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HomeMy WebLinkAboutAgenda Report - March 1, 2017 G-02 PHCITY OF LODI COUNCIL COMMUNICATION AGENDA ITEM G- 2 TM AGENDA TITLE: Public Hearing to Consider Introducing an Ordinance Amending Lodi Municipal Code Chapter 13.20 — Electrical Service — by Repealing and Reenacting Article III, "Rates," in Its Entirety MEETING DATE: March 1, 2017 PREPARED BY: Electric Utility Director RECOMMENDED ACTION BACKGROUND INFORMATION: Public hearing to consider introducing an ordinance amending Lodi Municipal Code Chapter 13.20 — Electrical Service by repealing and reenacting Article III, "Rates," in its entirety. In 2014, a 10 -year financial planning model was completed to identify revenue requirements for the Lodi Electric Utility (LEU) through 2024 which called for a five -percent rate increase to address deferred maintenance and capital infrastructure needs of the utility. The five -percent increase was approved by the City Council and implemented effective January 2, 2015 across all electric utility rate classes. In addition, staff recommended annual inflationary increases of no more than two percent through 2019 to be brought back to the City Council for consideration as the financial model was updated and the need arose; it was noted at the time that the Council also preferred smaller inflationary increases. The financial model has been updated through 2025 and is attached as Exhibit A. Rate revenue has been forecasted based on updated Toad projections, taking into consideration both the loss of General Mills and additional growth resulting from new development and business expansion within LEU's service territory. Power supply costs comprise approximately 55 percent of LEU's annual budget. These expenses have been forecasted based on costs associated with existing generation resources, transmission access charges, and costs associated with meeting State mandates for greenhouse gas emissions and Renewables Portfolio Standard requirements. Non -power supply costs, including debt service, contributions to the General Fund, energy efficiency, and operating and capital expenses, comprise the remaining 45 percent of LEU's annual budget. Operating expenses, including labor and supply/material costs, continue to rise and have been projected to increase annually between two and 2.5 percent. Capital costs total over $20 million to address deferred maintenance and needed system improvements, including: underground and overhead infrastructure; substation maintenance and improvements; vehicles and equipment; streetlight repairs, maintenance, and LED replacements; security upgrades and improvements; distribution capacity upgrades; implementation of a Meter Data Management System; and 230 kV Interconnection Project planning. Not included in the model are design and construction costs APPROVED: Stephen Sch 'uer, City Manager Public Hearing to Consider Introducing an Ordinance Amending Lodi Municipal Code Chapter 13.20 — Electrical Service — by Repealing and Reenacting Article III, "Rates," in Its Entirety March 1, 2017 Page 2 of 3 associated with the 230 kV Interconnection Project as it is anticipated that savings realized from reduced transmission access charges will mitigate the debt costs associated with the project during this planning period. Based on projections, LEU is anticipated to experience an annual deficit ranging from approximately $1.5 million in FY 2016/17 to over $2 million by FY 2024/25. LEU cash reserves are projected to be reduced from a current estimated $25.3 million in 2017 to $13 million by 2025. Additional rate revenue is necessary to meet debt service coverage requirements, gradually close the annual projected deficit for non -power supply costs, sufficiently fund deferred capital maintenance, and meet reserve targets set forth by City Council policy and contractual requirements. To provide the additional revenue as identified above, LEU is proposing a one-time increase of two -percent, effective May 1, 2017. Each year, the LEU reviews the Handy Whitman Index (HWI) to evaluate cost trends. The HWI, published since 1924, calculates cost trends for various types of utility construction and provides an index relative to the electric industry and even more specific to electric distribution systems. LEU did not request an inflationary increase in 2016 as it was focused instead on a revenue neutral effort to better align costs and charges. This proposed two -percent increase will address inflationary trends for the past two years but to a lesser extent than those indicated by the HWI for the past two years (3.3 percent and 1.5 percent). Failure to approve the rate increases subjects the LEU to system reliability issues resulting from additional deferred maintenance; an inability to meet reserve requirements; and possible downgrading by rating agencies resulting in future higher costs. An average residential customer using 550 kWh per month will see an increase of Tess than $2 per month. Increases to commercial and industrial customers will vary depending on average use and demand for each rate class. Approving incremental adjustments such as this will help avoid future potential rate shock while maintaining the financial integrity and bond rating of the City's electric utility. LEU is also proposing modifications to Schedule ED (Residential SHARE Program Service), Schedule EP (Energy Purchase), Schedule ES (City Facilities Service), and Schedule EV (Electric Vehicle Pilot Charging Rate) to better align these schedules with the recent changes approved by City Council to address the changing utility business model. With the exception of Schedule EP (Energy Purchase), most of the proposed changes are administrative in nature. For Schedule EP (Energy Purchase), staff proposes a mechanism by which to continue to compensate customers who install self -generation such as solar, as LEU has reached the cap at which it is no longer required by law to offer net energy metering (NEM). NEM is a billing mechanism which compensates customer generators at the full retail rate for electricity they generate on-site. Doing so allows customers to reduce and avoid charges on their electric bill while still remaining interconnected to LEU's distribution grid, thus shifting costs to customers with no on-site generation. Based on the currently installed and pending customer solar systems, that cost shift is estimated to be approximately $850,000 annually. Since LEU has reached its cap, it is no longer required to offer NEM. A continuance of NEM, as currently structured, will increase cost shifts to non -customer generators. The new EP tariff does not affect current customer generators on LEU's existing NEM rate; these customers will continue to receive compensation under the current NEM rate schedule 20 years from the date of their system's interconnection. In summary, Schedule EP will require the customer to pay all Public Hearing to Consider Introducing an Ordinance Amending Lodi Municipal Code Chapter 13.20 — Electrical Service — by Repealing and Reenacting Article III, "Rates," in Its Entirety March 1, 2017 Page 3 of 3 charges associated with their total consumption and be compensated for the full amount of their generation at LEU's avoided cost. LEU will update its avoided cost annually and is currently calculating what that initial cost will be. On November 15, 2016, City and LEU staff met with representatives from the California Solar Energy Industries Association (CAL SEIA) as well as multiple solar contractors to discuss the proposed Schedule EP. If approved, Schedule EP will be available to customers May 1, 2017. This will provide sufficient time to meet all of the necessary public hearing requirements and draft new specifications and interconnection requirements associated with the new tariff. LEU will continue to accept solar and rebate applications for review. These applications will begin to be processed in the order received once the final Schedule EP tariff is approved, the avoided cost calculations are complete and all engineering specifications and interconnection requirements have been completed. LEU staff are exploring the feasibility of other options (including billing capability, metering equipment requirements, and compatibility with the City's current fixed network) and will bring those options back for review and consideration at a later date if so desired by the Council. This update to Article III — "Rates" will include all rate schedules whereas previously some of the schedules were only referenced as exhibits to the ordinance and not actually displayed in the Lodi Municipal Code. It is recommended these changes, along with the two -percent rate increase, take effect May 1, 2017. FISCAL IMPACT: The proposed rate increase is anticipated to provide an additional $11.7 million in rate revenue through 2025 as illustrated in Exhibit B. A summary of the proposed changes is included as Exhibit C. Actual revenue realized will depend on customer growth and energy sales. FUNDING AVAILABLE: Not applicable..2 Elizabeth A. Kirkley Electric Utility Director PREPARED BY: Melissa Price, Rates & Resources Manager EAK/MCP/Ist LODI ELECTRIC UTILITY FINANCIAL FORECAST- BEFORE RATE ADJUSTMENT EXHIBIT A Account 15/16 Act 16/17 Est 17/18 Forecast 18/19 Forecast 19/20 Forecast 20/21 Forecast 21/22 Forecast 22/23 Forecast 23/24 Forecast 24/25 Forecast Total Rate Revenue $67,507,179 $68,526,450 $68,619,720 $68,990,448 $70,374,737 $71,980,232 $73,246,337 $74,351,202 $75,239,775 $72,745,393 Additional Rate Revenue from Proposed Adjustments $0 $0 $0 50 $0 $0 $0 $0 $0 $0 Loan Proceeds $1,500,000 $0 $0 50 50 $0 $0 $0 $0 $0 Other Revenue (Op and Non -Op) $4,763,522 $3,754,790 $3,435,274 53,448,040 $3,289,166 $2,194,530 $1,037,250 $1,037,250 $1,037,250 $1,037,250 Total Revenue $73,770,701 $72,281,240 $72,054,993 $72,438,488 $73,663,904 $74,174,761 $74,283,587 $75,388,452 $76,277,025 $73,782,643 Power Supply $38,632,485 $40,434,980 $40,926,847 $41,159,111 $42,404,244 $43,869,886 $44,995,439 $45,959,050 $46,705,662 $44,068,610 Construction & Maintenance 55,358,548 56,663,040 $6,838,295 $7,020,414 $7,209,804 57,406,901 $7,559,800 $7,715,876 $7,875,195 $8,037,826 Engineering & Operations $2,136,109 $2,722,260 $2,794,295 $2,869,179 $2,947,080 $3,028,180 $3,090,738 $3,154,596 $3,219,784 $3,286,327 Administrative & General (A&G) 51,717,043 $2,343,610 $2,399,264 $2,456,733 $2,516,111 $2,577,495 52,630,041 $2,683,662 $2,738,381 $2,794,221 In -Lieu Taxes $7,082,070 $7,131,330 $7,181,249 $7,231,518 $7,282,139 $7,333,114 $7,384,445 $7,436,137 $7,488,190 $7,540,607 Internal Cost of Service $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 Capital Funded from Rates 53,559,155 $4,500,711 $2,401,000 $3,121,000 $2,431,000 $2,161,000 $1,966,000 $1,375,000 $1,140,000 $1,140,000 Debt Service / Loan Repayment $8,168,594 $5,528,520 $5,538,575 $5,523,125 $5,519,375 $5,514,000 $5,522,950 $5,510,025 $5,268,650 $5,264,275 Funding of Capital Reserves $250,000 $250,000 $250,000 5250,000 $ - $ - $ - $ - $ - $ - Public Benefits/Solar $1,603,767 $2,190,160 $1,611,763 $1,643,998 $1,676,878 $1,710,416 $1,744,624 $1,779,517 51,815,107 $1,851,409 Total Expenses $70,611,771 573,868,611 572,045,289 $73,379,079 $74,090,631 $75,704,991 $76,998,037 $77,717,863 $78,354,969 $76,087,275 Surplus/(Deficit) $3,158,930 (51,587,371) $9,705 ($940,590) ($426,727) (51,530,229) (52,714,450) (52,329,410) (52,077,944) (52,304,632) 15/16 Act 16/17 Est 17/18 Forecast 18/19 Forecast 19/20 Forecast 20/21 Forecast 21/22 Forecast 22/23 Forecast 23/24 Forecast 24/25 Forecast Proposed Rate Adjustments 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0% Available Cash $26,936,574 $25,349,203 $25,358,908 $24,418,317 $23,991,591 $22,461,361 $19,746,911 $17,417,501 $15,339,557 $13,034,925 Operating Reserve Requirement (90 Days) $17,776,000 $17,350,000 $17,411,072 $17,564,520 $17,914,908 $18,385,998 $18,758,009 $19,085,716 $19,303,742 $18,736,819 Days Cash 138 133 133 127 122 111 96 83 73 63 Capital Reserve Funded ($1M Target) $ 250,000 $ 500,000 $ 750,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 Overall Target (Operating, Capital, NCPA GOR) $ 23,155,000 $ 22,776,000 $ 22,911,072 $ 23,064,520 $ 23,414,908 $ 23,885,998 $ 24,258,009 $ 24,585,716 $ 24,803,742 $ 24,236,819 % of Target 116.3% 111.3% 110.7% 105.9% 102.5% 94.0% 81.4% 70.8% 61.8% 53.8% LODI ELECTRIC UTILITY FINANCIAL FORECAST- AFTER RATE ADJUSTMENT (2%) EXHIBIT B Account 15/16 Act 16/17 Est 17/18 Forecast 18/19 Forecast 19/20 Forecast 20/21 Forecast 21/22 Forecast 22/23 Forecast 23/24 Forecast 24/25 Forecast Total Rate Revenue $67,507,179 $68,526,450 $68,619,720 $68,990,448 $70,374,737 $71,980,232 $73,246,337 $74,351,202 $75,239,775 $72,745,393 Additional Rate Revenue from Proposed Adjustments $0 $189,640 $1,375,894 $1,383,327 $1,411,084 $1,443,276 $1,468,662 $1,490,816 $1,508,633 $1,458,618 Loan Proceeds $1,500,000 $0 $0 $0 $0 $0 $0 $0 $0 $0 Other Revenue (Op and Non -Op) $4,763,522 $3,754,790 $3,435,274 $3,448,040 $3,289,166 $2,194,530 $1,037,250 $1,037,250 $1,037,250 $1,037,250 Total Revenue $73,770,701 $72,470,880 $73,430,887 $73,821,816 $75,074,988 $75,618,037 $75,752,250 $76,879,268 $77,785,658 $75,241,261 Power Supply $38,632,485 $40,434,980 $40,926,847 $41,159,111 $42,404,244 $43,869,886 $44,995,439 $45,959,050 $46,705,662 $44,068,610 Construction & Maintenance $5,358,548 $6,663,040 $6,838,295 $7,020,414 $7,209,804 $7,406,901 $7,559,800 $7,715,876 $7,875,195 $8,037,826 Engineering & Operations $2,136,109 $2,722,260 $2,794,295 $2,869,179 $2,947,080 $3,028,180 $3,090,738 $3,154,596 $3,219,784 $3,286,327 Administrative & General (A&G) $1,717,043 $2,343,610 $2,399,264 $2,456,733 $2,516,111 $2,577,495 $2,630,041 $2,683,662 $2,738,381 $2,794,221 In -Lieu Taxes $7,082,070 $7,131,330 $7,181,249 $7,231,518 $7,282,139 $7,333,114 $7,384,445 $7,436,137 $7,488,190 $7,540,607 Internal Cost of Service $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 $2,104,000 Capital Funded from Rates $3,559,155 $4,500,711 $2,401,000 $3,121,000 $2,431,000 $2,161,000 $1,966,000 $1,375,000 $1,140,000 $1,140,000 Debt Service / Loan Repayment $8,168,594 $5,528,520 $5,538,575 $5,523,125 $5,519,375 $5,514,000 $5,522,950 $5,510,025 $5,268,650 $5,264,275 Funding of Capital Reserves $250,000 $250,000 $250,000 5250,000 $ - $ - $ - $ - $ - $ - Public Benefits/Solar $1,603,767 $2,190,160 $1,611,763 $1,643,998 $1,676,878 $1,710,416 $1,744,624 $1,779,517 $1,815,107 $1,851,409 Total Expenses $70,611,771 573,868,611 $72,045,289 $73,379,079 $74,090,631 $75,704,991 $76,998,037 $77,717,863 $78,354,969 $76,087,275 Surplus/(Deficit) $3,158,930 ($1,397,731) $1,385,599 I $442,737 $984,357 ($86,954) (81,245,788) ($838,594) (S569,311) ($846,014) 15/16 Act 16/17 Est 17/18 Forecast 18/19 Forecast 19/20 Forecast 20/21 Forecast 21/22 Forecast 22/23 Forecast 23/24 Forecast 24/25 Forecast Proposed Rate Adjustments 0.0% 0.3% 1.7% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0% Available Cash $26,936,574 $25,538,843 $26,924,441 $27,367,178 $28,351,535 $28,264,582 $27,018,794 $26,180,199 $25,610,888 $24,764,874 Operating Reserve Requirement (90 Days) $17,776,000 $17,350,000 $17,411,072 $17,564,520 $17,914,908 $18,385,998 $18,758,009 $19,085,716 $19,303,742 $18,736,819 Days Cash 138 134 141 142 144 140 131 125 121 121 Capital Reserve Funded ($1M Target) $ 250,000 $ 500,000 $ 750,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 Overall Target (Operating, Capital, NCPA GOR) $ 23,155,000 $ 22,776,000 $ 22,911,072 $ 23,064,520 $ 23,414,908 $ 23,885,998 $ 24,258,009 $ 24,585,716 $ 24,803,742 $ 24,236,819 % of Target 116.3% 112.1% 117.5% 118.7% 121.1% 118.3% 111.4% 106.5% 103.3% 102.2% EXHIBIT C Lodi Electric Utility Proposed 2017 Rate Changes Energy Tier(s) Rate(s) Current Proposed RESIDENTIAL - Schedule EA Customer Charge N/A $ 10.00 $ 10.20 Energy Charge - Summer ($/kWh) Tier 1 0 - 481 kWh / month $ 0.1400 $ 0.1428 Tier 2 482 - 962 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 962 kWh / month $ 0.3300 $ 0.3366 Energy Charge - Winter ($/kWh) Tier 1 0 - 391 kWh / month $ 0.1400 $ 0.1428 Tier 2 392 - 782 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 782 kWh / month $ 0.3300 $ 0.3366 MOBILE HOME PARK - Schedule EM Customer Charge (Master Meter Customer) N/A $ 1.00 $ 1.02 Energy Charge - Summer ($/kWh) Tier 1 0 - 481 kWh / month $ 0.1400 $ 0.1428 Tier 2 482 - 962 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 962 kWh / month $ 0.3300 $ 0.3366 Energy Charge - Winter ($/kWh) Tier 1 0 - 391 kWh / month $ 0.1400 $ 0.1428 Tier 2 392 - 782 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 782 kWh / month $ 0.3300 $ 0.3366 DUSK -TO -DAWN LIGHTING - Schedule EL 6,000 lumen gas discharge lamp (each) - per billing cycle N/A $ 12.76 $ 13.02 18,000 lumen gas discharge lamp (each) - per billing cycle N/A $ 23.69 $ 24.16 CITY FACILITIES - Schedule ES Minimum Charge N/A $ 5.25 $ Customer Charge N/A $ - $ 10.20 Energy Charge ($/kWh) All kWh $ 0.10948 $ 0.10890 COMMERCIAL/INDUSTRIAL - Schedule G1 (< 8,000 kWh/month] Customer Charge Single -Phase Service N/A $ 7.35 $ 7.50 Three -Phase or Combination Service N/A $ 10.87 $ 11.09 Energy Charge ($/kWh) Summer See Notes $ 0.18883 $ 0.19261 Winter See Notes $ 0.13965 $ 0.14244 COMMERCIAL/INDUSTRIAL - Schedule G2 (> 8,000 kWh/month) Customer Charge N/A $ 59.20 $ 60.38 Demand Charge ($/kW) N/A $ 4.10 $ 4.18 Energy Charge ($/kWh) Summer See Notes $ 0.15519 $ 0.15829 Winter See Notes $ 0.12423 $ 0.12671 COMMERCIAL/INDUSTRIAL - Schedule G3 -S (Secondary) (400 kW - 500 kW/month] Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 4.10 $ 4.18 Peak Demand Charge - Summer ($/kW) N/A $ 11.47 $ 11.70 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.16890 $ 0.17228 Part -Peak See Notes $ 0.13528 $ 0.13799 Off -Peak See Notes $ 0.11621 $ 0.11853 Energy Charges Winter ($/kWh) Part -Peak See Notes $ 0.12259 $ 0.12504 Off -Peak See Notes $ 0.11188 $ 0.11412 Page 1 of 3 EXHIBIT C COMMERCIAL/INDUSTRIAL - Schedule G3 -P (Primary) (400 kW - 500 kW/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 3.17 $ 3.23 Peak Demand Charge - Summer ($/kW) N/A $ 10.76 $ 10.98 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.16280 $ 0.16606 Part -Peak See Notes $ 0.13086 $ 0.13348 Off -Peak See Notes $ 0.11274 $ 0.11499 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.11880 $ 0.12118 Off -Peak See Notes $ 0.10862 $ 0.11079 COMMERCIAL/INDUSTRIAL - Schedule G4 -S (Secondary) (500 kW - 1,000 kW/month] Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 4.10 $ 4.18 Peak Demand Charge - Summer ($/kW) N/A $ 11.47 $ 11.70 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.15592 $ 0.15904 Part -Peak See Notes $ 0.12225 $ 0.12470 Off -Peak See Notes $ 0.10322 $ 0.10528 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.11031 $ 0.11252 Off -Peak See Notes $ 0.09969 $ 0.10168 COMMERCIAL/INDUSTRIAL - Schedule G4 -P (Primary) (500 kW - 1,000 kW/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 3.17 $ 3.23 Peak Demand Charge - Summer ($/kW) N/A $ 10.76 $ 10.98 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.14988 $ 0.15288 Part -Peak See Notes $ 0.11791 $ 0.12027 Off -Peak See Notes $ 0.09981 $ 0.10181 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.10657 $ 0.10870 Off -Peak See Notes $ 0.09647 $ 0.09840 COMMERCIAL/INDUSTRIAL - Schedule G5 -S (Secondary) (> 1,000 kW/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 4.10 $ 4.18 Peak Demand Charge - Summer ($/kW) N/A $ 11.47 $ 11.70 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.14365 $ 0.14652 Part -Peak See Notes $ 0.11005 $ 0.11225 Off -Peak See Notes $ 0.09311 $ 0.09497 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.09825 $ 0.10022 Off -Peak See Notes $ 0.09009 $ 0.09189 Economic Stimulus Rate Credit ($/kWh) All kWh $ 0.00431 $ 0.00440 COMMERCIAL/INDUSTRIAL - Schedule G5 -P (Primary) (>1,000 kW/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 3.17 $ 3.23 Peak Demand Charge - Summer ($/kW) N/A $ 10.76 $ 10.98 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.13794 $ 0.14070 Part -Peak See Notes $ 0.10602 $ 0.10814 Off -Peak See Notes $ 0.08993 $ 0.09173 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.09481 $ 0.09671 Off -Peak See Notes $ 0.08706 $ 0.08880 Economic Stimulus Rate Credit ($/kWh) All kWh $ 0.00431 $ 0.00440 Page 2 of 3 EXHIBIT C EP ENERGY PURCHASE - Schedule EP Compensation for customer owned generation N/A Contract Basis Avoided Cost COMMERCIAL/INDUSTRIAL - OPTIONAL - Schedule 11 (>1,000 kW/month) - Special Conditions Apply Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 3.17 $ 3.23 Peak Demand Charge - Summer ($/kW) N/A $ 10.76 $ 10.98 Customers with demand < 4,000 kW: Energy Charges - Summer ($/kWh) Peak See Notes $ 0.14029 $ 0.14310 Part -Peak See Notes $ 0.10807 $ 0.11023 Off -Peak See Notes $ 0.09245 $ 0.09430 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.09972 $ 0.10171 Off -Peak See Notes $ 0.09177 $ 0.09361 Customers with demand >_ 4,000 kW Energy Charges - Summer ($/kWh) Peak See Notes $ 0.13378 $ 0.13646 Part -Peak See Notes $ 0.10156 $ 0.10359 Off -Peak See Notes $ 0.08594 $ 0.08766 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.09321 $ 0.09507 Off -Peak See Notes $ 0.08526 $ 0.08697 Economic Stimulus Rate Credit ($/kWh) All kWh $ 0.01359 $ 0.01386 ELECTRIC VEHICLE CHARGING SERVICE -Schedule EV Minimum Charge N/A $ 5.25 $ Customer Charge N/A $ - $ 3.00 Energy Charge ($/kWh) EV Charging Period Non -EV Charging Period NOTES: Summer (May 1 through Oct 31) Peak: 3 pm to 7 pm - Mon through Fri (except holidays) Part -Peak: 8:30 am to 3 pm and 7 pm to 9:30 pm - Mon through Fri (except holidays) Off -Peak: 9:30 pm to 8:30 am - Mon through Fri and all day Sat, Sun, holidays Winter (Nov 1 through Apr 30) Part -Peak: 8:30 am to 9:30 pm - Mon through Fri (except holidays) Off -Peak: 9:30 pm to 8:30 am - Mon through Fri and all day Sat, Sun, holidays EV Charging Period: 8 pm to 6 am - Mon through Fri (and all day weekends and holidays) Non -EV Charging Period: 6 am to 8 pm - Mon through Fri (excluding weekends and holidays) Schedule EA Tier See Notes $ 0.14910 1 Energy Charge Schedule EA Tier See Notes $ 0.34650 3 Energy Charge Holidays include: New Year's Day, Presidents' Day, Memorial Day, Independence Day, Labor Day, Veterans' Day, Thanksgiving Day, the day after Thanksgiving Day and Christmas Day. The dates will be based on those days on which the holidays are legally observed. Page 3 of 3 ORDINANCE NO. AN ORDINANCE OF THE LODI CITY COUNCIL AMENDING LODI MUNICIPAL CODE CHAPTER 13.20 – ELECTRICAL SERVICE – BY REPEALING AND REENACTING ARTICLE III "RATES" IN ITS ENTIRETY BE IT ORDAINED BY THE LODI CITY COUNCIL AS FOLLOWS: SECTION 1. Lodi Municipal Code Chapter 13.20 – Electrical Service is hereby amended by repealing and reenacting Article III. "Rates" in its entirety and shall read as follows: 13.20.175 13.20.180 13.20.185 13.20.190 13.20.200 13.20.210 13.20.220 13.20.225 13.20.227 13.20.230 13.20.235 13.20.240 13.20.250 13.20.260 13.20.270 13.20.280 13.20.290 13.20.300 13.20.310 13.20.315 13,v v20 13.20.325 Article III. – Rates Schedulo ECA Energy cost 34144strnentApplicability. Appl+cabilifySchedule ECA—Energy Cost AdIustment. Schedule CSS—California Solar Initiative Surcharge. Schedule EA—Residential Service. Schedule ED—Residential SHARE Program Service. Schedule EM—Mobilehome Park Service. Schedule MR—Residential Medical Rider. Schedule NEM—Net Energy Metering Rider. Conversion of Prior Schedule CEM—Co-Energy Metering Rider. Schedule EL—Outdoor Dusk -To -Dawn Lighting. Schedule ES—City Facilities Service. Schedule G1—General Service—Group 1 Commercial/Industrial. Schedule G2—General Service—Group 2 Commercial/Industrial. Schedule G3—General Service—Group 3 Commercial/Industrial. Schedule G4—General Service—Group 4 Commercial/Industrial. Schedule G5—General Service—Group 5 Commercial/Industrial. Schedule EP—Energy Purchase. Schedule SS—Standby Service. Schedule I1—General Service—Group 5 Commercial/Industrial—Optional. Schedule EDR—Economic Development Rates. Schedule NST—New Sales Tax Rate. Reserved. Schedule EV—Electric Vehicle Charging Service. * Editor's Note: The -sed rotes sh. preps n--oF-after May 1. 1998- .Reserved. 13.20.4-80175 APPLICABILITY. The sale of electric energy by the City shall be at the rates set forth in this article. 13.20.4-75180 SCHEDULE ECA—ENERGY COST ADJUSTMENT. A. Applicability. This schedule is applicable to all electric customers served by the City of Lodi. Each customer shall pay the applicable rate plus an energy cost adjustment (ECA) for each kilowatt-hour (kWh) delivered to the customer. The adjustment shall be the product of the total kilowatt-hours (kWh) for which the bill is rendered times the ECA amount per kWh. The purpose of the ECA is to adjust for increases/decreases to the City of Lodi's wholesale energy costs. This adjustment provides a mechanism to recover increased costs for wholesale energy or to lower collections when costs decrease below the base charge level. B. Rates: Effective July 6, 2007, the ECA billing factor for any given month shall be calculated as follows: Where ECA= (a) + (b) - (c)(d+f) - (f) (e) a. equals the amount the City of Lodi is actually charged by the Northern California Power Agency for the billing month, including adjustments for prior billing periods, less any third party revenue credits. b. equals the City of Lodi's estimated costs related to the acquisition of wholesale power, both financial and physical, procured directly by the city for the billing month, including adjustments for prior billing periods. c. equals the difference between actual retail energy sales and projected sales levels for the month which is two months prior to the billing month. d. equals the ECA billing factor for the month which is two months prior to the billing month. e. equals the forecast of projected retail energy sales for the billing month. f. equals the baseline energy cost for the city of $0.0831. The City of Lodi will recalculate the ECA each month, and resulting amount shall be automatically implemented for bills rendered during the following billing month. The ECA shall not be discounted. SCHEDULE 1-1 FIXED ECA OPTION: Customers must elect this option prior to the start of the twelve-month cycle (July -June) and must be billed for the entire twelve months under this option. Customers may opt out in the May prior to the next twelve-month billing period. The City of Lodi will calculate a fixed ECA based on projected sales divided by the budgeted NCPA all resource bill for the upcoming twelve-month period (July -June) minus eight point three one (8.31) cents. The resulting amount shall be automatically implemented for bills rendered during the eleven billing months beginning in July and ending in May. The June billing shall include a true -up for the actual ECA billed in the same eleven -month period and the actual ECA for the month of June. 13.20.185 SCHEDULE CSS—CALIFORNIA SOLAR INITIATIVE SURCHARGE. A. Applicability. 2 This schedule is applicable to all electric customers served by the City of Lodi. Each customer shall pay the applicable rate(s) plus the California Solar Initiative Surcharge (CSS) for each kilowatt-hour (kWh) delivered to the customer. The CSS shall fund incentives for customers participating in the Lodi Solar Rebate Pilot Program. California Senate Bill 1 (SB 1) mandates that all electric utilities offer a solar photovoltaic program that provides incentives to support the development and installation of solar systems throughout their given service territory. Based upon SB 1 funding requirements, Lodi Electric Utility shall make available approximately six hundred thousand dollars annually between the years 2008 — 2017. B. Rates. Effective on all bills rendered on or after January 1, 2008 until December 31, 2017, a surcharge per kilowatt-hour (kWh) will be applied to all kWh sold. The CSS shall be applied to all kWh sold and will be non -discounted. The surcharge amount of $0.00125 will be applied to all kWh consumed by each customer in all rate classes. All funds collected under this surcharge will be placed in an account solely for the purpose of implementing the Lodi Solar Rebate Pilot Program. 13.20.190 SCHEDULE EA—RESIDENTIAL SERVICE. For residential-Ben/ice rates, soe the` section. mance- A. Applicability: are sadified iR-thiE. This schedule is applicable to single-phase domestic power service in single-family and multi -family dwellings separately metered by the City including those on discontinued all electric rate schedule, EE. B. Rates: Customer Charge Energy Charge is by Tier of kWh usage: $4-9-9910.20 Tier 1 Tier 2 Tier 3 $/kWh $0.14000.1428 $0.15500.1581 $0.33000.3366 Summer (May through October) Energy Tiers Tier 1 0 Beginning Tier kWh/month Tier 2 Tier 3 482 >962 Ending Tier kWh/month 481 962 3 Winter (November through April) Energy Tiers Beginning Tier kWh/month Tier 1 Tier 2 Tier 3 0 Ending Tier kWh/month 392 391 782 >782 C. Energy Cost Adjustment (ECA) An energy cost adjustment shall be included in each bill for service as provided in 1 Section 13.20.1-7,5180 Schedule ECA – Energy Cost Adjustment. D. Billing Cycle Charge (Monthly Bill): The Billing Cycle Charge is the sum of the Customer Charge, the Energy Charge and the ECA. E. Special Conditions: a When a business or commercial establishment is conducted in conjunction with a residence and both are measured through one meter, this rate does not apply. b. This rate does not apply to service used for common area and facilities in multi- family dwellings. c. Additional discounts are available as described in Schedule MR, Residential Medical Discount and Schedule ED, Residential SHARE Program Service. F. Fixed Income Discount: For those customers who are on fixed incomes below $45,000 annually and who are over 62 years of age, and do not qualify for any other discount, a discount of 5% shall apply to the electric bill. Procedures as to qualification will be established by the Electric Utility Department. 13.20.200 SCHEDULE ED—RESIDENTIAL SHARE PROGRAM SERVICE. A. Applicability. Applicable to domestic service in single-family and multi -family dwellings separately metered by the City of Lodi where the customer meets all the special conditions of this rate schedule including those on discontinued all electric SHARE rate schedule, EF. B. Rates. Customers under this schedule will have bills computed using the EA rate schedule less a 30% discount. C. Energy Cost Adjustment (ECA). An energy cost adjustment shall be included in each bill for service as provided in 1 Section 13.20.180 Schedule ECA - Energy Cost Adjustment. 4 D. Billing Cycle Charge (Monthly Bill). The billing cycle charge is l,v F? -the sum of minimum the customer charge, and :,` the energy charge and the ECA. E. Special Conditions. 1. When a business or commercial establishment is conducted in conjunction with a residence and both are measured through one meter, this rate does not apply. This rate does not apply to service used for common area and facilities in multi- family dwellings. 3. Single Household Alternative Rate for Energy (SHARE) Eligibility: To be eligible to receive SHARE an applicant must complete an application and qualify based on the income eligibility criteria for state of California Low Income Home Energy Assistance Program. Completed applications must be submitted to the City of Lodi finance department. The City of Lodi finance department shall certify the eligibility of all applicants. All applicants will be required to certify income eligibility for the SHARE program. Customers must sign a statement upon application indicating that the City of Lodi may verify the customer's eligibility at any time. If verification established that the customer is ineligible, the customer will be removed from the program and the City of Lodi may render corrective billings. 6. An additional discount is available as described in Schedule MR, Residential Medical Discount. 13.20.210 SCHEDULE EM—MOBILEHOME PARK SERVICE. A. Applicability: This schedule is applicable to service supplied to mobile home parks through one meter and sub -metered to all individual mobile home units. B. Rates: 1 Customer Charge (Master Meter Customer)...$41.02 per individual mobile home park unit. Energy Charge is by Summer (May through October Tier 1 Tier 1 Tier 2 Tier 3 $/kWh $0.14000.1428 $0-1500.1581 $0:33000.3366 Summer (May through October Tier 1 Tier 2 Tier 3 5 Beginning Tier kWh/month Ending Tier kWh/month 0 482 481 962 >962 Winter (November through April) Energy Tiers Tier 1 Beginning Tier kWh/month 0 Ending Tier kWh/month 391 Tier 2 Tier 3 392 >782 C. Master Meter / Sub -Meter Discount: 782 For each occupied mobile home park unit, the park owner will receive a monthly discount in the amount of $3.00. D. Energy Cost Adjustment (ECA): An energy cost adjustment shall be included in each bill for service as provided in Section 13.2047180 Schedule ECA — Energy Cost Adjustment. E. Billing Cycle Charge (Monthly Bill): The Billing Cycle Charge is the sum of the Customer Charge kMaster Meter Customer), the Energy Charge, the Master Meter / Sub -Meter Discount and the ECA. F. Special Conditions: 1. This rate is available only for mobile home park master metering in service prior to March 31, 1989. 2. It is the responsibility of the master -metered customer to notify the City Finance Department by the 5th day of each month of any change in the number of occupied mobile home park units wired for service on the first day of that month. 3. Miscellaneous electric Toads such as general lighting, laundry rooms, general maintenance, and other similar use incidental to the operation of the premises as a multi -family accommodation will be considered domestic use. 4. For the master -metered Customer to qualify for Single Household Alternative Rate for Energy (SHARE) and/or the Residential Medical Discount, the qualified sub -metered tenants of the master -metered Customer must submit the applicable application(s), including the tenant's unit number, to the City of Lodi Finance Department. The City of Lodi Finance Department will notify the master -metered Customer in writing of the tenant's certification for these programs. 5. For tenants who are on fixed incomes below $45,000 annually and who are over 62 years of age, and do not qualify for any other discount, a discount of 5% of the qualifying tenant's electric bill (Fixed Income Discount) shall be provided to the master -metered Customer. Procedures as to qualification will be established by the Electric Utility Department. 6 6. The master -metered customer, not the City of Lodi, is responsible for extending the SHARE, Residential Medical Discount, and Fixed Income Discount to tenants certified to receive them. If verification establishes that the SHARE, Residential Medical Discount, or Fixed Income Discount tenant is ineligible, the tenant will be removed from the master -metered Customer's qualified tenants and the City of Lodi may render corrective billings. The master -metered Customer shall not bill any sub -metered tenant more than that tenant would be billed if that tenant were an individual customer of the City of Lodi. For a qualifying SHARE tenant, the master -metered Customer shall bill the qualifying tenant at the applicable rates equivalent to Schedule ED, Residential SHARE Program Service. For a tenant qualifying for a Residential Medical Discount, the master -metered Customer shall the bill the qualifying tenant in accordance with the provisions of Schedule MR, Residential Medical Discount. For tenants qualifying for a Fixed Income Discount, the master - metered Customer shall bill the qualifying tenant in accordance with the provisions of paragraph (e) herein. A tenant not qualified for any of the above discounts shall be billed using the rates and charges provided for in Schedule EM, Mobile Home Park Service, except the Master Meter / Sub -Meter Discount shall not be provided to tenants and the master -metered Customer shall not bill the tenant the Schedule EM, Mobile Home Park Service Customer Charge (Master Meter Customer). With the exception of the Customer Charge provided for in Schedule EA, Residential Service, the master-meter/sub-meter rate discount provided herein prohibits further recovery by mobile home park owners for the costs of owning, operating and maintaining their electric sub -metered system. Upon request, mobile home park owners must submit copies of their tenant billings to the City of Lodi for auditing to ensure compliance with this rate tariff, provided however that such requests shall not be made more often than semi- annually. 13.20.220 SCHEDULE MR—RESIDENTIAL MEDICAL RIDER. For residential medical -rider rates, see -the schedule attached to the ordinance codified in this section, marked Ex -hi -bit E --arid m e -a -part hereof -as -4f set out-ira-fulf- A. Applicability: Qualifying residential customers on Schedule EA are entitled to a discount of 25% from the total bill. Qualifying residential customers on Schedule ED are entitled to a discount of 5% from the total bill. Master -metered customers with qualifying tenant(s) on Schedule EA are entitled to a discount of 25% per billing cycle (monthly bill) for each qualifying household or mobile home unit. Master -metered customers with qualifying tenant's' on Schedule ED are entitled to a discount of 5% per billing cycle (monthly bill) for each qualifying household or mobile home unit. If a customer or full-time resident in the home or mobile home unit has one or more of the medical conditions listed below, contact the Electric Utility Department to request a City application, "Declaration of Eligibility for Medical Discount." Only one medical discount adjustment per household or mobile home unit is available. B. Qualifying Conditions: 7 To qualify for the Medical Discount, the customer will be required to submit a completed City application, including the certification of a doctor of medicine or osteopathy licensed to practice in the State of California that a customer or other full time resident in the home is: a. Dependent on a life-support device used in the home. b. Paraplegic, hemiplegic, or quadriplegic person having special air-conditioning needs. c. A multiple -sclerosis patient with special heating or air-conditioning needs. d. Medical conditions other than multiple sclerosis, paraplegia, hemiplegia, or quadriplegia may qualify customers for medical quantities for electric heating or air conditioning. Any such conditions will be reviewed on an individual basis. C. Life Support Devices: A life support device is any medical device necessary to sustain life or relied upon for mobility. To qualify under this schedule, the device must be used in the home and must run on electricity supplied by the City of Lodi. The term "life support device" includes, but is not limited to respirators, iron lungs, hemodialysis machines, suction machines, electric nerve stimulators, pressure pads and pumps, aerosol tents, electrostatic and ultrasonic nebulizers, compressors, IPPB machines and motorized wheelchairs. D. Heating and Air Conditioning: Special heating and/or air-conditioning needs will qualify for a Medical Discount only if the main source of energy for heating or air conditioning is electricity supplied by the City of Lodi. E. Medical Discount for Mobile Home Park Service Customers: Residential tenants of mobile home park service customers can also qualify for Medical Discount. If one or more of the customer's tenant(s) have a medical condition that qualifies under the conditions listed above, contact the Electric Utility Department to apply. Any Medical Discount must be passed on to the qualifying tenant(s) when tenants are billed for the electricity they use. 13.20.225 SCHEDULE NEM—NET ENERGY METERING RIDER. A. Purpose. The purpose of this rider is to establish rates, terms, and conditions for providing net metering services to customers generating electricity using solar and wind facilities of one MW or less in size. This rider complies with California State legislation requiring every electric utility in the state, including municipally -owned utilities, to develop a standard contract or tariff providing for net energy metering, as defined below. B. Applicability. This schedule is applicable to service for customers where a part or all of the electrical requirements of the customer can be supplied from a solar or wind power production source owned and operated by the customer (customer -generated). Availability of this schedule to eligible customer -generators will be on a first-come, first-served basis and will 8 be available until such time the total rated generating capacity used by eligible customer - generators equals five percent of the City of Lodi aggregate customer annual peak demand. The solar or wind generation source must: 1) have a capacity of one MW or less, 2) be located on the customer -generator's premises, 3) be connected for parallel operation with Lodi's distribution facilities, and 4) be intended for the sole purpose of offsetting a part or all of the customer -generator's own electrical requirements. In no case shall the power or energy generated by the customer -owned solar or wind source be available for resale, except as specified under this rider. Additional terms and conditions for service, including terms of interconnection and parallel operation, are specified in a customer -specific Electrical Interconnection and Net Energy Metering Payment Agreement. C. Rates. Charges for electricity supplied by the city will be based on metered usage in accordance with special conditions (D)(3) and (5) below. Rates charged under this schedule will be in accordance with the eligible customer -generator's otherwise applicable rate schedule. Public benefit charges and monthly customer charges shall not be by -passable. D. Special Conditions. Other Agreements. A signed electrical interconnection and net metering payment agreement between the customer -generator and the city is required for service under this schedule. 2. Metering Equipment. Net energy metering shall be accomplished using a single meter capable of registering the flow of electricity in two directions. If customer's existing electrical meter is not capable of measuring the flow of electricity in two directions, the customer -generator shall be responsible for all expenses involved in purchasing and installing a meter that is capable of measuring electricity in both directions. Co -energy metering customers transferred to net metering pursuant to Section 13.20.227 of this code, may remain on the dual meter system. Net energy metering customers, at their election may opt for the dual meter system. Net Energy Metering and Billing. Net energy is defined as measuring the difference between the electricity supplied by the city through the electric grid to the eligible customer -generator and electricity generated by an eligible customer - generator and fed back into the electric grid over a twelve-month period. In the event that the electricity supplied by the city during the twelve-month period exceeds the electricity generated by the eligible customer -generator during the same period, the eligible customer is a net electricity consumer and the city shall bill the customer for the net consumption during the twelve-month period based on the retail price per kilowatt-hour for eligible customer - generator's rate class over the same period. The city shall provide the customer -generator with net electricity consumption information on each regular bill. That information shall include the current amount owed to the city for the net electricity consumed. Customer -generator may exercise the option to pay monthly for the net energy consumed, but in any 9 event shall be responsible for any payments due at the end of each twelve- month period. Attributes. Any capacity attributes or environmental attributes associated with the renewable energy produced by the customer -generator at sites subject to this schedule shall belong to the city with the sole exception of renewable energy credits for solar and wind generation up to the amount of on-site consumption. Capacity attributes include, but are not limited to, system resource adequacy capacity and local resource adequacy capacity, if any. Environmental attributes include, but are not limited to, renewable portfolio standard recognition, renewable energy credits, greenhouse gas credits, and emission reduction credits, if any. 5. Excess Energy. Net energy metering will be administered on an annualized basis, beginning with the month of interconnection of the customer's generating system with the city's electrical system. Electric solar and wind generation production may result in a dollar credit carrying forward to the next billing period. If a credit accumulation results in a net customer -owned generation credit at the end of the annualized year, unused dollar credits will be set to zero and not be carried into the new annualized year unless the customer -generator affirmatively elects to be paid for such excess. If the customer -generator so elects, the city shall either pay the customer -generator or credit the customer generator's account for such excess at the baseline energy cost rate specified in Schedule ECA plus the energy cost adjustment rate averaged for the billing periods with excess generation. 6. Rules and Regulations. Other conditions specified in the City of Lodi electric utility department's rules, regulations and engineering standards shall apply to this electric rate schedule. 13.20.227 CONVERSION OF PRIOR SCHEDULE CEM—CO-ENERGY METERING RIDER. A. On the effective date of this [ordinance no. 1853], customer generators on the city's prior schedule CEM co -metering rider will be converted to the city's schedule NEM -net energy metering rider. In calendar year 2011, the annual net energy bill as provided in Subsection 13.20.225(D)(3) of this code, shall be calculated retroactive to January 1, 2011, and the annual excess energy credit or payment (if any) shall be calculated retroactive to January 1, 2011. 13.20.230 SCHEDULE EL—OUTDOOR DUSK -TO -DAWN LIGHTING. For out : - _ - = . .. _ - . , - - rl Th' -salts+ ed--to-t ae ordinance codified in E4hi t Q "":v--m-a t in f41-1-: A. Applicability: This schedule is applicable to City -owned and maintained outdoor overhead area lighting service. Dusk -to -Dawn lighting may not be used for street lighting purposes. B. Rates: For each 6,000 lumen gas discharge Tamp $12.7613.07 per billing cycle For each 18,000 lumen gas discharge Tamp $2-3-6$24.16 per billing cycle 10 1 C. Energy Cost Adjustment (ECA): An energy cost adjustment shall be included in each bill for service as provided in Section 13.20. Schedule ECA - Energy Cost Adjustment. D. Billing Cycle Charge (Monthly Bill): a. Lamps shall be approximately 6,000 or 18,000 lumen gas discharge with luminaire and bracket, as specified by the City of Lodi Electric Utility Department, and shall be supported on City -owned poles which are used to carry distribution system circuits for other City purposes and shall be at locations approved by the City of Lodi. Lamps will be controlled from dusk to dawn each night so as to give approximately 4,380 hours of service annually. b. Upon receipt of notice from a customer of failure of light to operate as scheduled, the City of Lodi Electric Utility Department will, within a reasonable period of time, make the necessary repairs. c. Relocation of existing outdoor lighting service equipment or the installation of additional facilities required other than mentioned in (a) above shall be at customer's expense prior to starting work. 13.20.235 SCHEDULE ES—CITY FACILITIES SERVICE. For city facilities --se e -rates, see the schedule attached to the ordinance codified in this section. mar—iced—Exhibit C and m of as--F'f-n -i-n-full. A. Applicability: This schedule is applicable only to those city facilities currently on schedule ES. B. Rates: MinimumCustorner Charge $5:510.20 Energy Charge per kWh $-148480.10890 C. Energy Cost Adjustment (ECA): An energy cost adjustment shall be included in each bill for service as provided in 1 Section 13.20. :. i SO Schedule ECA - Energy Cost Adjustment. D. Billing Cycle Charge (Monthly Bill): The billing cycle charge is the highef-e- the sum of the MiftiffiumCustomer Charge. al -is -..the Energy Charge, and the ECA -air -the sum ef-the Energy Charge and the 13.20.240 SCHEDULE G1—GENERAL SERVICE—GROUP 1 COMMERCIAL/ INDUSTRIAL. F r-re,.p e miner-oaUindustrial`rates. ,ee-the schedule attached te- -ie-er-ci-thaTee-Gndifiesi-in this -section, marked Exhibit D and-naade a part hereof as if set out in full_ A. Applicability: 11 This schedule is applicable to customers with single-phase or three-phase service, or to a combination thereof, whose energy consumption does not exceed 8,000 kilowatt-hours (kWh) per billing cycle for three consecutive billing cycles. This schedule is not available for service when another commercial/industrial schedule is applicable. Assignment to Schedule: If, in the judgment of the City, an account is expected to have usage below 8,000 kWh per billing cycle, the City has the option of placing the account immediately on this schedule. When an account billed on this schedule permanently changes the nature of electrical operations to such an extent that the account would in time qualify for another rate schedule, such billing change will be made as soon as practicable after verification of said changes. If energy consumption equals or exceeds 8,000 kWh for three consecutive billing cycles, the City will transfer the account to the appropriate rate schedule. If the demand reaches or exceeds 400 kW for three consecutive billing cycles, the account will be transferred to the appropriate rate schedule. B. Rates Customer Charge: (per meter per billing cycle) Single -Phase Service $-745 7.50 Three -Phase or Combination Service $1-04711.09 Energy Charge: ($ per kWh) Summer (May through October) $30.19261 Winter (November through April) ... $0439650.14244 C. Energy Cost Adjustment (ECA): An energy cost adjustment shall be included in each bill for service as provided in Section 13.20.175180 Schedule ECA — Energy Cost Adjustment. D. Community Benefits Incentive Discount: G1 -Non-profit (as defined in Federal Internal Revenue 501 (c) (3)) Industrial/Commercial customers who are currently receiving Federal Community Development Block Grant funds or have received such funds not more than two years before preparation of the current billing cycle charge are eligible for the following discount on Energy and Demand charges: July 1, 1996 and after 30% It is the customer's responsibility to notify the Finance Department of this eligibility. This discount may not be used in conjunction with any other incentive discount. E. Billing Cycle Charge (Monthly Bill): The billing cycle charge is the sum of the Customer Charge, the Energy Charge and the ECA. 12 13.20.250 SCHEDULE G2—GENERAL SERVICE—GROUP 2 COMMERCIAL/INDUSTRIAL. For Gr^„^ 2 commereal/industrial rates, vee the sGrhedule attached to the ordinance codified in t€s-se t+en--mar-ked-E-xh+b+t-€ an eof as if set oat -in fig -14 A. Applicability: This schedule will be applied to accounts with energy consumption in excess of 8,000 kilowatt-hours (kWh) for three consecutive billing cycles. This schedule is not available for service when another commercial/industrial schedule is applicable. Billing Demand: The billing demand in any billing cycle will be the maximum average power taken during any metering interval in the period, but not less than the diversified resistance welder load. (The customary metering interval is 15 minutes; in cases where the use of energy is intermittent or subject to violent fluctuations, a 5 -minute interval may be used.) Assignment to Schedule: If, in the judgment of the City, an account is expected to have usage over 8,000 kWh per billing cycle, the City has the option of placing the account immediately on this schedule. When an account billed on this schedule permanently changes the nature of electrical operations to such an extent that the account would in time qualify for another rate schedule, such billing change will be made as soon as practicable after verification of said changes. It shall be the responsibility of the customer to notify the City of any such changes. If energy consumption drops below 8,000 kWh and remains there for 12 consecutive billing cycles, the City will transfer the account to the appropriate schedule. If the billing demand reaches or exceeds 400 kW for three consecutive billing cycles, the account will be transferred to the appropriate rate schedule as soon as practicable. B. Rates: Customer Charge: (per meter per billing cycle) $59-2060.38 Demand Charge: All kW of billing demand, per kW $ '1.104.18 Energy Charge: (per kWh) Summer (May through October) $0-190.15829 Winter (November through April) $0424-230.12871 Energy Cost Adjustment (ECA): An energy cost adjustment shall be included in each bill for service as provided in Section 13.20.175180 Schedule ECA - Energy Cost Adjustment. C. Voltage Discount: When delivery is made at the same primary distribution voltage as that of the line from which the service is supplied, a 4% discount will be allowed on the sum of the Demand Charge and the Energy Charge. 13 D. Community Benefits Incentive Discount: G2 -Non-profit (as defined in Federal Internal Revenue 501 (c) (3)) Industrial/Commercial customers who are currently receiving Federal Community Development Block Grant funds or have received such funds not more than two years before preparation of the current billing cycle charge are eligible for the following discount on Energy and Demand charges: July 1, 1996 and after 30% It is the customer's responsibility to notify the Finance Department of this eligibility. This discount may not be used in conjunction with any other incentive discount. E. Billing Cycle Charge (Monthly Bill) The billing cycle charge is the sum of the Customer Charge, the Demand Charge, the Energy Charge, the ECA and the voltage discount, if applicable. 13.20.260 Schedule G3—General service—Group 3 commercial/industrial. For Group 3 romerciallindustrial rates, see the schedule--attasIed-to the ordinance &o ified-in tis-sest+en, marked-Ex—Nb iia-adc a ieFeef as if set out in full. A. Applicability: This schedule shall be applied to accounts with billing period demands of between 400 kilowatts (kW) and 500 kW for three consecutive billing cycles. This schedule is not available for service when another commercial/industrial schedule is applicable. Demand: The billing period and peak period demands will be the maximum average power taken during any 15 -minute interval in the billing period and peak period, respectively, but not less than the diversified resistance welder load. In cases where the use of energy is intermittent or subject to violent fluctuations, a 5 -minute interval may be used. Assignment to Schedule: If, in the judgment of the City, an account is expected to have billing period demand of 400 kW or more and less than 500 kW per billing cycle, the City has the option of placing the account immediately on this schedule. When an account billed on this schedule permanently changes the nature of electrical operations to such an extent that the account would in time qualify for another rate schedule, such billing change will be made as soon as practicable after verification of said changes. It shall be the responsibility of the customer to notify the City of any such changes. If billing period demand drops below 400 kW and remains there for 12 consecutive billing cycles, the City will transfer the account to the appropriate rate schedule. If billing period demand reaches or exceeds 500 kW for three consecutive billing cycles, the account will be transferred to the appropriate rate schedule. 14 B. Rates: Customer Charge (per meter per billing cycle) , $13,1.54137.23 Service Voltage: Secondary (G3 -S) Primal./(G3-P) Season: Summer Winter Summer Winter Demand Charges: Per kW of peak 1 period demand $11.4711.70 -- $ 447.10.98 Per kW of billing 1 period demand $ —4444.18 $ 4404.18 $ 3.173.23 $ 3.173.23 Energy Charges: 'Peak Period (per kWh) $04-68900.17228 -- $0462800.1 6606 -- Partial peak period 1 (per kWh) $0,145280.13799 $0.122590.12504 $0.130860.13348 $0.118800.12118 Off peak period 1 (per kWh) $0.116210.11853 $041-1-880.11412 $0.1127,10.11499 $0.08620.11079 C. Energy Cost Adjustment (ECA): An energy cost adjustment shall be included in each bill for service as provided in section 13.20.175180 Schedule ECA — Energy Cost Adjustment. D. Types of Charges: The billing cycle charge for service is the sum of the Customer Charge, the Demand Charges, the Energy Charges, the ECA and the Power Factor Adjustment: 1. Customer Charge: The Customer Charge is a flat monthly fee. 2 Demand Charges: This schedule has two Demand Charges: A peak period Demand Charge and a billing period Demand Charge. The peak period Demand Charge per kW applies to the maximum average power taken during any metering interval during the billing cycle's peak hours. The billing period Demand Charge per kW applies to the maximum average power taken during any metering interval at any time during the billing cycle. The bill will include both Demand Charges. Time periods are defined below. 3. Energy Charges: This schedule has three Energy Charges: A peak period Energy Charge, a partial peak period Energy Charge, and an off peak period Energy Charge. The peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's peak hours. Partial peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's partial peak hours. Off peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's off peak hours. The bill will include all of these Energy Charges. Time periods are defined below. ECA: The ECA is a per kWh charge applied to the total kWh used during the billing cycle. 15 Monthly charges may be decreased or increased based upon power factor as defined below. As shown on the rates above, Demand and Energy Charges are based on the voltage at which service is taken. Service voltages are defined below. E. Definition of Service Voltage: The service voltage classes are (a) Primary: Service Voltage class for service at 12,000 volts (nominal). (b) Secondary: Service Voltage class for service at available voltages below 12,000 volts (nominal). Power Factor Adjustment: Bills will be adjusted for billing cycle average power factor as follows: The total charge (except taxes and customer charge) for any billing cycle as computed on the above rates shall be decreased or increased, respectively, by 0.0006% for each 0.01 percentage point that the average power factor of the customer's load in the billing cycle is greater or less than 85.00%, such average power factor to be computed (to the nearest hundredth of a percent) from the ratio of lagging kilovolt ampere -hours to kilowatt-hours consumed in the billing cycle. 2. Customers with service entrance equipment unable to accommodate the City's reactive metering equipment shall have their billing power factor determined by testing performed by the City. G. Definition of Time Periods: Times of the year and times of the day are defined as follows: 1. SUMMER: (May 1 through October 31) Peak: 3:00 p.m. to 7:00 p.m. Monday through Friday (except holidays). Partial Peak: 8:30 a.m. to 3:00 p.m. and 7:00 p.m. to 9:30 p.m. Monday through Friday (except holidays). Off Peak: 9:30 p.m. to 8:30 a.m. Monday through Friday and all day Saturday, Sunday and holidays. 2. WINTER: (November 1 through April 30) Partial Peak: 8:30 a.m. to 9:30 p.m. Monday through Friday (except holidays). 16 Off Peak: 9:30 p.m. to 8:30 a.m. Monday through Friday and all day Saturday, Sunday and holidays. 3. HOLIDAYS: "Holidays," for the purpose of this rate schedule, are New Year's Day, Presidents' Day, Memorial Day, Independence Day, Labor Day, Veterans' Day, Thanksgiving Day, the day after Thanksgiving Day and Christmas Day. The dates will be based on those days on which the holidays are legally observed. 13.20.270 SCHEDULE G4—GENERAL SERVICE—GROUP 4 COMMERCIAL/INDUSTRIAL. w ■ ....w - - - =mie attanhed to thTe-orvir'4e. rn ed -i -n this -section, marked -Exhibit G arid -mak o part hereof as if set out in full A. Applicability: This schedule shall be applied to accounts with billing period demands of between 500 kilowatts (kW) and 1,000 kW for three consecutive billing cycles. This schedule is not available for service when another commercial/industrial schedule is applicable. Demand: The billing period and peak period demands will be the maximum average power taken during any 15 -minute interval in the billing period and peak period, respectively, but not less than the diversified resistance welder load. In cases where the use of energy is intermittent or subject to violent fluctuations, a 5 -minute interval may be used. Assignment to Schedule: If, in the judgment of the City, an account is expected to have billing period demand between 500 kW and 1,000 kW per billing cycle, the City has the option of placing the account immediately on this schedule. When an account billed on this schedule permanently changes the nature of electrical operations to such an extent that the account would in time qualify for another rate schedule, such billing change will be made as soon as practicable after verification of said changes. It shall be the responsibility of the customer to notify the City of any such changes. If billing period demand drops below 500 kW and remains there for 12 consecutive billing cycles, the City will transfer the account to the appropriate rate schedule. If billing period demand reaches or exceeds 1,000 kW for three consecutive billing cycles, the account will be transferred to the appropriate rate schedule. B. Rates: Customer Charge (per meter per billing cycle) $134.54137.23 Service Voltage: Secondary (G4 -S) Prima (G4 -P) Season: Summer Winter Summer Winter Demand Charges: Per kW of peak j period demand $44-4711.70 -- $ 4-0,7610.98 -- 17 Per kW of billing d period demand $ -1..104.18 $ 4,1-04.18 $ 3.173.23 $ 3.173.23 Energy Charges: Peak Period (per kWh) 1 $0.155920.15904 -- $0.1.19880.15288 -- Partial peak period I (per kWh) $0422250.12470 $0.110310.11252 $0.11-7-9-10.12027 $04065-70.10870 Off peak period 9 (per kWh) $0.103220.10528 $97009690.10168 $94199840.10181 $9-990170.09840 C. Energy Cost Adjustment (ECA): An energy cost adjustment shall be included in each bill for service as provided in 1 Section 13.20.175180 Schedule ECA - Energy Cost Adjustment. D. Types of Charges: The billing cycle charge for service is the sum of the Customer Charge, the Demand Charges, the Energy Charges, the ECA and the Power Factor Adjustment: 1. Customer Charge: The Customer Charge is a flat monthly fee. 2. Demand Charges: This schedule has two Demand Charges: A peak period Demand Charge and a billing period Demand Charge. The peak period Demand Charge per kW applies to the maximum average power taken during any metering interval during the billing cycle's peak hours. The billing period Demand Charge per kW applies to the maximum average power taken during any metering interval at any time during the billing cycle. The bill will include both of these Demand Charges. Time periods are defined below. 3. Energy Charges: This schedule has three Energy Charges: A peak period Energy Charge, a partial peak period Energy Charge, and an off peak period Energy Charge. The peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's peak hours. Partial peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's partial peak hours. Off peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's off peak hours. The bill will include all of these Energy Charges. Time periods are defined below. 4. ECA: The ECA is a per kWh charge applied to the total kWh used during the billing cycle. Monthly charges may be decreased or increased based upon power factor as defined below. As shown on the rates above, Demand and Energy Charges are based on the voltage at which service is taken. Service Voltages are defined below. E. Definition of Service Voltage: The service voltage classes are: 18 (a) Primary: (b) Secondary: F. Power Factor Adjustment: Service Voltage class for service at 12,000 volts (nominal). Service Voltage class for service at available voltages below 12,000 volts (nominal). Bills will be adjusted for billing cycle average power factors as follows: 1. The total charge (except taxes and customer charge) for any billing cycle as computed on the above rates shall be decreased or increased, respectively, by 0.0006% for each 0.01 percentage point that the average power factor of the customer's load in the billing cycle is greater or less than 85.00%, such average power factor to be computed (to the nearest hundredth of a percent) from the ratio of lagging kilovolt ampere -hours to kilowatt-hours consumed in the billing cycle. 2. Customers with service entrance equipment unable to accommodate the City's reactive metering equipment shall have their billing power factor determined by testing performed by the City. G. Definition of Time Periods: Times of the year and times 1. SUMMER of the day are defined as follows: (May 1 through October 31) Peak: 3:00 p.m. to 7:00 p.m. Monday through Friday (except holidays). Partial Peak: 8:30 a.m. to 3:00 p.m. and 7:00 p.m. to 9:30 p.m. Monday through Friday (except holidays). Off Peak 9:30 p.m. to 8:30 a.m. Monday through Friday and all day Saturday, Sunday and holidays. 2. WINTER (November 1 through April 30) Partial Peak: 8:30 a.m. to 9:30 p.m. Monday through Friday (except holidays). Off Peak 9:30 p.m. to 8:30 a.m. Monday through Friday and all day Saturday, Sunday and holidays. 3. HOLIDAYS: "Holidays," for the purpose of this rate schedule, are New Year's Day, Presidents' Day, Memorial Day, Independence Day, Labor Day, Veterans Day, Thanksgiving Day, the Day after Thanksgiving Day and Christmas Day. The dates will be based on those days on which the holidays are legally observed. 19 13.20.280 SCHEDULE G5—GENERAL SERVICE—GROUP 5 COMMERCIAL/INDUSTRIAL. Applicability: v nrd i nanoe I�Af`IITied in This schedule shall be applied to accounts with billing period demands of 1,000 kilowatts (kW) or more for three consecutive months, unless the customer elects an optional rate schedule the account would otherwise qualify. Demand: The billing period and peak period demands will be the maximum average power taken during any 15 -minute interval in the billing period and peak period, respectively, but not less than the diversified resistance welder load. In cases where the use of energy is intermittent or subject to violent fluctuations, a 5 -minute interval may be used. Assignment to Schedule: If, in the judgment of the City, an account is expected to have billing period demand of 1,000 kW or more per billing cycle, the City has the option of placing the account immediately on this schedule. When an account billed on this schedule permanently changes the nature of electrical operations to such an extent that the account would in time qualify for another rate schedule, such billing change will be made as soon as practicable after verification of said changes. It shall be the responsibility of the customer to notify the City of any such change. If billing period demand drops below 1,000 kW and remains there for 12 consecutive billing cycles, the City will transfer the account to the appropriate rate schedule. B. Rates: Customer Charge (per meter per billing cycle) $1-34-54137.23 Service Voltage: Secondary (G5 -S) Prima (G5 -P) Season: Summer Winter Summer Winter Demand Charges: Per kW of peak period demand $1-1.4711.70 -- $10.7610.98 -- Per kW of billing period demand $ -4404.18 $ 4.104.18 $ 3.173.23 $ 3.173.23 Energy Charges: Period (per kWh) $0.143650.14652 -- $91379'10.14070 -- $0-1-06920.10814 $0.110050.11225 _Peak Partial peak period (per kWh) $0.098250.10022 $9.094810.09671 $0.088930.09173 $0-:037060.08880 $0.090090.09189 $0.093440.09497 Off peak period (per kWh) Economic Stimulus Rate Credit: (per kWh) $0,004310.00440 $0-004340.00440 $0-.00431.0.00440 $0.004310.00440 20 C. Energy Cost Adjustment (ECA). An energy cost adjustment shall be included in each bill for service as provided in Section 13.20.180 Schedule ECA — Energy Cost Adjustment. D. Types of Charges: The billing cycle for service is the sum of the Customer Charge, the Demand Charges, the Energy Charges, the ECA and the Power Factor Adjustment. 1. Customer Charge: The Customer Charge is a flat monthly fee. 2. Demand Charges: This schedule has two Demand Charges: A peak period Demand Charge and a billing period Demand Charge. The peak period Demand Charge per kW applies to the maximum average power taken during any metering interval during the billing cycle's peak hours. The billing period Demand Charge per kW applies to the maximum average power taken during any metering interval at any time during the billing cycle. The bill will include both of these Demand Charges. Time periods are defined below. 3. Energy Charges: This schedule has three Energy Charges: A peak period Energy Charge, a partial peak period Energy Charge, and an off peak period Energy Charge. The peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's peak hours. Partial peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's partial peak hours. Off peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's off peak hours. The bill will include all of these Energy Charges. Time periods are defined below. ECA: The ECA is a per kWh charge applied to the total kWh used during the billing cycle. Monthly charges may be decreased or increased based upon power factor as defined below. As shown on the rates above, Demand and Energy Charges are based on the voltage at which service is taken. Service Voltages are defined below. E. Definition of Service Voltage: The service voltage classes are: (a) Primary: Service Voltage class for service at 12,000 volts (nominal). (b) Secondary: Service Voltage class for service at available voltages below 12,000 volts (nominal). F Power Factor Adjustments: Bills will be adjusted for billing cycle average power factor as follows: 1. The total charge (except taxes and customer charge) for any billing cycle as computed on the above rates shall be decreased or increased, respectively, by 21 0.0006% for each 0.01 percentage point that the average power factor of the customer's load in the billing cycle is greater or less than 85.00%, such average power factor to be computed (to the nearest hundredth of a percent) from the ratio of lagging kilovolt ampere -hours to kilowatt-hours consumed in the billing cycle. 2. Customers with service entrance equipment unable to accommodate the City's reactive metering equipment shall have their billing power factor determined by testing performed by the City. G. Definition of Time Periods: Times of the year and times of the day are defined as follows: 1. SUMMER: (May 1 through October 31) Peak: 3:00 p.m. to 7:00 p.m. Monday through Friday (except holidays). Partial Peak: 8:30 a.m. to 3:00 p.m. and 7:00 p.m. to 9:30 p.m. Monday through Friday (except holidays). Off Peak: 9:30 p.m. to 8:30 a.m. Monday through Friday and all day Saturday, Sunday and holidays. 2. WINTER: (November 1 through April 30) Partial Peak: 8:30 a.m. to 9:30 p.m. Monday through Friday (except holidays). Off Peak: 9:30 p.m. to 8:30 a.m. Monday through Friday and all day Saturday, Sunday and holidays. 3. HOLIDAYS: "Holidays," for the purpose of this rate schedule, are New Year's Day, Presidents' Day, Memorial Day, Independence Day, Labor Day, Veterans' Day, Thanksgiving Day, the day after Thanksgiving Day and Christmas Day. The dates will be based on those days on which the holidays are legally observed. 13.20.290 SCHEDULE EP—ENERGY PURCHASE. energy --ase rates, see the -sok odule-attashcd to the-or-cii-naca ed in this section. r afked-Exh1bit E and m ide-a-part-herco€ as if set -out in full: A. Applicability: This schedule is applicable to qualifying customer-owned/leased and operated generating alternating current facilities operating in parallel with the City's electric distribution system_ on a contract basis. Customer generators must currently be served by the City of Lodi Electric Utility (LEU). 22 Generating facilities must be rated less than 1 MW, be located on the customer - generator's premises and be intended for the purpose of offsetting a part or all of the customer - generator's own electrical requirements. In no case shall the energy, capacity. and/or other attributes associated with the customer-owned/leased generating facility be available for resale ya party other than LEU. This schedule is available only to customers who do not otherwise qualify for compensation for customer -owned generation under an existing LEU rate schedule or contract. A. Rates: 1. Energy Charges: Customer will be billed for all usage at the applicable service rate in effect when the service was rendered in accordance with the eligible customer -generator's otherwise applicable rate schedule based on metered usage prior to any generation. Monthly customer charges, public benefit charges, and all other surcharges shall be non -bypassable. 2. Energy Purchase Credit: Credit will be provided to the customer for all metered output of the customer - owned and operated generating facility based on the avoided cost to the LEU, the specific value of which will be determined and updated by the LEU each year based on the following components: avoided energy and transmission costs, environmental attribute value (if applicable based on generation type), avoided system loss, and avoided capacity value. Energy Purchase Credit values will be published each year on LEU's website and provided to customers receiving service under this schedule, including any annual updates. The above charges and credits will be determined using two separate meters. Billing For each billing month. the customer shall receive a bill including all applicable Energy Charges, including, but not limited to, customer charges, energy charges, demand charges. and any applicable surcharges. taxes and/or discounts. The bill will also include all applicable Energy Purchase Credits which shall be used to offset the Energy Charges in a given billing month. Any credit(s) remaining at the end of each billing month shall carry forward and be applied to the customer's next monthly electric bill. Any outstanding charges will be due and Payable at the end of each billing month. C Special Conditions: Other conditions shall apply to this schedule as specified in the City of Lodi Electric Utility Department's Rules and Regulations, as updated from time to time, and Engineering Standards and Specifications (including metering requirements). 23 2. Customers will be responsible for any and all metering and interconnection charges as required to provide service under this schedule. Said charges will be determined by LEU and be based on the cost(s) associated with providing service under this schedule. 3. Any capacity or environmental attributes associated with the energy by customer -generator at sites subiect to this schedule shall belong to the City. Capacity attributes include, but are not limited to: system. local, and/or flexible resource adequacy capacity, if any. Environmental attributes include. but are not limited to: renewables portfolio standard eligible resources, renewable energy credits, greenhouse gas credits, and/or emission reduction credits. if any. 4. LEU reserves the riaht to reauire a contract should it determine the customer - owned generator does not qualify under this schedule. 13.20.300 SCHEDULE SS—STANDBY SERVICE. A. Applicability: This schedule is applicable to commercial/industrial customers who would otherwise qualify for Schedule G2, G3, G4, G5, or 11 and who have privately -owned generating facilities with a combined nameplate rating greater than one megawatt (1 MW) on their premises and where the city must stand ready to supply electric service to replace such a facility. This schedule will apply in addition to any other schedule applicable to the customer of record; any multiple generation facilities for one customer of record will be under one contract. B. Service by Contract. Service under this schedule shall be provided on a contract basis to commercial/industrial customers who have privately- owned generating facilities on their premises. Contracts shall be subject to terms approved by the city council and shall obligate the customer to pay the city for its costs associated with providing standby service for the actual life of the privately -owned generating facilities and for three months following written notice to the City of Lodi Electric Utility of the removal of the privately -owned generating facilities from operation. 13.20.310 SCHEDULE I1—GENERAL SERVICE—GROUP 5 COMMERCIAL/INDUSTRIAL- OPTIONAL. 1 For Group 5 cornmercial i&t ial. optional `rates, see the schedule attaehe4 to tho ordinanso 1 eed4 e4 -in -t 4s -section, mar - - - =reof as i-sct out in full. A. APPLICABILITY: This schedule is an optional rate for accounts who would otherwise qualify for primary service under the G5 rate schedule with billing period demands of 1,000 kilowatts (kW) or more for three consecutive months. Demand: The billing period and peak period demands will be the maximum average power taken during any 15 -minute period interval in the billing period and peak period, respectively, but not less than the diversified resistance welder load. In cases where the use of energy is intermittent or subject to violent fluctuations, a 5 -minute interval may be used. 24 Assignment to Schedule: Assignment to this schedule is at the option of the customer and does not supersede any standby service contracts. This rate schedule is prospective and not subject to rebate or retroactivity. When a customer chooses to be assigned to this schedule, the customer elects the City of Lodi (City) to be the sole electric power requirements provider of choice. The customer must give the City three year written notice before the customer can elect to use another electric power requirements provider. When a customer has a measurable incremental permanent load increase of 200 kW or greater, over the highest billing period demand in the previous twelve (12) months the customer will be eligible for a ten (10) percent discount on the incremental Demand and Energy charges. Such billing change will be made as soon as practicable after verification of said changes and is not subject to rebate or retroactivity. It shall be the responsibility of the customer to notify the City of any such change. When an account billed on this schedule qualifies for another City bundled rate schedule, the customer may elect to be billed on that other rate schedule. When a customer chooses to be assigned to another bundled rate a three-year written notice is still required before the customer can elect to use another electric power requirements provider. If the billing period demand drops below 1,000 kW and remains there for 12 consecutive billing cycles, the City will transfer the account to the appropriate rate schedule and the customer will be subject to the requirements of the appropriate schedule, rather than schedule 11. B. Rates. Customer Charge (per meter per billing cycle) 1 $134.51137.23 Winter Service Voltage: Primary (I1 -P) Season: Summer Winter $0.093240.09507 Off peak period (per kWh) $0.085940.08766 Demand Charges: Per kW of peak period demand $10.7610.98 -- Per kW of billing period demand $ 3.17123 $ 3.173.23 Energy Charges: < 4000 kW Summer Winter Peak period (per kWh) $0.140290.14310 -- Partial peak period (per kWh) $0.108070.11023 $0.099720.10171 Off peak period (per kWh) $0.092150.09430 $091770.09361 >_4000 kW Summer Winter Peak period (per kWh) $930.13646 -- Partial peak period (per kWh) $0,141-560 10359 $0.093240.09507 Off peak period (per kWh) $0.085940.08766 $8:60.08697 Economic Stimulus Rate Credit: (per kWh) $4-843590.01386 $0-0-14590.01386 C. Energy Cost Adjustment (ECA): 25 An energy cost adjustment shall be included in each bill for service as provided in Section 13.20.175180 Schedule ECA — Energy Cost Adjustment. D. Types of Charges: The billing cycle charge for service is the sum of the Customer Charge, the Demand Charges, the Energy Charges, the ECA and the Power Factor Adjustment: 1. Customer Charge: The Customer Charge is a flat monthly fee_ 2. Demand Charges: This schedule has two Demand Charges: A peak period Demand Charge and a billing period Demand Charge. The peak period Demand Charge per kW applies to the maximum average power taken during any metering interval during the billing cycle's peak hours. The billing period Demand Charge per kW applies to the maximum average power taken during any metering interval at any time during the billing cycle. The bill will include both of these Demand Charges. Time periods are defined below. 3. Energy Charges: This schedule has three Energy Charges: A peak period Energy Charge, a partial peak period Energy Charge, and an off peak period Energy Charge. The peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's peak hours. Partial peak period Energy Charge per kWh applies to the total kWh used during the billing cycle's partial peak hours. Off peak period Energy Charge per kWh applies to the total kWh used during the billing cycles off peak hours. The bill will include all of these Energy Charges. Time periods are defined below. 4. ECA: The ECA is a per kWh charge applied to the total kWh used during the billing cycle. Monthly charges may be decreased or increased based upon power factor as defined below. As shown on the rates above, Demand and Energy Charges are based on the voltage at which service is taken. Service Voltage is defined below. E. Definition of Service Voltage: The service voltage class: a. Primary: Service Voltage class for service at 12,000 volts (nominal). F. Power Factor Adjustments: Bills will be adjusted for billing cycle average power factor as follows: 1. The total charge (except taxes and customer charge) for any billing cycle as computed on the above rates shall be decreased or increased, respectively, by 0.0006% for each 0.01 percentage point that the average power factor of the customer's load in the billing cycle is greater or less than 85.00%, such average power factor to be computed (to the nearest hundredth of a percent) from the ratio of lagging kilovolt ampere -hours to kilowatt-hours consumed in the billing cycle. 26 2. Customers with service entrance equipment unable to accommodate the City's reactive metering equipment shall have their billing power factor determined by testing performed by the City. G. Definition of Time Periods: Times of the year and times of the day are defined as follows: 1. SUMMER: (May 1 through October 31) Peak: 3:00 p.m. to 7:00 p.m. Monday through Friday (except holidays). Partial Peak: 8:30 a.m. to 3:00 p.m. and 7:00 p.m. to 9:30 p.m. Monday through Friday (except holidays). Off Peak: 9:30 p.m. to 8:30 a.m. Monday through Friday and all day Saturday, Sunday and holidays. 2. WINTER: (November 1 through April 30) Partial Peak: 8:30 a.m. to 9:30 p.m. Monday through Friday (except holidays). Off Peak: 9:30 p.m. to 8:30 a.m. Monday through Friday and all day Saturday, Sunday and holidays. 3. HOLIDAYS: "Holidays," for the purpose of this rate schedule, are New Year's Day, Presidents' Day, Memorial Day, Independence Day, Labor Day, Veterans' Day, Thanksgiving Day, the day after Thanksgiving Day and Christmas Day. The dates will be based on those days on which the holidays are legally observed. 13.20.315 SCHEDULE EDR—ECONOMIC DEVELOPMENT RATES. Applicability: A. New Business Rate Discount. NBR discount, applicable to any new commercial or industrial customer that locates their operations/business that receives electric utility service from the City of Lodi, with the following stipulations: a customer assigned to the G1 electric utility rate shall receive a discount for twelve consecutive months of twenty-five dollars per month; and, customers assigned to the G2, G3, G4, G5, or 11 electric utility rate shall receive a discount for twelve consecutive months of five percent; and this rate discount may not be combined with any other electric discount or rate and shall only apply to the base rate. Surcharges including, but not limited to, the California Energy Commission fee, solar surcharge, public benefits charge, state energy tax, and other assessments or charges after the date of this rate schedule shall not be subject to this discount. B. New Jobs Rate Discount. NJR discount, applicable to any commercial or industrial customer that adds a minimum of one full-time position, and retains that position for at least twelve consecutive months, with the following stipulation: A two percent discount for one 27 • to three new positions; four percent for four to six new positions; six percent for seven to nine positions; and eight percent for ten or more new positions. The maximum discount available is eight percent; all discounts are available for twelve consecutive months; and this rate discount may not be combined with any other electric discount or rate and shall only apply to the base rate. Surcharges including, but not limited to, the California Energy Commission fee, solar surcharge, public benefits charge, state energy tax, and other assessments or charges after the date of this rate schedule shall not be subject to this discount. C. The rate schedules referenced above shall be effective on applicable electric utility billings prepared by the City of Lodi on or after September 1, 2015 and said utility rate discounts shall expire on June 30, 2018. 13.20.320 Schedule NST New -sales tax-ra-taReserved. A— Applicability. Yids ra G1, G2, G3, G4, or G5 rate for the purpose of attraot ew-businesses gener-at4 s antial sales -tax -revenue -into vacant properties: Q. Commercial Businesses. 1. Qualifying Customers. A qualifying cu:tomor is one who: a. Takes permitted ocsepafl-ey-afteF-(44 Gity of Lodi ("Lodi") and receives electric service from the City of Lodi. The property—must—be lent property'): and IA - - - - b. -At-the-s bjest-pr- er rakes -retain sales that generate new -sales -tax of one hundred thousand dollars per year or more, as determined by the City of Lodi; and c. Files a complete application requesl:ing-a-new-sales tax rate (NS -T-), 2. New Sales Tax. a. "New sales-taa as = cedn graph (B)(1)(b) abovo refers to the po on-ef the sales tax -paid to the City of Lodi generated -by -sales at the subject- pr pe odi NST"); and b. -II- isi.ness #tato e6 wit in—the Le n additional one hundred -thousand -doll_ _ - • g alify fer this rate Discount lie -discount shall qua .0 -n -of -the Lodi-utility-la+ll y for bills for periods ending-withthe-year-ending-June 30, 2011, and five percent fo�-t#e-eleetris portion of the -Lodi -utility bill asseeiatad-wit --t• = c subject shall -r o� te-tlae-seta charge -levied -on -electric pr-ovieled otee vi_ after June 30, 2012. rrgy tax, or any other aac�t or bills after the -effective -date of this -rate schedule unless specifically .ding with meter_rea4ing • • - - - - - - - • - amgw-i-�-rrT..-cc.-r-+-ccsvrrrg D. Verificat+ do information satisfactory to Lodi regards he planned size of the new load and sales -tax -generation. If, in-the--epinie t--ef-I e€ c sterner is 28 deemed qualified on the basis of sales -tax projectic-ns,tit-is-laterund-not to be quad, en the -basis of actual sal i r -4hen any discount will be rebilled-and-due back to Lodi. If, in tla= z - - - - - - - - - - - - - - -e basis of sales - projections. but-is-late-F-foundlified, on the basis of actual sales tax generation. thea any -di n f�eab l rre east+ve period -will be-credi}4t,he-customer's-aeeeuat- -- • .- • - - -• . •- ,- - and/cc-wine-industry business discount under the EDprT.-a:nye-giver-} the larger of the two discounts, but not both, for the per '=- - - - - :-alifisations for both F. Sunset. This NST rate shall expire at the end of June 2012. It shall not apply to any bill b eed-er }h�-�„ Q - - - - . en after June 30, 2012. tablishing administrative rules and processes for adeai isterin sr -rate edele donees shall provide information -on a timely basis to enable EDD to verify -eligibility -arid to administer the terms+ of +hie r- te-se eduIe.. 13.20.325 Schedule EV—Electric Vehicle Charging Service. A. Applicability: This schedule is applicable to single-phase electric vehicle charging service in single- family and multi -family dwellings separately metered by the City. B. Rates: MinimurmCustomer Charge $5.23.00 r�rrnirrrrrr rr Energy Charge: EV Charging period (per kWh) Non -EV Charging period (per kWh) 0.4OlOSchedule EA Tier 1 Energy Charge 0.3'1659Schedule EA Tier 3 Energy Charge C. Energy Cost Adjustment (ECA): An energy cost adjustment shall be included in each bill for service as provided in 1 Section 13.20.175180 Schedule ECA - Energy Cost Adjustment. D. Billing Cycle Charge (Monthly Bill): The billing cycle charge is the higher of the sum of the M mum -Customer Charge, the Energy Charge and -the or t e -sun of the Energy Charge -and the ECA. E. Definition of Time Periods: Times of the day are defined as follows: EV Charging period: 8:00 p.m. to 6:00 a.m. Monday through Friday (and all day weekends and holidays). 29 Non -EV Charging period: 6:00 a.m. to 8:00 p.m. Monday through Friday (excluding weekends and holidays). 13.20.330 SGhektu4 Reserved. A. Applicabilityphis-s edule--is li atale4o--alt-single-phase--er-th-ree-phaee nrtmmornial and—industrial customers separately metered by tho City of Lodi. This schedule shall only -be available to customers who--purchase-aa d-insstall-a-separate—el cfi met�edise} " ig reeh-argcNable battery industria - The minirmim charge is five dollars and twenty4lve-sent a.,m 44e through F e - , bserved holidays -an -we --toarging rechargeable batten/ industrial equipment shall be a flat rate-of-S04042--74144h-plus the ECA set forth in Section -4-3,20474-0 this code ("ECA"). At alt other times, the charge slag -be a f#al-Fates 0.00 tiWh plus the ECA. This schedule4E-may---oat--be-e bined-with-any-etlaer electric rate or rate- dissea t---org-the lE meter -and all surcharges, including, but not limited to the-Galifornia Energy Commission fee, ssessnaents or charges after= -the date of this rate schedul ll be -in -addition to this r,tte schedule, T e r.,te served - - - _ - e e - - _ - _ .. _ icabi4 electric utility billings prepared by the City of Lodi on or after July 1. 201-3 and --said utility rate discounts shall expire on June 30, 2015. 8. Rates. Minimum charge —46,26 lE Charging period-fper kWh) Nan lE Charging period (per kW@» S0-1-084.8 0.3,#650 C. €-nergy-C-est-Ad}ustin for service as provided .dent, D. Billing Cycle Charge -(Monthly Bill). The billin c o �,--ro4he-hig e_ of the s> rn of the minimum charge and the ECA or the sum of the energy charge and the ECA. E. Definition of time Periods. Times of the d lE charging -period: Ten p.m. to six a.ra--M holidays -and -weekends). Nen l-ehar-ging--Aeries S. observed holidays eluding City obsended eui h- riday- (� (e luding City SECTION 2. No Mandatory Duty of Care. This ordinance is not intended to and shall not be construed or given effect in a manner which imposes upon the City, or any officer or employee thereof, a mandatory duty of care towards persons or property within the City or outside of the City so as to provide a basis of civil liability for damages, except as otherwise imposed by law. 30 SECTION 3. Severability. If any provision of this ordinance or the application thereof to any person or circumstances is held invalid, such invalidity shall not affect other provisions or applications of the ordinance which can be given effect without the invalid provision or application. To this end, the provisions of this ordinance are severable. The City Council hereby declares that it would have adopted this ordinance irrespective of the invalidity of any particular portion thereof. SECTION 4. All ordinances and parts of ordinances in conflict herewith are repealed insofar as such conflict may exist. SECTION 5. Effective Date and Publication. This Ordinance shall take effect on May 1, 2017. In lieu of publication of the full text of the ordinance within fifteen (15) days after its passage, a summary of the ordinance may be published at least five (5) days prior to and fifteen (15) days after adoption by the City Council, and a certified copy shall be posted in the office of the City Clerk pursuant to Government Code section 36933(c)(1). Approved this day of , 2017 DOUG KUEHNE ATTEST: Mayor JENNIFER M. FERRAIOLO City Clerk State of California County of San Joaquin, ss. I, Jennifer M. Ferraiolo, City Clerk of the City of Lodi, do hereby certify that Ordinance No. was introduced at a regular meeting of the City Council of the City of Lodi held March 1, 2017, and was thereafter passed, adopted, and ordered to print at a regular meeting of said Council held . 2017, by the following vote: AYES: COUNCIL MEMBERS — NOES: COUNCIL MEMBERS — ABSENT: COUNCIL MEMBERS — ABSTAIN: COUNCIL MEMBERS — 1 further certify that Ordinance No. was approved and signed by the Mayor on the date of its passage and the same has been published pursuant to law. Approved as to Form: JENNIFER M. FERRAIOLO JANICE D. MAGDICH City Attorney 31 City Clerk Please immediately confirm receipt of this fax by calling 333-6702 CITY OF LODI P. O. BOX 3006 LODI, CALIFORNIA 95241-1910 ADVERTISING INSTRUCTIONS SUBJECT: PUBLIC HEARING TO CONSIDER INTRODUCING AN ORDINANCE AMENDING LODI MUNICIPAL CODE CHAPTER 13.20 - ELECTRICAL SERVICE - BY REPEALING AND RE-ENACTING ARTICLE III, "RATES," IN ITS ENTIRETY PUBLISH DATE: SATURDAY, FEBRUARY 4, 2017 LEGAL AD TEAR SHEETS WANTED: One (1) please SEND AFFIDAVIT AND BILL TO: LNS ACCT. #0510052 JENNIFER M. FERRAIOLO, CITY CLERK City of Lodi P.O. Box 3006 Lodi, CA 95241-1910 DATED: THURSDAY, FEBRUARY 2, 2017 ORDERED BY: JENNIFER M. FERRAIOLO CITY CLERK PAMELA M. FARRIS DEPUTY CITY CLERK ELIZABETH BURGOS ADMINISTRATIVE CLERK Verify Appearance of this Legal in the Newspaper — Copy to File Emailed to the Sentinel at dianer@lodinews.com at /D = /ne) on LNS Phoned to confirm receipt of all pages at (time) ,E8 /7(date) (pages) _PMF (initials) forms\advins.doc DECLARATION OF POSTING PUBLIC HEARING TO CONSIDER INTRODUCING ORDINANCE AMENDING LODI MUNICIPAL CODE CHAPTER 13.20 — ELECTRICAL SERVICE — BY REPEALING AND RE-ENACTING ARTICLE III, "RATES," IN ITS ENTIRETY On Thursday, February 2, 2017, in the City of Lodi, San Joaquin County, California, a Notice of Public Hearing to consider introducing ordinance amending Lodi Municipal Code Chapter 13.20 — Electrical Service — by repealing and re-enacting Article 111, "Rates," in its entirety (attached and marked as Exhibit A) was posted at the following locations: Lodi City Clerk's Office Lodi City Hall Lobby Lodi Carnegie Forum WorkNet Office I declare under penalty of perjury that the foregoing is true and correct. Executed on February 2, 2017, at Lodi, California. PAMELA M. FARRIS DEPUTYCITY CLERK ORDERED BY: JENNIFER M. FERRAIOLO CITY CLERK ELIZABETH BURGOS ADMINISTRATIVE CLERK N:\Administration\CLERK\Public Hearings\AFFADAVITS\DECPOSTEUD.DOC CITY OF LODI Carnegie Forum 305 West Pine Street, Lodi NOTICE OF PUBLIC HEARING Date: March 1, 2017 Time: 7:00 p.m. 1 For information regarding this notice please contact: Jennifer M. Ferraiolo City Clerk Telephone: (209) 333-6702 J EYL911A NOTICE OF PUBLIC HEARING NOTICE IS HEREBY GIVEN that on Wednesday, March 1, 2017, at the hour of 7:00 p.m., or as soon thereafter as the matter may be heard, the City Council will conduct a public hearing at the Carnegie Forum, 305 West Pine Street, Lodi, to consider the following matter: a) Introduce ordinance amending Lodi Municipal Code Chapter 13.20 — Electrical Service — by repealing and re-enacting Article III, "Rates," in its entirety (as identified on the attached Exhibit A). Information regarding this item may be obtained in the Electric Utility Department, 1331 South Ham Lane, Lodi, (209) 333-6762. All interested persons are invited to present their views and comments on this matter. Written statements may be filed with the City Clerk, City Hall, 221 West Pine Street, 2nd Floor, Lodi, 95240, at any time prior to the hearing scheduled herein, and oral statements may be made at said hearing. If you challenge the subject matter in court, you may be limited to raising only those issues you or someone else raised at the public hearing described in this notice or in written correspondence delivered to the City Clerk, 221 West Pine Street, at or prior to the close of the public hearing. By Order of the Lodi City Council: nifer .Ferraiolo City Clerk Dated: February 1, 2017 Approved as to form: Janice 13:'Magdich City Attorney AVISO: Para obtener ayuda interpretativa con esta noticia, por favor (lame a la oficina de la Secretaria Municipal, a las (209) 333-6702. CLERK\PUBHEAR\NOTICES\Noteud.doc 1/27/17 EXHIBIT C Lodi Electric Utility Proposed 2017 Rate Changes Energy Tier(s) Rate(s) Current Proposed RESIDENTIAL - Schedule EA Customer Charge N/A $ 10.00 $ 10.20 Energy Charge -Summer ($/kWh) Tier 1 0-481 kWh / month $ 0.1400 $ 0.1428 Tier 2 482 - 962 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 962 kWh / month $ 0.3300 $ 0.3366 Energy Charge - Winter ($/kWh) Tier 1 0 - 391 kWh / month $ 0.1400 $ 0.1428 Tier 2 392 - 782 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 782 kWh / month $ 0.3300 $ 0.3366 MOBILE NOME PARK - Schedule EM Customer Charge (Master Meter Customer) N/A $ 1.00 $ 1.02 Energy Charge - Summer ($/kWh) Tier 1 0 -481 kWh / month $ 0.1400 $ 0.1428 Tier 2 482 - 962 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 962 kWh / month $ 0.3300 $ 0.3366 Energy Charge - Winter ($/kWh) Tier 1 0 - 391 kWh / month $ 0.1400 $ 0.1428 Tier 2 392 - 782 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 782 kWh / month $ 0.3300 $ 0.3366 DUSK -TO -DAWN LIGHTING - Schedule EL 6,000 lumen gas discharge lamp (each) - per billing cycle N/A $ 12.76 $ 13.02 18,000 lumen gas discharge lamp (each) - per billing cycle N/A $ 23.69 $ 24.16 CITY FAC I L! T I E S- Schedule E5 Minimum Charge N/A $ 5.25 $ Customer Charge N/A $ - $ 10.20 Energy Charge ($/kWh) All kWh $ 0.10948 $ 0.10890 COMMERCIAL/INDUSTRIAL-Schedule 61 (' 8,000 kWh/month) Customer Charge Single -Phase Service N/A $ 7.35 $ 7.50 Three -Phase or Combination Service N/A $ 10.87 $ 11.09 Energy Charge ($/kWh) Summer See Notes $ 0.18883 $ 0.19261 Winter See Notes $ 0.13965 $ 0.14244 COMMERCIAL/INDUSTRFAL - Schedule G2 (> 5,000 kWh/mouth] Customer Charge N/A $ 59.20 $ 60.38 Demand Charge ($/kW) N/A $ 4.10 $ 4.18 Energy Charge ($/kWh) Summer See Notes $ 0.15519 $ 0.15829 Winter See Notes $ 0.12423 $ 0.12671 COMMERCIAL/INDUSTRIAL - Schedule G3-5 (Secondary) (400 kW - 500 kW/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 4.10 $ 4.18 Peak Demand Charge - Summer ($/kW) N/A $ 11.47 $ 11.70 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.16890 $ 0.17228 Part -Peak See Notes $ 0.13528 $ 0.13799 Off -Peak See Notes $ 0.11621 $ 0.11853 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.12259 $ 0.12504 Off -Peak See Notes $ 0.11188 $ 0.11412 Page 1 of 3 EXHIBIT C COMMERCIAL/INDUSTRIAL - Schedule G3 -P (Primary) (400 kW - 500 kW/month} N/A $ 134.54 $ 137.23 Customer Charge N/A $ 3.17 $ 3.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 10.76 $ 10.98 Peak Demand Charge - Summer ($/kW) Energy Charges - Summer ($/kWh) See Notes $ 0.16280 $ 0.16606 Peak See Notes $ 0.13086 $ 0.13348 Part -Peak See Notes $ 0.11274 $ 0.11499 Off -Peak Energy Charges - Winter ($/kWh) See Notes $ 0.11880 $ 0.12118 Part -Peak See Notes $ 0.10862 $ 0.11079 Off -Peak C0MMERCIAL/INDUSTRIAL -Schedule G4-5 (Secondary] (500 kW -1.000 kW/month] N/A $ 134.54 $ 137.23 Customer Charge N/A $ 4.10 $ 4.18 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 11.47 $ 11.70 Peak Demand Charge - Summer ($/kW) Energy Charges -Summer ($/kWh) See Notes $ 0.15592 $ 0.15904 Peak See Notes $ 0.12225 $ 0.12470 PartPeak See Notes $ 0.10322 $ 0.10528 Off -Peak Energy Charges - Winter ($/kWh) See Notes $ 0.11031 $ 0.11252 Part -Peak See Notes $ 0.09969 $ 0.10168 Off -Peak COMMERCIAL/INDUSTRIAL - Schedule G4 -P (Primary) (500 kW -1,000 kW/month) N/A $ 134.54 $ 137.23 Customer Charge N/A $ 3.17 $ 3.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 10.76 $ 10.98 Peak Demand Charge - Summer ($/kW) Energy Charges - Summer ($/kWh) See Notes $ 0.14988 $ 0.15288 Peak See Notes $ 0.11791 $ 0.12027 Part -Peak See Notes $ 0.09981 $ 0.10181 Off -Peak Energy Charges - Winter ($/kWh) See Notes $ 0.10657 $ 0.10870 Part -Peak See Notes $ 0.09647 $ 0.09840 Off -Peak COMMERCIAL/INDUSTRIAL - Schedule G5 -S (Secondary) (> 1,000 kW/month) N/A $ 134,54 $ 137.23 Customer Charge N/A $ 4.10 $ 4.18 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 11.47 $ 11.70 Peak Demand Charge - Summer ($/kW) Energy Charges - Summer ($/kWh) Peak See Notes $ 0.14365 $ 0.14652 See Notes $ 0.11005 $ 0.11225 Part -Peak See Notes $ 0.09311 $ 0.09497 Off -Peak Energy Charges - Winter ($/kWh) See Notes $ 0.09825 $ 0.10022 Part -Peak See Notes $ 0.09009 $ 0.09189 Off -Peak All kWh $ 0.00431 $ 0.00440 Economic Stimulus Rate Credit ($/kWh) COMMERCIAL/INDUSTRIAL - Schedule G5 -P (Primary) (>1,000 kW/month) N/A $ 134.54 $ 137.23 Customer Charge N/A $ 3,17 $ 3.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 10.76 $ 10.98 Peak Demand Charge - Summer ($/kW) Energy Charges - Summer ($/kWh) See Notes $ 0.13794 $ 0.14070 Peak See Notes $ 0.10602 $ 0.10814 PartPeak See Notes $ 0.08993 $ 0.09173 Off -Peak Energy Charges - Winter ($/kWh) See Notes $ 0.09481 $ 0.09671 Part -Peak See Notes $ 0.08706 $ 0.088 Off -Peak All kWh $ 0.00431 $ 0.00440 Economic Stimulus Rate Credit ($/kWh) Page 2of3 EXHIBIT C EP ENERGY PURCHASE - Schedule EP N/A Contract Basis Avoided Cost Compensation for customer owned generation COMMERCIAL/INDUSTRIAL - OPTIONAL - Schedule 11 (>1,000 kW/month) - Special Conditions Apply N/A $ 134.54 $ 137.23 Customer Charge N/A $ 3.17 $ 3.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 10.76 $ 13.23 Peak Demand Charge - Summer ($/kW) Customers with demand <4.000 kW: Energy Charges - Summer ($/kWh) See Notes $ 0.14029 $ 0.14310 Peak See Notes $ 0.10807 $ 0.11023 Part -Peak See Notes $ 0.09245 $ 0.09430 Off -Peak Energy Charges - Winter ($/kWh)Part-PeaSee Notes $ 0.09972 $ 0.10171 Off -Peak See Notes $ 0.09177 $ 0.09361 Off -Peak Customers with demand x 4,000 kW Energy Charges - Summer ($/kWh) Peak See Notes $ 0.13378 $ 0.13646 Part -Peak See Notes $ 0.10156 $ 0.10359 See Notes $ 0.08594 $ 0.08766 Off -Peak Energy Charges - Winter ($/kWh) See Notes $ 0.09321 $ 0.09507 Part -Peak See Notes $ 0.08526 $ 0.08697 Off -Peak Economic Stimulus Rate Credit ($/kWh) All kWh $ 0.01359 $ 0.01386 ELECTRIC VEHICLE CHARGING SERVICE -Schedule EV N/A $ 5.25 $ Minimum Charge N/A $ $ 3.00 Customer Charge Energy Charge ($/kWh) EV Charging Period Non -EV Charging Period NOTES: Summer (May 1 through Oct 31) Peak: 3 pm to 7 pm - Mon through Fri (except holidays) Part -Peak: 8:30 am to 3 pm and 7 pm to 9:30 pm - Mon through Fri (except holidays) Off -Peak: 9:30 pm to 8:30 am - Mon through Fri and all day Sat, Sun, holidays Schedule EA Tier 1 See Notes $ 0.14910 Energy Charge Schedule EA Tier 3 See Notes $ 0.34650 Energy Charge Winter (Nov 1 through Apr 30) Part -Peak: 8:30 am to 9:30 pm - Mon through Fri (except holidays) Off -Peak: 9:30 pm to 8:30 am - Mon through Fri and all day Sat, Sun, holidays EV Charging Period 8 pm to 6 am - Mon through Fri (and all day weekends and holidays) Non -EV Charging Period: 6 am to 8 pm - Mon through Fri (excluding weekends and holidays) Holidays include: New Year's Day, Presidents' Day, Memorial Day, Independence Day, Labor Day, Veterans' Day, Thanksgiving Day, the day after Thanksgiving Day and Christmas Day. The dates will be based on those days on which the holidays are legally observed. Page 3of3 Please immediately confirm receipt of this fax by calling 333-6702 CITY OF LODI P. O. BOX 3006 LODI, CALIFORNIA 95241-1910 ADVERTISING INSTRUCTIONS SUBJECT: CONTINUED PUBLIC HEARING TO CONSIDER INTRODUCING AN ORDINANCE AMENDING LODI MUNICIPAL CODE CHAPTER 13.20 - ELECTRICAL SERVICE - BY REPEALING AND RE-ENACTING ARTICLE III, "RATES," IN ITS ENTIRETY PUBLISH DATE: SATURDAY, MARCH 4, 2017 LEGAL AD TEAR SHEETS WANTED: One (1] please SEND AFFIDAVIT AND BILL TO: LNS ACCT. #0510052 DATED: THURSDAY, MARCH 2, 2017 JENNIFER M. FERRAIOLO, CITY CLERK City of Lodi ' P.O. Box 3006 Lodi, CA 95241-1910 ORDERED BY: JENNIFER M. FERRAIOLO CITY CLERK N...72gAA-z;c, (,92 PAMELA M. FARRIS DEPUTY CITY CLERK ELIZABETH BURGOS ADMINISTRATIVE CLERK Verify Appearance of this Legal in the Newspaper — Copy to File Emailed to the Sentinel at dianer@lodinews.com at (time) on LNS Phoned to confirm receipt of all pages at (time) ____,EB PMF (initials) (date) (pages) forms\advins.doc DECLARATION OF POSTING CONTINUED PUBLIC HEARING TO CONSIDER INTRODUCING ORDINANCE AMENDING LODI MUNICIPAL CODE CHAPTER 13.20 — ELECTRICAL SERVICE — BY REPEALING AND RE-ENACTING ARTICLE III, "RATES," IN ITS ENTIRETY On Thursday, March 2, 2017, in the City of Lodi, San Joaquin County, California, a Notice of Continued Public Hearing to consider introducing ordinance amending Lodi Municipal Code Chapter 13.20 — Electrical Service — by repealing and re-enacting Article III, "Rates," in its entirety (attached and marked as Exhibit A) was posted at the following locations: Lodi City Clerk's Office Lodi City Hall Lobby Lodi Carnegie Forum WorkNet Office I declare under penalty of perjury that the foregoing is true and correct. Executed on March 2, 2017, at Lodi, California. r �E_Aly - PAMELA M. FARRIS ELIZABETH BURGOS DEPUTYCITY CLERK ADMINISTRATIVE CLERK ORDERED BY: JENNIFER M. FERRAIOLO CITY CLERK N:\Administration\CLERK\Public Hearings\AFFADAVITS\DECPOSTEUD.DOC CITY OF LODI Carnegie Forum 305 West Pine Street, Lodi NOTICE OF CONTINUED PUBLIC HEARING Date: April 5, 2017 Time: 7:00 p.m. For information regarding this notice please contact: Jennifer M. Ferraiolo City Clerk Telephone: (209) 333-6702 1 NOTICE OF CONTINUED PUBLIC HEARING NOTICE IS HEREBY GIVEN that on Wednesday, April 5, 2017, at the hour of 7:00 p.m., or as soon thereafter as the matter may be heard, the City Council will conduct a public hearing at the Carnegie Forum, 305 West Pine Street, Lodi, to consider the following matter: a) Introduce ordinance amending Lodi Municipal Code Chapter 13.20 — Electrical Service — by repealing and re-enacting Article III, "Rates," in its entirety (as identified on the attached Exhibit A). Information regarding this item may be obtained in the Electric Utility Department, 1331 South Ham Lane, Lodi, (209) 333-6762. All interested persons are invited to present their views and comments on this matter. Written statements may be filed with the City Clerk, City Hall, 221 West Pine Street, 2nd Floor, Lodi, 95240, at any time prior to the hearing scheduled herein, and oral statements may be made at said hearing. If you challenge the subject matter in court, you may be limited to raising only those issues you or someone else raised at the public hearing described in this notice or in written correspondence delivered to the City Clerk, 221 West Pine Street, at or prior to the close of the public hearing. By Order of the Lodi City Council: +nnifer ity Clerk Dated: March 1, 2017 Approved as to form: Janice D. Magdich City Attorney Ferraiolo 1:&u a.�,o�e AVISO: Para obtener ayuda interpretativa con esta noticia, por favor Ilame a la oficina de la Secretaria Municipal, a las (209) 333-6702. CLERK\PUBHEARINOTICES\Noteud.doc 3/1/17 EXHIBIT A Lodi Electric Utility Proposed 2017 Rate Changes Energy Tier(s) Rate(s) Current Pro0osed RESIDENTIAL - Schedule EA Customer Charge N/A $ 1000 $ 10.20 Energy Charge - Summer ($/kWh) Tier 1 0 -481 kWh / month $ 0.1400 $ 0.1428 Tier 2 482 - 962 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 962 kWh / month $ 0.3300 $ 0.3366 Energy Charge - Winter ($/kWh) Tier 1 0 - 391 kWh / month $ 0.1400 $ 0.1428 Tier 2 392 - 782 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 782 kWh / month $ 0.3300 $ 0.3366 MOBILE HOME PARK -Schedule EM Customer Charge (Master Meter Customer) N/A $ 1.00 $ 1.02 Energy Charge - Summer ($/kWh) Tier 1 0-481 kWh / month $ 0.1400 $ 0.1428 Tier 2 482 - 962 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 962 kWh / month $ 0.3300 $ 0.3366 Energy Charge - Winter ($/kWh) Tier 1 0 - 391 kWh / month $ 0.1400 $ 0.1428 Tier 2 392 - 782 kWh / month $ 0.1550 $ 0.1581 Tier 3 > 782 kWh / month $ 0.3300 $ 0.3366 DUSK -TO -DAWN LIGHTING - Schedule EL 6,000 lumen gas discharge lamp (each) - per billing cycle N/A $ 12.76 $ 13.02 18,000 lumen gas discharge lamp (each) - per billing cycle N/A $ 23.69 $ 24.16 CITY FAC1UTIES - Schedule E5 Minimum Charge N/A $ 5.25 $ - Customer Charge N/A $ - $ 10.20 Energy Charge ($/kWh) All kWh $ 0.10948 $ 0.10890 COMMERCIAL/INDUSTRIAL - Schedu[e G1 (< $ 000 kWh/month) Customer Charge Single -Phase Service N/A $ 7.35 $ 7.50 Three -Phase or Combination Service N/A $ 10.87 $ 11.09 Energy Charge ($/kWh) Summer See Notes $ 0.18883 $ 0.19261 Winter See Notes $ 0.13965 $ 0.14244 COMMERCIAL/INDUSTRIAL - Schedule G21> 8,000 kWh/rno ntkil Customer Charge N/A $ 59.20 $ 60.38 Demand Charge ($/kW) N/A $ 4.10 $ 4.18 Energy Charge ($/kWh) Summer See Notes $ 0.15519 $ 0.15829 Winter See Notes $ 0.12423 $ 0.12671 COMMERCIAL(INDUSTRIAL - Schedule G3.5 lSecondarvl 000 kW - 500 kW/month} Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 4.10 $ 4.18 Peak Demand Charge - Summer ($/kW) N/A $ 11.47 $ 11.70 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.16890 $ 0.17228 Part -Peak See Notes $ 0.13528 $ 0.13799 Off -Peak See Notes $ 0.11621 $ 0.11853 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.12259 $ 0.12504 Off -Peak See Notes $ 0.11188 $ 0.11412 Page 1 of 3 EXHIBIT A COMMERCIAL/INDUSTRIAL- Schedule G3 -P (Primary} {400 kW -500 kw/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 3.17 $ 3.23 Peak Demand Charge - Summer ($/kW) N/A $ 10.76 $ 10.98 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.16280 $ 0.16606 Part -Peak See Notes $ 0.13086 $ 0.13348 Off -Peak See Notes $ 0.11274 $ 0.11499 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.11880 $ 0.12118 Off -Peak See Notes $ 0.10862 $ 0.11079 COMMERCIAL/INDUSTRIAL - Schedule G4 -S (Secondary] (500 kW - 1,000 MA//montill Customer Charge N/A $ 134.54 $ 137,23 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 4.10 $ 4.18 Peak Demand Charge - Summer ($/kW) N/A $ 11.47 $ 11.70 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.15592 $ 0.15904 Part -Peak See Notes $ 0.12225 $ 0.12470 Off -Peak See Notes $ 0.10322 $ 0.10528 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.11031 $ 0.11252 Off -Peak See Notes $ 0.09969 $ 0.10168 COMMERCIAL/INDUSTRIAL - Schedule G4 -P (Primary) (500 kW -1,000 kW/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 3.17 $ 3.23 Peak Demand Charge - Summer ($/kW) N/A $ 10.76 $ 10.98 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.14988 $ 0.15288 Part -Peak See Notes $ 0.11791 $ 0.12027 Off -Peak See Notes $ 0.09981 $ 0.10181 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.10657 $ 0.10870 Off -Peak See Notes $ 0.09647 $ 0.09840 COMMERCIAL/INDUSTRIAL - Schedule G5 -S (Secondary) (> 1,000 kW/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 4.10 $ 4.18 Demand Charge - Winter ($/kW) N/A $ 4.10 $ 4.18 Peak Demand Charge - Summer ($/kW) N/A $ 11.47 $ 11.70 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.14365 $ 0.14652 Part -Peak See Notes $ 0.11005 $ 0.11225 Off -Peak See Notes $ 0.09311 $ 0.09497 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.09825 $ 0.10022 Off -Peak See Notes $ 0.09009 $ 0.09189 Economic Stimulus Rate Credit ($/kWh) All kWh $ 0.00431 $ 0.00440 COMMERCIAL/INDUSTRIAL - Schedule G5 -P (Primary) (>1,000 kW/month) Customer Charge N/A $ 134.54 $ 137.23 Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 3.17 $ 3.23 Peak Demand Charge - Summer ($/kW) N/A $ 10.76 $ 10.98 Energy Charges - Summer ($/kWh) Peak See Notes $ 0.13794 $ 0.14070 Part -Peak See Notes $ 0.10602 $ 0.10814 Off -Peak See Notes $ 0.08993 $ 0.09173 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.09481 $ 0.09671 Off -Peak See Notes $ 0.08706 $ 0.08880 Economic Stimulus Rate Credit ($/kWh) All kWh $ 0.00431 $ 0.00440 Page 2of3 EXHIBIT A EP ENERGY PURCHASE - Schedule EP Compensation for customer owned generation N/A Contract Basis Avoided Cost COMMERCIAL/INDUSTRIAL - OPTIONAL - Schedule I1(>1,000 kW/month) - Special Conditions Apply N/A $ 134.54 $ 137.23 Customer Charge Demand Charge - Summer ($/kW) N/A $ 3.17 $ 3.23 Demand Charge - Winter ($/kW) N/A $ 3.17 $ 3.23 Peak Demand Charge - Summer ($/kW) N/A $ 10.76 $ 10.98 Customers +Nath demand c 4,000 kW: Energy Charges -Summer ($/kWh) Peak See Notes $ 0.14029 $ 0.14310 Part -Peak See Notes $ 0.10807 $ 0.11023 Off -Peak See Notes $ 0.09245 $ 0.09430 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.09972 $ 0.10171 Off -Peak See Notes $ 0.09177 $ 0.09361 Custanz:ers with demand z 4000 kW Energy Charges - Summer ($/kWh) Peak See Notes $ 0.13378 $ 0.13646 Part -Peak See Notes $ 0.10156 $ 0.10359 Off -Peak See Notes $ 0.08594 $ 0.08766 Energy Charges - Winter ($/kWh) Part -Peak See Notes $ 0.09321 $ 0.09507 Off -Peak See Notes $ 0.08526 $ 0.08697 Economic Stimulus Rate Credit ($/kWh) All kWh $ 0.01359 $ 0.01386 ELECTRIC VEHICLE CHARGING SERVICE -Schedule EV Minimum Charge N/A $ 5.25 $ Customer Charge N/A $ - $ 3.00 Energy Charge ($/kWh) EV Charging Period Non -EV Charging Period NOTES: Summer (May 1 through Oct 31) Peak: 3 pm to 7 pm - Mon through Fri (except holidays) Part -Peak: 8:30 am to 3 pm and 7 pm to 9:30 pm - Mon through Fri (except holidays) Off -Peak: 9:30 pm to 8:30 am - Mon through Fri and all day Sat, Sun, holidays Winter (Nov 1 through Apr 30) Part -Peak: 8:30 am to 9:30 pm - Mon through Fri (except holidays) Off -Peak: 9:30 pm to 8:30 am - Mon through Fri and all day Sat, Sun, holidays Schedule EA Tier 1 See Notes $ 0.14910 Energy Charge Schedule EA Tier 3 See Notes $ 0.34650 Energy Charge EV Charging Period: 8 pm to 6 am - Mon through Fri (and all day weekends and holidays) Non -EV Charging Period: 6 am to 8 pm - Mon through Fri (excluding weekends and holidays) Holidays include: New Year's Day, Presidents' Day, Memorial Day, Independence Day, Labor Day, Veterans' Day, Thanksgiving Day, the day after Thanksgiving Day and Christmas Day. The dates will be based on those days on which the holidays are legally observed. Page 3 of 3