be applicable.
4. Customers exempted from the CRC tariff:
(a) Customers with backup on -site generation that is used exclusively when service from the utility is not available in the event of an interruption in utility service and which are not used to offset Customer electricity purchases. (b) The applicability of these exemptions shall be determined at the discretion of the Utilities Manager.
5. Standby Demand in kW represents the entire reserved capacity needed for the City to serve the customer’s load, regularly served by the customer’s generating facility when such facility experiences a partial or complete outage. The level of Standby Demand, which shall not exceed the nameplate capacity of the customer’s
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generating facility, is initially designated by the customer and is set forth in the generation interconnection agreement. Once a customer’s designated Standby Demand has been set, it shall remain at such level for a minimum of 12 months unless, in the Cit y’s determination, the Standby Demand needs to be adjusted to more accurately represent the customer’s actual reserve capacity needs. Upon the City’s determination that the customer’s designated Standby Demand does not reflect the actual level of needed re serve capacity, over any 15 -minute period or through on-site verification, the City shall adjust the Standby Demand to reflect the actual needed reserve capacity. When the Standby Demand is adjusted by the City as provided above, a qualified change in the Standby Demand shall not be made for 12 months from the last adjustment. The customer is responsible for notifying the City of permanent or material changes in their generation facilities (size, type and operations) for future adjustments to the Standby Demand.
6. Diversity Factor - a statistical assumption that a certain percentage of standby load will be utilizing substation and distribution service between each class’ peak demand and the system peak demand. This factor was determined using the diversity factors calculated in the ut ility’s most recent cost of service study and is embedded in the current CRC tariff. A percentage difference was identified as the diversity factor and the distribution and substation portion of the standby rates were reduced accordingly reflecting a reduction in those infrastructure requirements.
E. Billing Calculation
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges on the customer’s applicable nameplate generation capacity for the generating unit at the customer’s facility. All other usage provided by RCMU will be based on the applicable rate tariff, including any riders or additional charges.
Customers served under this Schedule shall pay both energy and non -energy charges on a monthly basis, in accordance with the customer’s Otherwise Applicable Tariff except as otherwise allowed by State law.
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ELECTRIC VEHICLE CHARGING
A. Applicability
Applicable solely for the charging of electric vehicles, on a premises or public right of way where a separate RCMU meter to serve electric vehicle (EV) charging facilities is requested.
B. Territory
Within the entire territory served.
C. Rates
Energy Charge - $/kWh/Meter/Month
Summer Season – On-Peak 0.23654
Mid-Peak 0.107380.11086
Off-Peak 0.04273
Winter Season – On-Peak 0.091290.09477
Mid-Peak 0.07932
Off-Peak 0.053260.05674
Customer Charge - $/Meter/Month Under 20 kW 30.00 Over 20 kW 185.00
Demand Charge - $/kW of Billing Demand/Meter/Month
Facilities Related 12.00
Power Factor Adjustment - $/KVA 0.30
D. Special Conditions
1. Time periods are defined as follows:
On-Peak: Noon to 6:00 p.m. weekdays except holidays
Mid-Peak: 8:00 a.m. to noon and 6:00 p.m. to 11:00 p.m. weekdays except holidays.
Off-Peak: All other hours.
Holidays are New Year’s Day (January 1), Washington’s Birthday (third Monday in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Veteran’s Day (November 11), Thanksgiving Day (fourth Thursday in November), and Christmas (December 25).
When any holiday listed above falls on Sunday, the following Monday will be recognized as an off-peak period. No change will be made for holidays falling on Saturday.
The Summer Season shall commence at 12:00 a.m. on June 1 st and continue until 12:00 a.m. on October 1 st of each year. The Winter Season shall commence at 12:00 a.m. on October 1st of each year and continue until 12:00 a.m. on June 1st of
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the following year. A pro rata computation will be made for seasonal billing purposes.
2. Voltage Service will be supplied at one (1) standard voltage.
3. Metering
Only EV charging facilities and related equipment shall be separately metered and served under this Schedule. Where RCMU determines that the operation of the EV charging facilities may interfere with service to that customer or other customers, RCMU will install a load management device at customer’s expense to control when EV charging will occur. For purposes of monitoring customer load, RCMU may install at its expense, load research metering. The customer shall provide, at no expense to RCMU, a suitable location for meters and associated equipment.
4. Billing Demand
The Billing Demand shall be the kilowatts (kW) of Maximum Demand, determined to the nearest kW. The Demand Charge may include the following billing components. The Time Related Component shall be for the kilowatts of Maximum Demand recorded during (or es tablished for) the monthly billing period. The Facilities Related Component shall be for the kilowatts of Maximum Demand recorded during (or established for) the monthly billing period. However, when the Utility determines the Customer's Meter will recor d little or no energy use for extended periods of time or when the Customer's Meter has not recorded a Maximum Demand in the preceding eleven (11) months, the Facilities Related Component of the Demand Charge may be established at fifty percent (50%) of the Customer's Connected Load.
5. Maximum Demand
The Maximum Demand in any month shall be the measured maximum kilowatt input, indicated or recorded by instruments, during any 15-minute metered interval in the month.
6. Power Factor Adjustment
The Customer’s bill will be increased each month for power factor by the amount shown in the Rates section above for service metered and delivered at the applicable voltage level, based on the per kilovar of maximum reactive demand imposed by the Utility.
The maximum reactive demand shall be the highest measured maximum average kilovar demand indicated or recorded by metering during any 15-minute interval in the month. The kilovars shall be determined to the nearest unit. A device will be installed on each kilovar meter to prevent reverse operation of the meter.
7. Interconnection
Customers taking service under this Schedule shall have no electrical interconnection beyond the RCMU’s Point of Delivery between electrical loads eligible for service under this Schedule and any other electrical loads.
8. Temporary Discontinuance of Service.
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Where the use of energy is seasonal or intermittent, no adjustments will be made for a temporary discontinuance of service. Any Customer resuming service within twelve (12) months after such service was discontinued will be required to pay all charges which would have been billed if service had not been discontinued.
9. Customer-Owned Electrical Generating Facilities.
Upon written approval by the Utility, momentary parallel operation may be permitted to allow the Customer to test the auxiliary/emergency generating facilities.
10. Billing Calculation.
A Customer’s bill is calculated according to the rates and conditions above. The charges are calculated by applying the Rate Charges when applicable to the actual billing determinants (kilowatt hours [kWh], demand [kW], kilovar [kVa], etc.).
11. Power Cost Adjustment Factor (PCAF).
The rates above are subject to an adjustment as provided in Rule 12, Section E.
12. Change of Law Adjustment Factor (CLAF).
The rates above are subject to an adjustment as provided in Rule 12, Section F.
12. State Mandated Public Purpose Programs Charge.
State law requires all California electric utilities to establish a public purpose program charge of 2.85% of electric retail revenues to fund qualifying energy efficiency programs, renewable energy resources, research and demonstration projects, and services for low-income electricity customers.
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POWER COST ADJUSTMENT FACTOR
A. Applicability
The Power Cost Adjustment Factor (PCAF) is a charge per kWh which is used to adjust the Utility’s electric rates for the actual cost of purchasing and generating electric power and energy to service the Utility’s customers and to minimize fluctuations in rates.
The energy charge per kWh in each Rate Schedule recovers the costs of purchasing and delivering power and energy from all suppliers of power and energy, other suppliers and the cost of power from the Utility’s owned generating resources.
B. Territory
Within the entire territory served.
C. Calculation
The PCAF will be calculated using the most recent six (6) month’s actual power cost and applied to each customer’s following monthly billed energy (kWh).
The Adjustment shall be calculated according to the following formula:
PCAF = ((P/S) + L) – B
P = Wholesale power supplier cost*
S = Number of kilowatt-hours sold during the same time period as factor “P” L = System annual average losses
B = The average cost of power per kilowatt -hour sold and recovered through base retail rates
*Power Supplier Costs shall include all costs of power supply including but not limited to costs of power production, power purchases, transmission and wheeling payments, losses, CAISO, capacity, REC’s, environmental allowances and scheduling and dispatching.
D. Special Conditions
1. The PCAF, which may be either positive or negative, will be reviewed and revised monthly to reflect actual changes.
2. Should the PCAF ever exceed the base retail rate, the Utility will cap the PCAF for the billing month at the base retail rate and charge each customer the difference between the PCAF and the base retail rate in the next available subsequent billing month.
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SERVICE ESTABLISHMENT CHARGE
A. Applicability
Applicable to General Service and Domestic Service customers.
B. Territory
Within the entire territory served.
C. Rates
For each establishment of electric service…………… $15.00
D. Special Conditions
1. The service establishment charge provided for herein is in addition to the charges calculated in accordance with the applicable schedule and may be made each time an account is established. As used herein, establishment means each time an account is opened, including a turn on of electric service or a change of name which requires a meter reading.
2. In case the customer requests that electric service be established on the day of his request or outside of regular hours, an additional charge of $11.00 may be made.
DATE: November 19, 2025
TO: Mayor and Members of the City Council
FROM: John R. Gillison, City Manager
INITIATED BY: Jennifer Nakamura, CNU-A, Planning Director Aracely Estrada, Management Analyst I
SUBJECT: Consideration of First Reading of Ordinance No. 1051, to be Read by Title Only and Waive Further Reading, an Ordinance that Repeals Ordinance 89 Adopting a Design Review Procedure. (ORDINANCE NO. 1051) (CITY)
RECOMMENDATION:
Staff recommends that the City Council adopt Ordinance No. 1051, by approving a first reading, to be read by title only, and waive further reading, an ordinance which serves to repeal Ordinance 89 adopting a design review procedure that established a Design Review Committee and design review criteria.
BACKGROUND:
The City of Rancho Cucamonga has several advisory bodies that meet to review and make recommendations on policies and priorities. Advisory bodies play an important role in the governance of the City and provide valuable input to the City Council and the Planning Commission. An advisory body under the purview of the Planning Department is the Design Review Committee (DRC). The DRC is not an authoritative body, but rather, a recommending body subject to the authority of the Planning Commission.
Advisory committees like the DRC abide by administrative regulations set forth in the Municipal Code and applicable state laws such as the Ralph M. Brown Act. Administrative regulations are intended to guide the committees on matters related to policies, duties, operations, and procedures.
ANALYSIS:
In 1979, the DRC was established under Ordinance 89 and by Resolution No. 79-61. Both the Ordinance and the Resolution provided the DRC with procedures to follow and authorized the DRC the right to develop its own rules and regulations for conducting its meetings and for developing its own criteria and standards.
Although provisions of Municipal Code section 17.04.020 Administrative Responsibility–Planning Agency, and the City of Rancho Cucamonga’s 2023 Boards/Commissions/Committees Staff Liaison Handbook offered more updated administrative regulations than did the Resolution and Ordinance, neither the Municipal Code nor the Staff Liaison Handbook provided sufficient details specific to the DRC. Thus, Resolution No. 2025-033 was created to provide updated
3 1
4 3
administrative regulations. Resolution 2025-033 repeals Resolution No. 79-61 and adopts DRC Bylaws. The Resolution was approved and adopted by the Planning Commission on October 22, 2025.
Accordingly, it was determined that Ordinance 89 is obsolete and consequently, should be repealed.
FISCAL IMPACT:
None.
COUNCIL MISSION / VISION / VALUE(S) ADDRESSED:
This item supports the City Council’s core values of relentless pursuit of improvement.
ATTACHMENTS:
Attachment 1 - Draft Ordinance No. 1051
Ordinance No. 1051 - Page 1 of 3
ORDINANCE NO. 1051
AN ORDINANCE OF THE CITY OF RANCHO CUCAMONGA,
CALIFORNIA, REPEALING ORDINANCE NO. 89 ADOPTING A
DESIGN REVIEW PROCEDURE WHICH ESTABLISHES A
DESIGN REVIEW COMMITTEE AND DESIGN REVIEW
CRITERIA
The City Council of the City of Rancho Cucamonga does ordain as follows:
Section 1. Recitals.
A. In 1979 t he City Council of the City Rancho Cucamonga (“City”) adopted Ordinance 89 and the City’s Planning Commission adopted Resolution 79-61, both collectively establishing the Design Review Committee as an advisory body to the Planning Commission and City Council and applicable governing regulations in order to support the implementation of the General Plan.
B. The Design Review Committee is a recommending body with the authority to review architectural and site plan elements as defined by Municipal Code Section 17.04.020.
The Design Review Committee has further been operating under the guidance of established documentation such as Rancho Cucamonga’s 2023 Boards/Commissions/Committees Staff Liaison Handbook.
C. In order to better define the role of the Design Review Committee considering recent changes to State law governing land use and land development procedures, City staff have prepared draft administrative regulations , otherwise referred to as the DRC Bylaws.
Planning Commission Resolution 2025- 033 repealed the previous Planning Commission Resolution 79-61.
D. On October 22, 2025, the Planning Commission of the City of Rancho Cucamonga considered the proposed DRC Bylaws, and following the receipt of public comment, adopted Resolution No. 2025 -033 approving the DRC Bylaws and repealing Planning Commission Resolution 79-61.
E. The City Council desires to repeal Ordinance No. 89, as the Planning Commission’s adoption of the DRC Bylaws by adoption of Resolution No. 2025-033 now provide the governing regulations for the Design Review Committee.
Section 2. Ordinance.
A. Recitals. The City Council finds the foregoing recitals and their findings to be true and correct, and hereby incorporates such recitals and their findings into this Ordinance.
B. Ordinance No. 89 (An Ordinance of the City of Rancho Cucamonga, California, Adopting a Design Review Procedure Which Establishes a Design Review Committee and Design Review Criteria) is hereby repealed in its entirety.
Attachment 1
Ordinance No. 1051 - Page 2 of 3
Section 3. CEQA. Pursuant to the California Environmental Quality Act (“CEQA”) and the City’s local CEQA Guidelines, the City Council finds that adoption of this Ordinance is covered by general rule that CEQA applies only to projects which have the potential for causing a significant effect on the environment. The City Council finds that there is no possible significant effect directly related to adoption of this Ordinance, therefore no further action is required under CEQA pursuant to Section 15061(b)(3) of the State CEQA Guidelines (14 CCR § 15061(b)(3)).
This is becaus e this Ordinance will result in no potential development that could have an environmental impact.
Section 4. Severability. The City Council declares that, should any section, subsection, subdivision, sentence, clause, phrase, or portion of this Ordinance for any reason be held invalid or unconstitutional by the decision of any court of competent jurisdiction, such decision shall not affect the validity of the remaining portions of this Ordinance. The City Council hereby declares that it would have adopted this Ordinance and each section, subsection, subdivision, sentence, clause, phrase, or portion ther eof, irrespective of the fact that any one or more sections, subsections, subdivisions, sentences, clauses, phrases, or portions thereof be declared invalid or unconstitutional.
Section 5. Effective Date. This Ordinance shall be in full force and effective thirty (30) days after its adoption, and shall be published or posted as required by law.
Section 6. Publication. The City Clerk shall certify to the adoption of this Ordinance and shall cause it to be published in the manner required by law.
Ordinance No. 1051 - Page 3 of 3
PASSED, APPROVED, AND ADOPTED this __ day of November, 2025.
L. Dennis Michael, Mayor
ATTEST:
__________________________
Kim Sevy, City Clerk
STATE OF CALIFORNIA )
COUNTY OF SAN BERNARDINO ) ss
CITY OF RANCHO CUCAMONGA )
I, Kim Sevy, City Clerk of the City of Rancho Cucamonga, California, do hereby certify that the foregoing Ordinance was introduced at a Regular Meeting of the City Council of the City of Rancho Cucamonga held on the 19
th day of November, 2025, and was passed at a
Regular Meeting of the City Council of the City of Rancho Cucamonga held on the 3rd day of December, 2025.
AYES:
NOES:
ABSENT:
ABSTAINED:
Executed this ____ day of December, 2025, at Rancho Cucamonga, California.
__________________________
Kim Sevy, City Clerk
DATE:November 19, 2025
TO:Mayor and Members of the City Council
President and Members of the Board of Directors
FROM:John R. Gillison, City Manager
INITIATED BY: Peter Castro, Deputy City Manager
Julie A. Sowles, Deputy City Manager
Jevin Kaye, Finance Director
Rick Flinchum, Deputy Finance Director
Darrell Richardson, Management Analyst II
Adriana Camacho, Management Analyst I
SUBJECT: Consideration to Receive and File the First Quarter Financial Update for the Fiscal Year 2025/26 and to Approve Additional Appropriations in the Amount of $3,090,670 in Revenues and $4,695,800 in Expenditures. (CITY/FIRE)
RECOMMENDATION:
Staff recommends the City Council and Board of Directors of the Rancho Cucamonga Fire Protection District receive and file the attached quarterly financial update for the first quarter of the Fiscal Year 2025/26 and approve additional appropriations in the amount of $3,090,670 in Revenues and $4,695,800 in Expenditures as outlined in the fiscal impact section.
BACKGROUND:
Every quarter, the City Manager’s Office and the Finance Department provide the City Council and Board of Directors with a brief update on the financial performance of the City’s operating funds, consisting of the General Fund, Library Fund, and the Fire District’s primary operating funds. The report also includes an economic update for the City Council.
Additional appropriations are also requested with the presentation of this report to provide necessary funding for additional and adjusted operations consistent with the performance of the first quarter of the fiscal year.
ANALYSIS:
The quarterly financial update provides the City Council with a detailed analysis of revenues and expenditures across all major operating funds. With approximately 25% of the fiscal year complete, overall financial performance is tracking within expected ranges based on historical trends and current budget assumptions. Staff will continue to monitor key revenue categories and expenditure patterns closely and will make targeted adjustments as needed to maintain balanced operations and ensure continued fiscal stability.
As is typical during the first quarter of the fiscal year, instances where departmental expenditures appear to exceed the 25 percent benchmark are largely the result of encumbrances established at the beginning of the year. These encumbrances represent planned commitments such as
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contracts, purchase orders, and ongoing service agreements, rather than actual expenditures.
This practice serves as a proactive budget management tool to reserve funds for known obligations and prevent departments from exceeding their approved appropriations. Each department’s encumbrances that contribute to variances from the benchmark have been reviewed and summarized within this report for Council’s reference.
Major revenue sources are generally performing in line with expectations for the first quarter.
Property tax revenues are not received until December and will be reflected in the second quarter’s report, while sales tax collections ordinarily begin in August or September and are included on a lagging basis. Other revenue streams such as licenses and permits, fines and forfeitures, and charges for services, are tracking near the 25 percent benchmark relative to annual budget projections. Overall, first quarter revenues indicate a stable and seasonally typical start to the fiscal year.
The report also includes an analysis of the most recently available economic data, including unemployment rates, the size of the labor force, consumer price index, residential real estate and prices, and summarized trends in sales tax. An overview of the information presented in the report is as follows:
As of August 2025, the City’s unemployment rate has increased slightly to 5.9% compared to the same period in the prior year. Despite the slight uptick, the City’s unemployment remains slightly more favorable than those in the local region and throughout San Bernardino County and the State of California.
In September 2025, the consumer price index rose 3.5% year-over-year, primarily driven by escalating costs in food and energy. In line with regional and nationwide trends, inflation seems lower than in recent years, but still slightly persistent. As a result, we have seen a couple of interest rate cuts from the Fed over the last year. Consumer confidence is cautious amid concerns of impending economic headwinds, though trends do not indicate heavy risk factors at this time.
FISCAL IMPACT:
Requested appropriations are outlined in detail on Attachment 2 to this staff report and are summarized below:
Total Revenue Requests: $3,090,670 Total Expenditure Requests: $4,695,800 General Fund (F001): $1,602,740 General Fund (F001): $864,520 Includes $441,000 in Reimbursable Costs
Fire Fund (F281): $1,409,780 Fire Fund (F281): ($850,340) Library Fund (F290): $78,150 Special Revenue Funds: $4,681,620 In the General Fund, Fire Fund, and Library Fund, as mentioned in the Financial Update, the property tax revenue budget is being revised due to higher than anticipated projections from the City’s property tax consultant. Staff have included these revisions as appropriations requests in Attachment 2 to this Staff Report.
Note: Because these appropriations are being approved in November, the revised property tax figures are not reflected in the Financial Update document included as Attachment 1. Upon City Council approval, the updated figures will be incorporated into the Second Quarter Financial Update prepared by the Finance Department in March 2026.
These revenue revisions also offset the Finance Contract staffing appropriation approved by City Council on September 16, 2025. The costs were originally planned to be funded through vacancy savings in the Sheriff’s Contract, though will now be covered by the additional expected revenues.
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Increases in the General Fund are also being requested to recognize additional property transfer tax revenue in the current fiscal year. The City previously forecasted property transfer tax revenue at $302,000 in response to declining sales activity. However, based on a review of recent receipts and a sustained, though lower, level of sales activity, the Finance Department is revising its projection to $750,000 for the fiscal year.
Furthermore, increases in General Fund revenue are being requested to recognize reimbursements for on-call services and higher than anticipated interest earnings in the City’s investment portfolio.
With respects to expenditures, requests in the General Fund are included for several Engineering and Public Works Department items for expanded on-call services along with ongoing fleet and facility maintenance projects, infrastructure and HVAC repairs, and safety and monitoring upgrades.
The largest items within the requested appropriations are two Major Projects in the Engineering Department funded by the Road Maintenance and Rehabilitation Act (RMRA) Fund. These include $2.67 million for the Vineyard Avenue Major Arterial Paving Project and $1.46 million for the Highland Avenue Major Arterial Paving Project. Both projects were originally included in the Major Projects Program (MPP) adopted by the City Council as part of the June 26, 2025 Budget.
However, due to a clerical omission during final budget preparation, the appropriations were not reflected in the final document. As such, these two projects are included in the current appropriations request to formally provide funding to the Engineering Department for project commencement.
The Fire Fund shows a reduction in expenditure due to budget corrections and shifts of a capital vehicle purchase to the Fire Capital Fund.
Requests are included for several special revenue funds as part of ongoing service additions, adjustments for higher than anticipated contract bids, and new service additions and equipment purchases that are being added for Fiscal Year 2025/26.
COUNCIL MISSION / VISION / GOAL(S) ADDRESSED:
Providing the City Council with regular financial updates supports the City Council’s goals of intentionally embracing and anticipating the future by receiving timely financial information upon which they can base their current and future decisions.
ATTACHMENTS:
Attachment 1 – FY 2025/26 First Quarter Financial Update Attachment 2 – FY 2025/26 First Quarter Requested Appropriations
ATTACHMENT 1
Quarterly Financial Update
Quarter Ended
September 30, 2025
1 UPDATE ON COUNCIL GOALS
As part of the quarterly update, the City Manager’s Team is providing an update on Council Goals for FY 2025/26.
Updates are provided in italics as part of this report:
Goal 1:
By the end of October 2025, bring a project to add lights to the Garcia Sports Field to the City Council for consideration.
The City conducted a comprehensive community engagement process from June 24 through July 30, 2025 to gather feedback on the proposed addition of sport field lighting at Garcia Park, including the installation of new electrical infrastructure, foundations, light poles, and LED lighting at the existing single ballfield. Efforts included mailers to households in Landscape Maintenance District 9 (LMD 9), community pop-up events, and a virtual community meeting.
Generating 908 responses, staff confirmed strong community interest in field lighting and validated the project’s inclusion in the City’s Major Projects Program. Accordingly, the Garcia Park Field Lighting Project is ready to advance to the next phase of implementation —construction and installation — in alignment with the Fiscal Year 2025–2026 Major Projects Program.
Goal 2:
By the end of December 2025, present to the City Council a plan and implementation strategy for workforce development pathways into public service.
In March 2025, staff presented the PathwaysRC plan to the City Council. This plan outlined a vision and goals for creating pathways to public service through various connections and programs for three specific groups: 1) Elementary and Middle School students, 2) High School students, and 3) Early Career Individuals. Following this presentation, staff was assigned the task of refining the Pathways RC plan and developing an implementation strategy as part of the City Council’s annual goal-setting process. To facilitate this, a staff subcommittee was formed to work on the updated plan and strategy. The subcommittee is expected to present their findings to the City Council in December 2025.
Goal 3:
By the end of December 2025, present to the City Council concept plans to modernize and expand the public safety facilities at the Civic Center.
City and Sheriff personnel worked with a design consultant to develop a needs and operations assessment, deployment options and concept design, and preliminary cost estimates to incrementally improve and modernize the police headquarters building. Based on feedback, the consultant is refining the scope and developing a full set of design plans and cost estimates. This is expected at the end of November 2025.
Goal 4:
By the end of June 2026, complete construction on Phase 2 of ATMS.
The expected completion of construction for ATMS Phase 2 is Q2 of 2026 along the corridors of Milliken Ave, 19th St., Arrow Rte., Rochester Ave., and Day Creek Blvd.
Goal 5:
3 By the end of June 2026, finalize the site location and high-level concept design details for the second RCMU substation.
Since Council passed a FY 2025/26 goal for a second RCMU substation, several important milestones have been achieved. A site location of approximately 4.61 acres has been identified at Napa Street and Etiwanda, adjacent to the Southern California Edison (SCE) Etiwanda Substation. High-level conceptual site plans and single line diagram plans have been drafted and were submitted to SCE to be incorporated into two concurrent studies. The two SCE studies look at feasibility and SCE-related backend infrastructure costs required to either implement a 66kV Interconnection with SCE (with a 66kV Substation very similar to existing RCMU Arbor Substation) or a 230kV Interconnection to serve a new 100MVA Transmission Load (which would double the capacity of the existing RCMU Arbor Substation). The first SCE study was completed at the beginning of October 2025, and the second study is expected in early December 2025.
Once the second study is completed, Staff will evaluate the studies and recommend to Council which substation path to pursue based on total cost, benefits to the community, feasibility, and timeliness for construction.
1 INTRODUCTION AND EXECUTIVE SUMMARYY
The City Manager’s Office and Finance Department are
providing this quarterly financial report to the City Council with a high-level overview of the City's financial status through the quarter end, and an overview of economic
indicators that can influence the City's revenues and
expenditures.
This report has several components:
1.Quarterly Report: This report includes budget to
actual variance analysis for revenues and
expenditures for July 1, 2025, through September 30,
2025. The quarterly report provides this detail for the General Fund, Fire District, and Library Fund.
2.Economic Brief: This report compiles economic
information and indicators, such as employment data,
sales tax data, and other local and regional economic
news.
After the first quarter of the fiscal year, the City's
financial status is in line with expectations. Significant accounts and notable variances are presented in this
quarterly financial report.
The tables in this report compare budgeted to actual
amounts for the General Fund, Fire District, and Library.
The year-to-date (YTD) financials are unaudited actuals and presented with encumbrances requested throughout
the quarter. The revised budget includes budget
adjustments, encumbrance carryovers from the prior
fiscal year, and any supplemental appropriations
approved by the City Council throughout the quarter. The percent of the budget
(% Bud) is the percentage received/spent of the budget.
The prior year-to-date (PYTD) financials show comparable information from the same quarter of the prior fiscal year.
The report uses colored icons to illustrate how well the category is doing financially. Green indicates that
performance is within expected parameters, yellow
signals areas being monitored closely, and red denotes
issues requiring corrective action or further attention.
As of the first quarter, no departments show a Red status, demonstrating sound overall budget performance.
GENERAL FUND OVERVIEW
The City’s General Fund is the primary fund used to pay for a variety of programs and services that are provided to people and businesses in Rancho Cucamonga. This
includes programs and services offered by different
departments of the City.
Overall, the revenues (amount of money coming in) and
expenditures (going out) of the General Fund are within the expected range, accounting for items like seasonal
changes and ongoing expenses.
Currently, the amount of money spent or encumbered
from the General Fund is 30% of the total budget for the year. This includes both general expenses that benefit the whole city, as well as the costs of running individual
departments. This report will focus on analyzing the
expenses for each department within the General Fund.
The table above includes departmental and non-departmental spending. Non-departmental expenditures are excluded from the operating departmental analysis section.
2 General Fund Revenues
Primary revenue sources for the General Fund are
property tax, sales tax, franchise fees, and transient
occupancy tax. Collectively, these comprise about 82% of the annual budget.
Property Tax. The first major apportionment of property tax occurs in December each year. The City partners with a property tax consultant to continually monitor and
project property tax revenues. The adopted budget
assumed a 4% increase over the prior year. Based on
updated projections from the consultant, this Financial Update adjusts the budget to reflect a 5.3% increase over the prior year, consistent with continued growth in
assessed valuations and stable activity in the region.
Property taxes include property tax in lieu of vehicle
license fees budgeted for $27.9 million and residual
property tax for the form RDA budgeted for $3.6 million.
Both revenue sources are received in installments later in the fiscal year.
Note: As part of this quarterly financial update, a request is being made for additional appropriations to the
property tax budget for FY 2025/26. Though these
additional figures are not reflected in the chart above, upon approval, they will be reflected in the Second
Quarter Financial Update in March 2026.
Sales Tax. Sales tax is the largest single source of revenue for the City. As such, City staff and consultants monitor how much sales tax is coming in closely. The sales tax
received to date is slightly lower, but ultimately on-par with the prior year-to-date. As the city heads into Quarter 2, the peak months of November and December will help
provide data to adjust forecasts for the remainder of the year. Note that due to timing of receipts, only one month (July) is reflected in the actuals for Quarter 1 each year.
Franchise Fees/Transient Occupancy Taxes. Transient
Occupancy Taxes (TOT) and Franchise Fees comprise 13%
of the taxes received by the General Fund. Franchisees
remit payment to the City on recurring schedules, but not in the first quarter of the year. Gas and electric franchise fees are received in the year's final quarter. At the same time, refuse and cable franchise fees are received after the quarter. TOT is remitted by hotels to the City monthly.
The budget estimate projects growth of approximately
18.7% from the prior year's budget, based on the opening of the Sanctity Hotel during the last fiscal year and the increases forecasted as a result of the passage of Measure Q in November 2024.
Licenses and Permits. After the end of the first quarter, actual revenue is at 27% of the budget. The largest
category of this section is business licenses, which
comprise almost 60% of the budget. In the first quarter, these receipts are as expected.
Fines and Forfeitures. Includes vehicle and parking fines and citations comprise 70% of the fines and forfeitures budget, and other general fines and forfeitures. This
category includes vehicle code fines collected by San
Bernardino County and remitted to the City. At the end of the first quarter, fines and forfeitures are in line with expectations.
Charges for Services. Charges for services refer to the amounts collected for specific services provided by the departments. Includes various community development
fees, such as plan check, planning, and engineering fees, comprise 70% of the budget, and recreation fees make up 28%. As of the first quarter, charges for services are
performing well at 38% of expected budget for the year.
Intergovernmental. The bulk of this category includes
motor vehicle in-lieu fees and homeowners property tax
relief revenues from the County, which are predominantly received later in the year.
4 Transfers In. Transfers represent the transfers of
resources from other funds to the General Fund and are
typically booked starting in the second quarter.
Other Revenues. Includes interest earned on invested
funds, rental and lease income, reimbursements, and
miscellaneous revenues. Reimbursements represent 28%
of this category. Revenues fluctuate heavily in this
category due to timing of receipts but are within
expectations for those reimbursements expected in the
first quarter.
General Fund Departmental Expenditures
Expenditures for the General Fund can vary because of
the timing of vendor payments, carryover of purchase
orders from the prior year, and the changes in operations during the year. Therefore, even if expenditures are above or below the benchmark of 25%, departments could be
within the expected range due to their need to issue
purchase orders and blanket encumbrances at the start of each fiscal year for operations.
Personnel:
Last fiscal year marked the first time fringe benefit costs were distributed to departments in real time as they were incurred, rather than allocated in full at the start of the year. With this process now fully implemented, current
personnel costs are more comparable to prior year-to-
date figures. This approach continues to provide a more accurate and timely reflection of actual expenses
throughout the year.
Cost Allocations
Departments that provide services that benefit the City have their budgets reduced to reflect the allocation of the cost of those services to the benefiting departments. This is the Cost Allocation category within the department’s budget. These are typically booked beginning in Quarter 2 of each fiscal year.
Department Summaries
The Administrative Services budget is in the process of being merged with the overall City Management budget
as its costs solely cover costs for the Deputy City Manager assigned to Administrative Services. In Quarter 2, the
Finance Department will be reclassifying transactions in this category to correct expenditures and close this
budget out.
For Animal Care and Services, professional services are over three-fourths of the budget at 79% for the year.
Professional services include encumbrances for recurring programs, such as professional spay and neuter services, as well as laboratory testing services. The budgets for these categories will be monitored to ensure
overspending does not occur but overall are within the
expected range.
In Building & Safety, professional services are at 98% due to fully encumbered contracts with consultants to assist with building examinations and plan check services to aid in operations. The budget for this category will be
monitored, but is overall within expectations.
5 For City Clerk and Records Management, overall
operations and professional services are within expected ranges. Because this fiscal year is a non-election year, some expenditures are lower than in the prior year.
City Council expenditures are meeting expectations.
Operations and maintenance expenses can vary as they
primarily consist of travel and meetings. Spending is
expected with current activity and will adjust as further travel is scheduled.
In the City Manager’s Office, personnel expenses are
tracking lower due to pending reclassifications from
Administrative Services. Once completed, expenses will
be as expected for the department.
Overall budget for the City Manager’s Office will appear lower year-to-year due to the separation of budgets
within the newly formed Engagement & Special Programs
department, described below.
This fiscal year marks the first full budget where Healthy RC, the Community Affairs Network (CAN), and RCMU
were integrated into a single Engagement & Special
Programs Department. All previous budgets for these
divisions are now reflected in the single graphic above and show that expenditures are tracking as expected.
Professional services are at 72% of budget due to
encumbrance activity for planned Healthy RC and CAN
services for the fiscal year.
For Community Improvement, professional services
expenses, which primarily include legal fees for
abatements, civil litigation, and other necessary services, are at 42% of the budget.
In Community Services, operations and maintenance and
professional services are approximate to the benchmark, at 20% and 35% of their respective budgets. Operations
and maintenance and professional services can vary
depending on the timing of events. In the current fiscal year, significant expenditures represent special
programming and consulting of the Victoria Gardens
Cultural Center, as well as planned spending for additional subsites for the Lewis Family Playhouse and Second Story and Beyond®.
Capital Outlay includes spending and encumbrances for
portable radios, a sound system, and camera equipment
for the Victoria Gardens Cultural Center.
In Economic Development, operations and maintenance
are near the benchmark at 20% of the budget. The current fiscal year spending is lower than the prior year due to the timing of bills to vendors but is within the expected ranges overall.
Professional services are 43% of their budget due to
encumbrances for marketing, branding, and
communications services for specific efforts.
6 In the Engineering Department, professional services are at 88% of its budget, which includes spending on
engineering on-call plan check services and other land
development services to aid in reviewing large projects.
In Finance, professional services are at 34% of the budget.
Expenses are higher than the adopted budget due to the
ongoing accounting services contract related to staff
turnover and onboarding of new staff.
This fiscal year marks the first full year of the realignment of this previous budget into two departments: Human
Resources & Organizational Development.
The Human Resources budget is showing near benchmark
across all activities. As the fiscal year continues, HR typically sees higher spending activity in Quarter 2
onward, so receipts are as expected currently.
As mentioned above, the Organizational Development
department was formed last fiscal year, and this year
marks its first full budget year and includes the Risk
Management division. Spending across categories is as
expected and tracking below the benchmark in Q1.
For the Innovation and Technology Department,
professional services are at 56% of the budget due to
software subscriptions and support services. These are
often encumbered and paid for at the beginning of the
year and include some support costs for new systems
implemented in support of the Workday implementation.
For the Planning Department, professional services are
above the benchmark at 52% due to contracts
encumbered for the full year for CEQA services,
environmental review services, and other planning
services. Many of these costs are reimbursed to the City.
For the Police Department, operations and maintenance
covers events, training, and other crime prevention
activities and are tracking as expected. The “Other”
category includes capital costs associated with office
furniture renewal in the department headquarters.
Professional services are primarily dedicated to the
contract with the San Bernardino County Sheriff for
policing services in the City.
7 In the Public Works Department, operations and
maintenance are above the benchmark at 53% of the
budget, mainly due to internal service user fees for vehicle and equipment charges from the City’s Equipment and
Vehicle Replacement Fund at the beginning of the fiscal year. This fee accounts for the immediate and long-term capital replacement needs for the City’s vehicles and
equipment. It is charged at the start of the year.
Professional services are at 88% of the budget due to
encumbrances for maintenance contracts made at the
beginning of the fiscal year, including park, vehicle,
equipment, and street maintenance.
Capital outlay expenditures are for the recurring citywide concrete repair project.
LIBRARY FUND OVERVIEW
The Library Fund has spent 20% of its total budget for the year, while the revenues are 17% of the total budget.
Library Revenues
Property Tax. The Library Fund receives a portion of the property taxes collected by the City. The first major
apportionment of property tax occurs in December each
year. As mentioned in the City’s analysis, preliminary
assessed valuation reports suggest that growth may be
near 5.3% over the prior year. As such, the Library
Revenue budget will be adjusted accordingly in this first quarter financial update. Also included in the property tax revenue category is a total of $2.5 million in statutory and residual payments from the dissolution of the former
redevelopment agency, which are received later in the
year.
7 Library Expenditures.
Operations and maintenance spending are above the
benchmark at 34% of the budget. This is because of
encumbrances of printed and digital books, materials, and supplies for the two libraries made at the start of each fiscal year.
Professional services spending is at 30% of the budget, which is approximate to the prior year, and due to
encumbrances for security services, cataloging services, and other materials at both libraries.
FIRE DISTRICT OVERVIEW
The Fire District is responsible for keeping the community safe by providing fire prevention and suppression
services. It includes the Fire General Fund and two
Community Facilities Districts (CFD) 85-1 and 88-1. The City has eight fire stations that are currently operational.
The Fire District’s expenditures are at 23% of the budget, while revenues are at 1% of the budget.
Fire District Revenues
Property Tax. The first major apportionment of property tax occurs in December each year. As mentioned in the
City’s analysis, the property tax forecast for this fiscal year shows an increase of 5.3% over the prior year, and
adjustments are accordingly included in the
appropriations requested for the first quarter.
The property tax revenue budget includes $22.3 million
for statutory payments from the dissolution of the former redevelopment agency, which are received later in the
year.
CFDs 85-1 and 88-1 levy special taxes for funding
administration, personnel services, maintenance, and
operations within the CFDs' boundaries. Combined, the
CFDs will collect $8.6 million and receive a $6.9 million contribution of resources from the Fire District’s General Fund to subsidize operations. The budget contribution is shown as a Transfer In (revenue) to the CFDs and
Transfers Out (expenditure) from the Fire District in the summary, revenue, and expenditure tables for the Fire
District. As mentioned for the City, transfers will be
booked beginning in the second quarter.
Other Revenues. Other revenue includes interest earned
on invested funds, rental and lease income,
reimbursements, and miscellaneous revenues.
Reimbursements from the Other Post-Employment
Benefits (OPEB) Trust for the retiree healthcare costs
comprise 48% and other non-abated reimbursements,
which primarily consist of CalOES, comprise 20% of the
budget. Finance requests reimbursements from the OPEB
Trust for retiree healthcare costs near the end of each fiscal year, and reimbursement from CalOES for fire
support depends on the timing of reimbursement receipts
9 processed by the state agency. As of the first quarter, results are within expectations.
Fire District Expenditures
Personnel services are higher than prior year, but right at the benchmark of 25% of budget. Operations and
maintenance are at 38% of the budget due to the timing
of expenditures and encumbrances necessary for
operations. For example, the payment of the general
liability insurance premium occurred within the first
quarter of the current fiscal year but not in the first quarter of the prior fiscal year.
Despite the timing of these transactions, overall
operations and maintenance appear to be within
expected ranges.
Professional services are at 39% of the budget due to
spending and encumbrances for various contract services necessary for fire administration, communications, and
facilities maintenance, and are comparable with the prior year.
Cost allocation represents the estimated service costs
that City departments expend to benefit the Fire District.
As mentioned in the City analysis, the Cost Allocations will begin assessment in the second quarter of this fiscal year.
10 ECONOMIC BRIEF
The economic brief provides information on economic indicators that can be used to measure and track economic activity at a local level. The economy is a combination of individual, business, and government spending or investment at the national, regional, and local levels. Governments of all levels keep an eye on these economic factors to assess the strength of the economy. This section of the brief focuses on indicators that can help track aspects of the local economy.
Statewide, Regional and Local Labor Market
According to preliminary August 2025 figures, San Bernardino County had an unemployment rate of 5.9%, which is approximate to the average unemployment rate for the State of California.
The graph below shows the unemployment rates (not seasonally adjusted) for the largest Counties and Metropolitan Areas statewide for August 2025:
Source: Employment Development Department, State of California
11 At a local level, the City’s unemployment rate for August 2025 was 4.9%. The City’s unemployment rate is lower but also consistent with changes in the unemployment rate for the County and State.
Source: Employment Development Department, State of California The graph above illustrates the historical unemployment rate for the City, County, and State.
12
12 Consumer Price Index
US headline inflation rose to 2.9% year-over-year in August, with core inflation rising to 3.1%. The Federal Reserve lowered interest rates by 25 basis points, continuing the recent trend of gradual rate cuts over the past year. This lowers the interest rate target to a range of 3.75% to 4.00% during its October policy meeting due to the progress made on inflation.
CPI is also calculated for cities and metropolitan areas, which helps consider more localized factors that affect price changes. Over the two months ending in September 2025, the Consumer Price Index for All Urban Consumers (CPI-U) in the Riverside area increased by .05%. The CPI for this area was recorded at a level of 137.71, consistent with the rate of 137.45 two months prior and up 3.5% from one year ago.
From September 2021 to September 2025, there has been a notable decrease in the percentage change in CPI-U, with the inflation rate peaking around March 2022 and then gradually fluctuating.
Within the area, food prices increased by 3.5% over the year, with prices for food at home increased by 2.1% and prices for food away from home increasing by 5.4%. Energy prices decreased by 1.8% over the year, largely due to lower prices for gasoline (-5.2%). The index for all items less food and energy rose by 3.9% over the year.
The graph below presents the rolling 12-month change for CPI for the Riverside-San Bernardino-Ontario area.
Source: Bureau of Labor Statistics
13 Sales Tax
Sales tax revenue is a primary source of revenue for the City. It is generated from retail and business activity, whether that be from sales within the City or sales tax receipts allocated from State and county pools. City staff closely monitors sales tax, not only for its fiscal impacts on operations but also at a policy level, ensuring revenue streams are healthy and diversified.
As of September 2025, various macroeconomic indicators and consumer spending trends in California depict a mixed picture, which may have implications for sales tax revenues for local governments. Nationwide, retail sales grew by 5.0% over the past year, indicating consistent sales growth despite the fluctuating inflation nationwide.
Inflation measures appear to be stabilizing overall, following gradual increases over the past year. However, a poll from the Public Policy Institute of California revealed that roughly six in ten Californians expect bad economic times to lie ahead. This perception might affect consumer spending and, consequently, sales tax revenues.
At a Statewide level, sales tax revenue showed a slight decrease of 1.0% for the Fiscal Year 2024-25. As the holiday shopping season approaches, expectations are that buyers will start spending sooner. Some consumers are expected to spend less as stubborn inflated prices for household obligations (utilities, insurance, and food) take priority over purchasing non-essential and gift items. The California Legislative Analyst’s Office anticipates statewide sales tax revenue to be relatively flat through the 2025-26 fiscal year.
For the City, sales tax revenues have remained consistent and the City anticipates projections to stay relatively flat. Continuous adaptation to changing consumer behaviors, price fluctuations, and other economic challenges will be just as necessary as it has been over the last two years. The growth in e-commerce, the shift towards in- state fulfillment, and changing sales tax allocations are critical factors that might impact sales tax revenues in the coming fiscal years.
The chart below depicts a breakdown of business sectors that generate sales tax for the City as of the most recent sales tax data available.
ATTACHMENT 2
FY 2025/26 First Quarter Financial Update
Request.for.First.Quarter.Appropriations.(City― Fire.District) Appropriations to Revenues
Account Codes Description Amount Justification
F001|CC000|RC0001 General Fund
Property Tax-Unsecured $36,630 Increased due to higher property tax forecast at 5.3%.
F001|CC000|RC0201 General Fund
Property Tax-Residual $20,250 Increased due to higher property tax forecast at 5.3%.
F001|CC000|RC0301 General Fund
Property Tax-In Lieu of VLF $150,380 Increased due to higher property tax forecast at 5.3%.
F001|CC000|RC0302
General Fund
Property Tax-
Supplemental
$1,570 Increased due to higher property
tax forecast at 5.3%.
F001|CC000|RC0303 General Fund
Property Tax-Unitary $5,180 Increased due to higher property tax forecast at 5.3%.
F001|CC000|RC0304 General Fund
Property Transfer Tax $447,130
Increased due to higher receipts
in prior fiscal year and higher
than anticipated sales activity.
F001|CC000|RC3000 General Fund
Interest Earnings $500,000
Increasing revenue budget for
interest earnings due to higher
than anticipated returns on the
City’s investment portfolio.
F001|CC305|RC6104
General Fund
Engineering
Reimbursements
$441,600
Increased reimbursement
revenue associated with on-call
plan check services and
appraisal services. This line
corresponds with a request in
the Expenditures section of this
report.
F281|CC501|RC0001 Fire Fund
Property Tax-Unsecured $310,600 Increased due to higher property tax forecast at 5.3%.
F281|CC501|RC0002 Fire Fund
Property Tax-Secured $4,260 Increased due to higher property tax forecast at 5.3%.
F281|CC501|RC0200 Fire Fund
RPTTF Passthrough $280,000 Increased due to higher property tax forecast at 5.3%.
F281|CC501|RC0302
Fire Fund
Property Tax-
Supplemental
$13,940 Increased due to higher property
tax forecast at 5.3%.
F281|CC501|RC0303 Fire Fund
Property Tax-Unitary $10,980 Increased due to higher property tax forecast at 5.3%.
F281|CC501|RC6105
P0116
Fire Fund
Reimbursement Revenues $750,000
Increased due to additional
strike team costs. This line
corresponds with a reimbursable
expenditure request in the
Expenditures section of this
report.
F281|CC501|RC6103
P0116
Fire Fund
Reimbursement Revenues $40,000
Increased due to anticipated
reimbursement of fire incident
costs. Corresponds with a
request in the Expenditures
section of this report.
F290|CC601|RC0001 Library Fund
Property Tax-Unsecured $45,670 Increased due to higher property tax forecast at 5.3%.
F290|CC601|RC0002 Library Fund
Property Tax-Secured $620 Increased due to higher property tax forecast at 5.3%.
F290|CC601|RC0200 Library Fund
RPTTF Passthrough $31,860 Increased due to higher property tax forecast at 5.3%.
General Fund Total $1,602,740
Fire Fund Total $1,409,780
Library Fund Total $78,150
Total Revenue Adjustments $3,090,670
Appropriations to Expenditures
Account Codes Description Amount Justification
F001|CC305|SC2106
General Fund
Engineering
Contract Services
$431,600
Additional funding for on-call
plan check services. These
costs are reimbursable to the
City and are aligned with the
revenue line request in the
Revenues Section of this report.
F001|CC307|SC2108
General Fund
Engineering
Contract Services
$10,000
Additional funding for
additional appraisal services.
These costs are reimbursable to
the City and are aligned with the
revenue line request in the
Revenues Section of this report.
F001|CC312|SC2101
General Fund
Public Works-Facilities
Contract Services
$422,920
Appropriations include funding
for fleet and facility
maintenance projects,
emergency building and
infrastructure repairs,
replacement of key mechanical
and HVAC systems, safety and
monitoring upgrades, software
subscriptions, and unplanned
operational costs.
F110|CC303|SC7004
PID-2112-110
Beautification Fund
Engineering
Capital Outlay
$31,820
Additional project costs related
to the San Sevaine Trail Project.
Additional funds come from
residual balance in
Beautification Fund.
F124|CC307|SC7004
PID-2086-124
Transportation DIF Fund
Engineering
Capital Outlay
$125,000
Additional costs for the ongoing
City Center Boulevard Project.
These additional funds are
aligned with a grant that will
later be reimbursed to the City.
F130|CC319|SC2105 LMD 1
Public Works-Parks $72,100 Parks Mowing and Facility
Landscape Contract received
Contract Services bids and were returned higher
than anticipated.
F133|CC319|SC2105
LMD3
Public Works-Parks
Contract Services
$64,160
Additional landscape
maintenance services for new
sites, including 9/11 memorial
park and 8th/Hellman.
F134|CC319|SC2105
LMD4
Public Works-Parks
Contract Services
$25,930
Additional costs in parks
landscape and facility
maintenance contracts.
F136|CC320|SC2105
LMD6-R
Public Works-Parks
Contract Services
$141,320
Additional West Coast Arborist
contract services and
additional costs for pesticides,
fertilizers, and fencing costs.
F137|CC312|SC2106
LMD7
Public Works-Parks
Contract Services
$1,700
Additional costs not included in
adopted budget for pesticides
and fertilizers for park
maintenance.
F139|CC320|SC2105
LMD9
Public Works-Parks
Contract Services
$12,350 Additional costs for contract
mowing and fertilizer services.
F174|CC307|SC7004
PID-2198-174
Gas Tax Fund
Engineering Capital Outlay $20,950
Additional project costs related
to the survey work for the Local
Overlay Pavement
Rehabilitation project.
F177|CC307|SC7004
PID-2198-177
Measure I Fund
Engineering
Capital Outlay
$34,610
Additional survey work costs
related to the Local Overlay
Pavement Rehabilitation
Project.
F179|CC307|SC7004
PID-2196-179
Road Maintenance Fund
Engineering
Capital Outlay
$2,678,960
Project costs for the Vineyard
Ave. Major Arterial Paving
Project were included in the
Major Projects Program for
FY2025/26, but were
erroneously omitted in the final
budget entry process.
F179|CC307|SC7004
PID-2104-179
Road Maintenance Fund
Engineering
Capital Outlay
$1,460,000
Project costs for the Highland
Ave. Major Arterial Paving
Project were included in the
Major Projects Program for
FY2025/26, but were
erroneously omitted in the final
budget entry process.
F179|CC307|SC7004
PID-2097-179
Road Maintenance Fund
Engineering
Capital Outlay
$1,050
Additional costs related to
Geotech investigations for the
Base Line Road Major Arterial
Paving Program.
F198|CC303|SC2104
PID-2112-198
City Infrastructure Fund
Engineering
Contract Services-Legal
$5,030 Additional legal costs related to
the San Sevaine Trail Project.
F198|CC303|SC2104
PID-2086-198
City Infrastructure Fund
Engineering
Capital Outlay
$112,220
Additional legal costs related to
the Yellowwood Connection
project.
F198|CC303|SC7004
PID-000217
City Infrastructure Fund
Engineering
Capital Outlay
$18,190
Additional legal costs related to
the Etiwanda Grade Separation
project.
F227|CC313|SC0003
GR-000110
Used Oil Recycling Fund
Public Works
Personnel – Overtime
$17,300
Additional overtime costs
associated with Household
Hazardous Waste Collection.
F281|CC501|SC1201
Fire Fund
Fire Administration
Operations
($718,740)
Costs for minor equipment and
small tools were included in the
Fire Capital Budget for this
Fiscal Year. These funds are not
needed for the year.
F281|CC527|SC2000
P0114
Fire Fund
Vehicle & Equipment Maint.
Interfund Reimbursements
($316,140)
Funds associated with
reimbursements to the City
were overstated in budget and
are being corrected to actual
activity for the year.
F281|CC501|SC2200
P0122
Fire Fund
Fire Administration
Insurance Premiums
$15,780 Increases due to higher than
anticipated CIRA premiums.
F281|CC508|SC0004
P0026|A0122
Fire Fund
Fire Suppression
Reimbursable Overtime
$750,000
Increase to reimbursable
overtime budget to
accommodate for additional
strike team deployment. This
line has a corresponding
revenue line and is
reimbursable to the District.
F281|CC508|SC1003
P0116
Fire Fund
Fire Suppression
Operations – Reimbursable
$28,000
Increases to reimbursable fire
incident costs. This line has a
corresponding revenue line and
is reimbursable to the District.
F281|CC529|SC2000
P0114
Fire Fund
Fire Administration
Interfund Reimbursements
$140,760
Correcting interfund
reimbursements and account
coding for District
reimbursement of Fire
Maintenance Workers.
F288|CC501|SC2106
P0128
Fire Capital Fund
Fire Administration
Contract Services
$11,300
Additional costs associated
with roof repair design for Fire
District facilities.
F288|CC501|SC7007
P0110
Fire Capital Fund
Fire Administration
Capital Outlay
$60,000
Funds for fire mechanic vehicle
were budgeted in F281
(Interfund Reimbursements).
Purchase will now be done
directly by the District out of the
Capital Fund.
F700|CC312|SC2101
Sports Complex Fund
Public Works-Facilities
Contract Services
$70,240 Replacement costs for facility’s
fire door manual hand crank.
F705|CC304|SC7009
PID-2181-705
RCMU Fund
Capital Outlay
Utility Equipment
$120,350
Acquisition of Supervisory
Control and Data Acquisition
(SCADA) system for RCMU
operations.
F712|CC001|SC7002 Vehicle Replacement Fund
Public Works $102,850 Conclusion of purchase
activities from FY2024/25,
Capital Outlay including final costs for
replacement of Diesel Utility
vehicle and bunker rake.
F714|CC001|SC0001 Tech. Replacement Fund
Personnel-Salaries ($103,720)
Personnel costs associated to
the Workday project were
budgeted and are no longer
needed.
F714|CC001|SC1200 Tech. Replacement Fund
Minor Equipment $145,000
Additional costs for PSVN
Camera Replacement not
previously included in budget.
F714|CC001|SC7002 Tech. Replacement Fund
Capital Outlay-Equipment ($688,000)
Budget correction for Data
Network Refresh project that
was over-appropriated.
F848|CC303|SC1606
P0048 A0284
PD-85
Public Works
Water Utilities
$71,210
Additional water utilities costs
for PD-85 parks that were
erroneously omitted from the
adopted budget.
F868|CC319|SC2105
CFD 2000-03
Public Works
Contract Services
$49,560
Parks Mowing and Facility
Landscape Contract received
bids and were returned higher
than anticipated.
F876|CC318|SC2106
CFD 2018-01
Public Works
Contract Services
$21,190
Additional unanticipated costs
related to signal maintenance
that exceed adopted budget.
Total s: Amount Notes
F001 General Fund $864,520 ₰ 007? 666.in.Reimbursable.
Costs
F110 Beautification Fund $31,820
F124 Transportation DIF $125,000
F130 LMD 1 $72,100
F133 LMD3 $64,160
F134 LMD 4 $25,930
F136 LMD 6-R $141,320
F137 LMD 7 $1,700
F139 LMD 9 $12,350
F174 Gas Tax Fund $20,950
F177 Measure I Fund $34,610
F179 Road Maintenance & Rehab. Fund $4,138,960
F198 City Infrastructure Fund $135,440
F277 Used Oil Recycling Program $17,300
F281 Fire Fund ($850,340)
F288 Fire Capital Fund $71,300
F700 Sports Complex Fund $70,240
F705 Rancho Cucamonga Municipal Utility (RCMU) $120,350 F712 Vehicle Replacement Fund $102,850
F714 Computer/Equipment Replacement Fund ($646,720)
F848 PD-85 Fund $71,210
F868 CFD 2000-03 $49,560
F876 CFD 2018-01 $21,190
Grand Total $4,695,800
Budget.Amounts.that.are.decreasing.are.shown.in.(Parentheses)