addendum no. 1 - socccd · addendum no. 1 date: may 10, 2013 ... waukesha l7042 gsi c-14437/2 10...

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ADDENDUM NO. 1

Date: May 10, 2013

for

Cogeneration and Central Plant Operation, Maintenance Equipment Refresh and Environmental Compliance Services

Saddleback College - BID # 2009 South Orange County Community College District

General-All project documents including contract documents, drawings, and specifications, shall remain unchanged with the exception of those elements added, revised, deleted, or clarified by this addendum.

CONTENTS

ADDENDUM ITEMS

INDEX PAGE 1 ITEMS: 1-1 Pre-Qualification, Bid and Award Schedule (Revision) PAGE 2 1-2 Attachments PAGE 2 Exhibit II – SDGE Al – TOU – Interconnect Agreement Exhibit III – Sample Service levels Exhibit IV – System Schematics Exhibit VII – Condition Assessment Exhibit IX – AQMD Permits

Cogeneration and Central Plant Operation, Maintenance and Environmental Compliance Services Saddleback College - BID # 2009

Addendum #1 May 10, 2013

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1-1 Pre-Qualification, Bid and Award Schedule (Revision) From: .9 Debriefing meetings – Morning of June 10, 2013 To: .9 Debriefing meetings – Morning of June 11, 2013 1-2 Attachments Add: Add attachments at the Exhibits identified in the model contract: Exhibit II – SDGE Al – TOU – Interconnect Agreement at Exhibit II cover Exhibit III – Sample Service levels at Exhibit III cover Exhibit IV – System Schematics at Exhibit IV cover Exhibit VII – Condition Assessment at Exhibit VII cover Exhibit IX – AQMD Permits at Exhibit IX cover

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EXHIBIT II SUMMER 2012 BILLING

Hour Reading Due Gas Reading Date Initial Hour Reading Due Gas Reading2,226 247 54,739 4-Jan JEB 3,606 107 51,967

2,226 247 54,739 11-Jan JEB 3,606 107 51,967

2,226 247 54,739 18-Jan JEB 3,606 107 51,967

2,226 247 54,739 25-Jan JEB 3,606 107 51,967

2,247 226 55,309 1-Feb JEB 3,617 96 52,194

2,264 209 55,873 8-Feb JEB 3,624 89 52,437

2,287 186 56,434 15-Feb JEB 3,631 82 52,665

2,295 178 57,008 22-Feb JEB 3,635 78 52,891

2,319 154 57,567 29-Feb JEB 3,644 69 53,120

2,332 141 58,131 7-Mar JEB 3,659 54 53,358

2,356 117 58,706 14-Mar JEB 3,660 53 53,599

2,375 98 59,267 21-Mar JEB 3,675 38 53,821

2,390 83 59,837 28-Mar JEB 3,683 30 54,057

2,403 70 60,399 4-Apr JEB 3,682 31 54,282

2,428 45 60,964 11-Apr JEB 3,699 14 54,519

2,444 29 61,531 18-Apr JEB 3,705 8 54,751

2,464 9 62,096 25-Apr JEB 3,712 1 54,982

2,472 1 62,284 1-May JEB 3,712 1 54,982

2,472 1 62,284 8-May JEB 3,712 1 54,982

2,472 1 62,284 15-May JEB 3,712 1 54,982

2,472 1 62,284 22-May JEB 3,712 1 54,982

2,472 1 62,284 29-May JEB 3,712 1 54,982

2,472 1 62,284 5-Jun JEB 3,712 1 54,982

2,472 1 62,284 12-Jun JEB 3,712 1 54,982

2,472 1 62,284 19-Jun JEB 3,712 1 54,982

2,472 1 62,284 26-Jun JEB 3,712 1 54,982

2,472 1 62,284 3-Jul JEB 3,712 1 54,982

2,500 750 63,134 10-Jul JEB 3,723 750 55,225

2,527 723 63,987 17-Jul JM 3,727 746 55,460

2,559 691 64,834 24-Jul JM 3,739 734 55,703

2,583 667 65,686 31-Jul JM 3,745 728 55,932

2,616 634 66,530 7-Aug JS 3,758 715 56,177

2,643 607 67,382 14-Aug JS 3,767 706 56,411

2,669 581 68,227 21-Aug JS 3,772 701 56,654

2,696 554 69,074 28-Aug JS 3,783 690 56,897

2,761 489 70,813 4-Sep DJ 3,789 684 57,069

2,780 470 71,369 11-Sep DJ 3,805 668 57,569

2,799 451 71,925 18-Sep DJ 3,821 652 58,069

2,832 418 72,848 25-Sep DJ 3,839 634 58,591

2,894 356 74,584 2-Oct DJ 3,843 630 58,720

2,933 317 75,633 9-Oct DJ 3,848 625 58,869

2,945 305 75,969 16-Oct DJ 3,852 621 58,984

2,965 285 76,306 23-Oct DJ 3,868 603 59,406

3,046 204 77,971 30-Oct DJ 3,975 496 62,195

3,046 204 77,971 6-Nov DJ 4,072 399 64,847

3,046 204 77,971 13-Nov DJ 4,249 222 70,165

3,138 112 80,410 20-Nov DJ 4,249 222 70,167

3,233 17 83,249 27-Nov DJ 4,268 203 70,805

4-Dec11-Dec18-Dec25-Dec

Boiler #2Boiler #12012 Boiler #1 & #2 Logs

Page 1 of 2

O2 Sensor Setpoint

O2 Sensor Voltage

Catalyst Inlet

Catalyst Outlet

Engine Hours

Since Check

Faults & Alarms Date Initial

O2 Sensor Setpoint

O2 Sensor Voltage

Catalyst Inlet

Catalyst Outlet

Engine Hours

Since Check

Faults & Alarms

1.02-1.05 1.02-1.05 1000-1250 1000-1350 N/A 0-750 None 1.02-1.05 1.02-1.05 1000-1250 1000-1350 0-750 0-750 None

Phi Phi Degrees F Degrees F Hours Hours N/A Phi Phi Degrees F Degrees F Hours Hours N/A

1.034 1.034 711 220 8,592 24 None 31-Dec DJ 1.034 1.034 711 220 9,408 120 None1-Jan DJ 1.034 1.034 711 220 9,432 144 None2-Jan DJ 1.034 1.034 711 220 9,456 168 None3-Jan DJ 1.034 1.034 711 220 9,480 192 None4-Jan DJ 1.034 1.034 711 220 9,504 216 None5-Jan DJ 1.034 1.034 711 220 9,528 240 None6-Jan DJ 1.034 1.034 711 220 9,552 264 None7-Jan DJ 1.034 1.034 711 220 9,576 288 None8-Jan DJ

1.034 1.034 711 220 8,616 48 None 9-Jan DJ1.034 1.034 711 220 8,640 72 None 10-Jan DJ1.034 1.034 711 220 8,664 96 None 11-Jan DJ1.034 1.034 711 220 8,688 120 None 12-Jan DJ1.034 1.034 711 220 8,712 144 None 13-Jan DJ1.034 1.034 711 220 8,736 168 None 14-Jan DJ1.034 1.034 711 220 8,760 192 None 15-Jan DJ

16-Jan17-Jan18-Jan19-Jan20-Jan21-Jan22-Jan23-Jan24-Jan25-Jan26-Jan27-Jan28-Jan29-Jan

Engine #12013 Engine #1 & #2 Logs

Engine #2Engine Hours + 60,000

Page 2 of 2

1 of 3 Attachment A-1 Condition Assessment(information provided by CalPwr December 2012)

Equipment Name Description Serial Number Age ConditionPOWER GENERATION

Engine #1 Waukesha L7042 GSI C-14437/2 10 years InFrame 2010 - Top End 2012Engine Controller #1 Woodward 2301 D 13278905 10 years GoodAir/Fuel Controller MEC-R Compliance Controls 3566-7725 06 years GoodIgnition Controller Murphy Power 01-501-100 06 years GoodSynchronizer #1 Bassler BE3-25A 7195 10 years GoodVoltage Regulator #1 Kato K125-10B 81035353-00 10 years GoodProtective Relay #1 SEL 300 G (Schlietzer) 2003056014 10 years GoodGenerator #1 Kato 750 kW 12 kV 15123-02 10 years Good12 kV Generator Breaker #1 Siemens 15GMI-500-1200-37 MV100434200-2 10 years GoodExhaust Heat Recovery Unit Cain Unit #1 3956 10 years GoodExhaust Silencer Miratec SP RHSS-4522-C 01 years Good New 2012Exhaust Catalyst Miratec 01 years Good New 2012Plate & Frame HX #1 Ameridex 93945 10 years GoodRadiator #1 Young Touchstone 2905322 10 years GoodFluid Cooler #1 Evapco WO37231 06 years Good New 2012

Engine #2 Waukesha L7042 GSI C-14437/1 10 years InFrame 2010 - Top End 2012Engine Controller #2 Woodward 2301 D 13262848 10 years GoodAir/Fuel Controller MEC-R Compliance Controls 3566-7725 06 years GoodIgnition Controller Murphy Power 01-501-100 06 years GoodSynchronizer #2 Bassler BE3-25A 7194 10 years GoodVoltage Regulator #2 Kato K125-10B 81035353-00 10 years GoodProtective Relay #2 SEL 300G (Schlietzer) 2003056015 10 years GoodGenerator #2 Kato 750 kW 12 kV 15123-01 10 years Good12 kV Generator Breaker #2 Siemens 15GMI-500-1200-37 MV100434200-1 10 years GoodExhaust Heat Recovery Unit Cain Unit #2 3957 10 years GoodExhaust Silencer Miratec SP RHSS-4522-C 01 years Good New 2012Exhaust Catalyst Miratec 01 years Good New 2012Plate & Frame HX #2 Ameridex 93944 10 years GoodRadiator #2 Young Touchstone 2905321 10 years GoodFluid Cooler #2 Evapco WO37232 06 years Good New 2012

POWER DISTRIBUTIONSDG&E Main Breaker Westinghouse VCP-W 92043351 17 years GoodProtective Relay (SDG&E) SEL 351S (Schlietzer) 2003099069 10 years GoodProtective Relay Beckwith 391 10 years Good12kV Breaker Westinghouse VCP-W 92043349 10 years Good12kV Breaker Westinghouse VCP-W 92043348 10 years Good12kV-480VAC Transformer "A" RSE Sierra ? 30 years Needs Replacement12kV-480VAC Transformer "B" MGM Transformer Co. 97-2-6983 10 years Fair


Equipment Name Description Serial Number Age ConditionHEATING LOOP

Hot Water Pump #1 20 HP Motor/488 GPM CP5811-2 10 years FairHot Water Pump #2 20 HP Motor/488 GPM CP5811-3 10 years FairHot Water Pump #3 20 HP Motor/488 GPM CP5811-1 10 years FairHot Water Pump #4 3 HP Motor/488 GPM CP5182-01 10 years FairHot Water Pump #5 3 HP Motor/488 GPM CP5182-02 10 years FairHot Water Pump #6 5 HP Motor/500 GPM CP5421-02 10 years FairHot Water Pump #7 3 HP Motor/465 GPM CP5421-01 10 years FairHot Water Pump #8 5 HP Motor/500 GPM CP5422-02 10 years FairHot Water Pump #9 3 HP Motor/465 GPM CP5422-01 10 years FairHot Water Expansion Tank Bell & Gosset B-122 01 years Good New in 2012Hot Water Air Separator 10 years FairBoiler #1 Parker 6,300,00 BTU 54547 10 years FairBoiler #2 Parker 6,300,00 BTU 54546 10 years Fair

COOLING LOOP1000 ton Chiller York Centrifugal GNDM 120890 17 years Good600 ton Chiller York Centrifugal SNDM 839220 17 years Good600 ton Chiller VFD York Centrifugal 00278HO797 11 years Good380 ton Absorption Chiller Thermax LT38T 7 05 years GoodCooling Tower #1 Marley 108719003-NC7221CM-97 16 years FairCooling Tower #2 Marley 108719001-NC7221CM-97 16 years PoorAbsorption Chiller Pump 10 hp motor Bell & Gosset 26A6008/1002598926 05 years GoodChill Water Pump #1 125 hp motor/2110 GPM CP5841-02 14 years GoodCWP 001 VFD Danfoss VLT 5000 807301Y133 10 years GoodChill Water Pump #2 125 hp motor/2110 GPM CP5841-01 14 years GoodCWP 002 VFD Danfoss VLT 5000 807501Y133 10 years GoodChill Water Pump #3 125 hp motor/2110 GPM CP5841-03 14 years GoodCWP 003 VFD Danfoss VLT 5000 807401Y133 10 years GoodChill Water Pump #4 (1000 Ton Chiller) 25 hp motor/2400 GPM BE87362 05 years GoodChill Water Pump #5 (6000 Ton Chiller) 15 hp motor/1440 GPM CP5831-01 14 years GoodThermal Storage Primary Pump 125 HP Motor/2750 GPM AJ91D0434A02 19 years FairThermal Storage Secondary Pump 125 HP Motor/2750 GPM ? 19 years FairCondenser Water Pump #5 100 hp motor/ 97JG6058 33 years FairCondenser Water Pump #6 100 hp motor/ ? 33 years FairCondenser Water Pump #7 100 hp motor/ 97JG6059 33 years FairSand Filter PEP ? 05 years Good


Equipment Name Description Serial Number Age ConditionMISCELLANEOUS

Program Logic Controls (PLC) Allen Bradley Plant operations PLC 10 years GoodEvaporative Cooler #1 Champion 14/21 DD LC11896 05 years FairEvaporative Cooler #2 Champion 14/21 DD LC11877 05 years FairEvaporative Cooler #3 Champion 14/21 DD LC11875 05 years FairEvaporative Cooler #4 Champion 14/21 DD LC11874 05 years FairChiller Room Exhaust Fans 15 years FairEngine Room Exhaust Fans 10 years FairLeak Detector 04 years FairAir Compressor "A" Quincy 5065819 10 years Good new heads 2010Air Compressor "B" Quincy 5135101 10 years Good new heads 2010

EXHIBIT IVPAGE 1 OFEXHIBIT IVPAGE 1 OF 5


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Exhibit III

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022SAMPLE SERVICE LEVELS - Major Overhauls must me performed over December Holiday Break - No planed maintenance during summer On and Semi Peak

Inspect Air Cleaner Filter Element Daily Daily Daily Daily Daily Daily Daily Daily Daily Daily

Inspect Pre-Air Filter Element Daily Daily Daily Daily Daily Daily Daily Daily Daily Daily

Inspect Throttle Control Rod Ends & Linkage Daily Daily Daily Daily Daily Daily Daily Daily Daily Daily

Inspect Auxiliary & Jacket Water Coolant Level Daily Daily Daily Daily Daily Daily Daily Daily Daily Daily

Inspect Crank Case Oil Level Daily Daily Daily Daily Daily Daily Daily Daily Daily Daily

Operate All Vents & Drains Daily Daily Daily Daily Daily Daily Daily Daily Daily Daily

Engine Oil Analysis Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Check and Replace O2 Sensors Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Engine Emissions Testing Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Fill Battery Electrlytes Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Check Belt Tensions Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Lubricate All Pumps & Bearings Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Clean & Lubricate Control Linkage Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Monthly Engine Maintenance Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Change Engine Oil Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Inspect & Fill Oil Head Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Change Engine Oil Filters & O-Rings Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Clean & Regap Spark Plugs Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Clean & Replace Crank Case Breathers Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Check Ignition Timing Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Clean Magnetic Plugs Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Clean MicroSpin Oil Separators Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Clean Lube Oil Strainer Element Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly Bi-Monthly

Inspect Ignition System Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Adjust Carburetor Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Check & Adjust Crank Case Vacuum Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Check & Adjust 99 Regulators Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Check & Adjust "Big Joe" Regulator Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Test Engine Shutdowns & Alarms Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Check & Adjust Valve Lash Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Replace Spark Plugs Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Inspect Wastegate Vent Plugs Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Clean or Replace Admission Valve Assembly Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Inspect and Clean Engine Catalysts Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Check & Record Cylinder Compression Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Clean 99 Regulator Filter Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Inspect Water Pump Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Inspect & Clean Carburetor Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Replace Pre-Air Filters Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

AQMD Source Testing Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Inspect Turbochargers Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Inspect Main & Rod Bearings Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Flush Auxiliary and Jacket Water Coolant Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Test Coolant Thermostates Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Clean Crank Case Oil Pickup Screen Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

SAMPLE SERVICE LEVELS - Major Overhauls must me performed over December Holiday Break - No planed maintenance during summer On and Semi Peak

SHADED AREA IS FOR FUTURE RFP

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Exhibit III

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022SAMPLE SERVICE LEVELS - Major Overhauls must me performed over December Holiday Break - No planed maintenance during summer On and Semi PeakSAMPLE SERVICE LEVELS - Major Overhauls must me performed over December Holiday Break - No planed maintenance during summer On and Semi Peak


Clean Auxiliary and Jacket Water Radiators Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Check Engine Mounting & Alignment Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Check Exhaust Back Pressure Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Test Natural Gas Relief Valve Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Inspect Generator High Voltage System Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Inspect and replace oil & Coolant Hoses Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Clean & Inspect MAG & HAL Pickups Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Clean Oil Pan Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Inspect Damper Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Jacket & Aux Water Analysis Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Clean & Inspect Intercooler Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Inspect & Rebuild Carburetors Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Replace Belts Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Inspect Ignition System Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Rebuild Wastegates Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Test and Inspect Detonation Sensing Module Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Test and Inspect Air Fuel Controller Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Top End Overhaul Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Bottom End Overhaul Every 4 Years Every 4 Years Every 4 Years

Chiller MaintenanceInspect Chemical Controllers Daily Daily Daily Daily Daily Daily Daily Daily Daily Daily

Add Bromicide to Condenser Water Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly

Add Biocide to Evaporators Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly

Cycle 600 & 1000 Ton Chillers Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly

Monthly Plant Analysis Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Inspect & Top Off Chemical Levels Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Inspect & Clean Condenser Water Towers Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Clean & Change Chill Water Filters Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Inspect, Repack and Rebuild All Pumps Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Comprehensive Chiller Maintenance Plan Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Comprehensive Eddy Current Cost ( Condenser) Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Comprehensive Eddy Current Cost (Evaporator) Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

600 Ton ChillerAnnually on 600 Ton Chiller Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Tube Brushing on 600 Ton Chiller Condenser Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Tube Brushing on 600 Ton Chiller Evaporator Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Eddy Current Test on 600 Ton Condenser Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Eddy Current Test on 600 Ton Evaporator Every 4 Years Every 4 Years Every 4 Years

1000 Ton ChillerAnnually on 1000 Ton Chiller Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Tube Brushing on 1000 Ton Chiller Condenser Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

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Exhibit III

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022SAMPLE SERVICE LEVELS - Major Overhauls must me performed over December Holiday Break - No planed maintenance during summer On and Semi PeakSAMPLE SERVICE LEVELS - Major Overhauls must me performed over December Holiday Break - No planed maintenance during summer On and Semi Peak


Tube Brushing on 1000 Ton Chiller Evaporator Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Eddy Current Test on 1000 Ton Condenser Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Eddy Current Test on 1000 Ton Evaporator Every 4 Years Every 4 Years Every 4 Years

Absorption ChillerPurge Absorption Chiller Twice Weekly Twice Weekly Twice Weekly Twice Weekly Twice Weekly Twice Weekly Twice Weekly Twice Weekly Twice Weekly Twice Weekly

Blow Down Absorption Chiller Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly

Solution Samples from Absorption Chiller Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Comprehensive inspection on Absorption Chiller Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Annually on Absorption Chiller Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Tube Brushing on Absorption Chiller Condenser Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Tube Brushing on Absorption Chiller Evaporator Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Eddy Current Test on Absorption Condenser Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Eddy Current Test on Absorption Evaporator Every Other Year Every Other Year Every Other Year Every Other Year Every Other Year

Tube Brushing on Absorption Chiller Generator Every 4 Years Every 4 Years Every 4 Years

Eddy Current Test on Absorption Generator Every 4 Years Every 4 Years Every 4 Years

Plant MaintenanceInspect Swamp Coolers & Replace Belts & Pads Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Inspect Exhaust Fans & Replace Belts Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Inspect & Rebuild All Pumps Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly Quarterly

Boiler Cleaning & Inspection Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Analyzer Maintenance Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months Every 6 Months

Replace Chiller Room Filters Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Test & Inspect Chiller Leak Detector Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Boiler Source Testing Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Switchgear Inspection & Cleaning Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

SDG&E Switchgear Inspection & Cleaning Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Operator Salary Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

2nd Operator Salary Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Day to Day Supplies Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

InsuranceReplace Switchgear 24 Volt Batteries Every 4 Years Every 4 Years Every 4 Years

Replace Swamp Coolers Every 5 Years Every 5 Years

Meeting attendance and ReportsAttend Supervisors Meetings Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly Weekly

Prepare Affidavit Report Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly

Engine Run Time Log Dailey Dailey Dailey Dailey Dailey Dailey Dailey Dailey Dailey Dailey

Boiler Run Time Log Dailey Dailey Dailey Dailey Dailey Dailey Dailey Dailey Dailey Dailey

Prepare Annually 1304 Report Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

Prepare Annually Efficiency Report Annually Annually Annually Annually Annually Annually Annually Annually Annually Annually

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EXHIBIT II WINTER 2012 BILLING

Revised Cal. P.U.C. Sheet No. 20504-E

San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 20258-E

SCHEDULE AL-TOU Sheet 1 GENERAL SERVICE - TIME METERED

(Continued) 1C20 Issued by Date Filed Mar 28, 2008 Advice Ltr. No. 1978-E Lee Schavrien Effective May 1, 2008 Senior Vice President Decision No. 08-02-034 Regulatory Affairs Resolution No.

APPLICABILITY Applicable to all metered non-residential customers whose monthly maximum demand equals, exceeds, or is expected to equal or exceed 20 kW. This schedule is not applicable to residential customers, except for those three-phase residential customers taking service on this schedule as of April 12, 2007 who may remain on this schedule while service continues in their name at the same service address. Those three-phase residential customers remaining on this schedule who choose to switch to a residential rate schedule may not return to this schedule. This schedule is optionally available to common use and metered non-residential customers whose Monthly Maximum Demand is less than 20 kW. Any customer whose Maximum Monthly Demand has fallen below 20 kW for three consecutive months may, at their option, elect to continue service under this schedule or be served under any other applicable schedule. This schedule is the utility's standard tariff for commercial and industrial customers with a Monthly Maximum Demand equaling or exceeding 20 kW. Non-profit group living facilities taking service under this schedule may be eligible for a 20% California Alternate Rates for Energy (CARE) discount on their bill, if such facilities qualify to receive service under the terms and conditions of Schedule E-CARE. Agricultural Employee Housing Facilities, as defined in Schedule E-CARE, may qualify for a 20% CARE discount on the bill if all eligibility criteria set forth in Form 142-4032 or Form 142-4035 is met. TERRITORY Within the entire territory served by the Utility. RATES

Description – AL-TOU Transm Distr PPP ND CTC RS TRAC UDC Total Basic Service Fees

($/month) 0-500 kW

Secondary $58.22 I $58.22 I Primary 58.22 I 58.22 I Secondary Substation 16,630.12 I 16,630.12 I Primary Substation 16,630.12 I 16,630.12 I Transmission 84.67 I 84.67 I

> 500 kW Secondary 232.87 I 232.87 I Primary 232.87 I 232.87 I Secondary Substation 16,630.12 I 16,630.12 I Primary Substation 16,630.12 I 16,630.12 I Transmission 338.77 I 338.77 I

> 12 MW Secondary Substation 26,185.08 I 26,185.08 I Primary Substation 26,185.08 I 26,185.08 I Trans. Multiple Bus 3,000.00 3,000.00 Distance Adjust. Fee Secondary - OH 1.23 1.23 Secondary - UG 3.17 3.17 Primary - OH 1.22 1.22 Primary - UG 3.13 3.13

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(Continued) 2C10 Issued by Date Filed Aug 30, 2012 Advice Ltr. No. 2396-E Lee Schavrien Effective Sep 1, 2012 Senior Vice President Decision No. 12-08-007 Regulatory Affairs Resolution No.

RATES (Continued)

Description – AL-TOU Transm Distr PPP ND CTC RS TRAC UDC Total Demand Charges ($/kW)

Non-Coincident Secondary 9.27 I 7.67 (0.09) 16.85 I Primary 8.96 I 7.55 (0.08) 16.43 I Secondary Substation 9.27 I (0.09) 9.18 I Primary Substation 8.96 I (0.08) 8.88 I Transmission 8.87 I (0.08) 8.79 I

Maximum On-Peak Summer

Secondary 2.02 I 5.02 1.07 R 8.11 I Primary 1.96 I 5.43 1.02 R 8.41 I Secondary Substation 2.02 I 0.82 1.07 R 3.91 I Primary Substation 1.96 I 0.20 0.50 R 2.66 I Transmission 1.94 I 0.15 0.50 R 2.59 I

Winter Secondary 0.44 I 4.28 0.15 R 4.87 I Primary 0.42 I 4.35 0.15 R 4.92 I Secondary Substation 0.44 I 0.12 0.15 R 0.71 I Primary Substation 0.42 I 0.04 0.10 R 0.56 I Transmission 0.42 I 0.03 0.10 R 0.55 I

Power Factor ($/kvar) Secondary 0.25 0.25 Primary 0.25 0.25 Secondary Substation 0.25 0.25 Primary Substation 0.25 0.25 Transmission

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(Continued) 3C9 Issued by Date Filed Aug 30, 2012 Advice Ltr. No. 2396-E Lee Schavrien Effective Sep 1, 2012 Senior Vice President Decision No. 12-08-007 Regulatory Affairs Resolution No.

RATES (Continued)

Description – AL-TOU Transm

Distr

PPP ND CTC RS

TRAC UDC Total

Energy Charges ($/kWh) On-Peak - Summer

Secondary (0.01219) R 0.00310 0.00698 0.00044 0.00260 R 0.00000 0.00093 RPrimary (0.01219) R 0.00177 0.00698 0.00044 0.00254 R 0.00000 (0.00046) RSecondary Substation (0.01219) R 0.00140 0.00698 0.00044 0.00260 R 0.00000 (0.00077) RPrimary Substation (0.01219) R 0.00025 0.00698 0.00044 0.00245 R 0.00000 (0.00207) RTransmission (0.01219) R 0.00028 0.00698 0.00044 0.00245 R 0.00000 (0.00204) R

Semi-Peak – Summer Secondary (0.01219) R 0.00180 0.00698 0.00044 0.00152 R 0.00000 (0.00145) RPrimary (0.01219) R 0.00104 0.00698 0.00044 0.00152 R 0.00000 (0.00221) RSecondary Substation (0.01219) R 0.00082 0.00698 0.00044 0.00152 R 0.00000 (0.00243) RPrimary Substation (0.01219) R 0.00015 0.00698 0.00044 0.00142 R 0.00000 (0.00320) RTransmission (0.01219) R 0.00017 0.00698 0.00044 0.00142 R 0.00000 (0.00318) R

Off-Peak – Summer Secondary (0.01219) R 0.00143 0.00698 0.00044 0.00122 R 0.00000 (0.00212) RPrimary (0.01219) R 0.00082 0.00698 0.00044 0.00117 R 0.00000 (0.00278) RSecondary Substation (0.01219) R 0.00065 0.00698 0.00044 0.00122 R 0.00000 (0.00290) RPrimary Substation (0.01219) R 0.00012 0.00698 0.00044 0.00117 R 0.00000 (0.00348) RTransmission (0.01219) R 0.00013 0.00698 0.00044 0.00117 R 0.00000 (0.00347) R

On-Peak – Winter Secondary (0.01219) R 0.00259 0.00698 0.00044 0.00219 R 0.00000 0.00001 RPrimary (0.01219) R 0.00147 0.00698 0.00044 0.00214 R 0.00000 (0.00116) RSecondary Substation (0.01219) R 0.00117 0.00698 0.00044 0.00219 R 0.00000 (0.00141) RPrimary Substation (0.01219) R 0.00021 0.00698 0.00044 0.00204 R 0.00000 (0.00252) RTransmission (0.01219) R 0.00024 0.00698 0.00044 0.00204 R 0.00000 (0.00249) R

Semi-Peak – Winter Secondary (0.01219) R 0.00180 0.00698 0.00044 0.00152 R 0.00000 (0.00145) RPrimary (0.01219) R 0.00104 0.00698 0.00044 0.00152 R 0.00000 (0.00221) RSecondary Substation (0.01219) R 0.00082 0.00698 0.00044 0.00152 R 0.00000 (0.00243) RPrimary Substation (0.01219) R 0.00015 0.00698 0.00044 0.00142 R 0.00000 (0.00320) RTransmission (0.01219) R 0.00017 0.00698 0.00044 0.00142 R 0.00000 (0.00318) R

Off-Peak - Winter Secondary (0.01219) R 0.00143 0.00698 0.00044 0.00122 R 0.00000 (0.00212) RPrimary (0.01219) R 0.00082 0.00698 0.00044 0.00117 R 0.00000 (0.00278) RSecondary Substation (0.01219) R 0.00065 0.00698 0.00044 0.00122 R 0.00000 (0.00290) RPrimary Substation (0.01219) R 0.00012 0.00698 0.00044 0.00117 R 0.00000 (0.00348) RTransmission (0.01219) R 0.00013 0.00698 0.00044 0.00117 R 0.00000 (0.00347) R

Notes: Transmission Energy charges include the Transmission Revenue Balancing Account Adjustment (TRBAA) of $(0.00026) per kWh and the Transmission Access Charge Balancing Account Adjustment (TACBAA) of $(0.01193) per kWh. PPP rate is composed of: Low Income PPP rate (LI-PPP) $0.00357 /kWh, Non-low Income PPP rate (Non-LI-PPP) $0.00001 /kWh (pursuant to PU Code Section 399.8, the Non-LI-PPP rate may not exceed January 1, 2000 levels), and Procurement Energy Efficiency Surcharge Rate of $0.00340 /kWh.

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RATES (Continued) Rate Components The Utility Distribution Company Total Rates (UDC Total) shown above are comprised of the following components (if applicable): (1) Transmission (Trans) Charges, (2) Distribution (Distr) Charges, (3) Public Purpose Program (PPP) Charges, (4) Nuclear Decommissioning (ND) Charge, (5) Ongoing Competition Transition Charges (CTC), (6) Reliability Services (RS), and (7) Total Rate Adjustment Component (TRAC). Utility Distribution Company (UDC) Total Rate shown above excludes any applicable commodity charges associated with Schedule EECC (Electric Energy Commodity Cost) and Schedule DWR-BC (Department of Water Resources Bond Charge). Certain Direct Access customers are exempt from the TRAC, as defined in Rule 1 – Definitions. Time Periods All time periods listed are applicable to local time. The definition of time will be based upon the date service is rendered. Summer May 1 - Sept 30 Winter All Other On-Peak 11 a.m. - 6 p.m. Weekdays 5 p.m. - 8 p.m. Weekdays Semi-Peak 6 a.m. - 11 a.m. Weekdays 6 a.m. - 5 p.m. Weekdays 6 p.m. - 10 p.m. Weekdays 8 p.m. - 10 p.m. Weekdays Off-Peak 10 p.m. - 6 a.m. Weekdays 10 p.m. - 6 a.m. Weekdays Plus Weekends & Holidays Plus Weekends & Holidays The time periods shown above will begin and end one hour later for the period between the second Sunday in March and the first Sunday in April, and for the period between the last Sunday in October and the first Sunday in November. Non-Standard Seasonal Changeover Customers may select on an optional basis to start the summer billing period on the first Monday of May and to start the winter billing period on the first Monday of October. Customers electing this option will be charged an additional $100 per year for metering equipment and programming. Franchise Fee Differential A Franchise Fee Differential of 5.78% will be applied to the monthly billings calculated under this schedule for all customers within the corporate limits of the City of San Diego. Such Franchise Fee Differential shall be so indicated and added as a separate item to bills rendered to such customers.

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SPECIAL CONDITIONS 1. Definitions: The Definitions of terms used in this schedule are found either herein or in Rule 1. 2. Voltage: Service under this schedule normally will be supplied at a standard available Voltage in

accordance with Rule 2. 3. Voltage Regulators: Voltage Regulators, if required by the customer, shall be furnished, installed,

owned, and maintained by the customer. 4. Reconnection Charge: Any customer resuming service within twelve months after such service was

discontinued will be required to pay all charges which would have been billed if service had not been discontinued.

5. Non-Coincident Demand Charge: The Non-Coincident Demand Charge shall be based on the

higher of the Maximum Monthly Demand or 50% of the Maximum Annual Demand. 6. On-Peak Period Demand Charge: The On-Peak Period Demand Charge shall be based on the

Maximum On-Peak Period Demand. 7. Power Factor: The Power Factor rate shall apply to those customers that have a Power Factor Test

Failure and will be based on the Maximum Kilovar billing demand. Those customers that have a Power Factor Test Failure will be required to pay for the Power Factor Metering that the utility will install.

8. Parallel Generation Limitation. This schedule is not applicable to standby, auxiliary service or

service operated in parallel with a customer's generating plant, except as specified in Rule 1 under the definition of Parallel Generation Limitation.

9. Seasonal Changeover Switching Limitation. Customers who elect the nonstandard Seasonal

Changeover option of this schedule will be prohibited from switching service to the regular seasonal changeover for a 12-month period.

10. Limitation on Non-Standard Seasonal Changeover Availability. At the utility's sole option, the

optional non-standard seasonal changeover provision is available to no more than ten additional Schedule AL-TOU and Schedule A6-TOU customers annually and; service will be provided in the order in which requests are received.

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(Continued) 6C7 Issued by Date Filed Oct 8, 2009 Advice Ltr. No. 2115-E Lee Schavrien Effective Jan 1, 2010 Senior Vice President Decision No. 09-09-036 Regulatory Affairs Resolution No.

SPECIAL CONDITIONS (Continued) 11. Terms of Optional Service. A customer receiving service under this schedule may elect to change

to another applicable rate schedule, but only after receiving service on this schedule for at least 12 consecutive months. If a customer elects to discontinue service on this schedule, the customer will not be permitted to return to this schedule for a period of one year.

12. Basic Service Fee Determination. The basic service fee will be determined each month based on

the customer’s Maximum Annual Demand. 13. Transmission Multiple Bus Basic Service Fee. This fee shall apply where a customer has at their

option elected to be billed at this rate and is limited to where the customer is delivering power and taking service at one or more than one transmission service level bus even if at two or more different voltage levels, for service to a generation facility that is located on a single premise owned or operated by the customer. In such a case, the Utility shall, for the purposes of applying retail rates, combine by subtracting any generation delivered from any loads served provided, however, that for purposes of applying retail rates the difference resulting from this combining may not be less than zero. All other charges on this tariff shall also apply to the resulting combined loads.

Any customer selecting this optional billing no later than six (6) months from the first effective date

of this new rate shall, for billing purposes, have any previously incurred demand ratchet treated as a “zero” from the effective date of the change in billing forward. In addition, any standby charges shall be adjusted to the customer’s contract level from the effective date of the change in billing forward until the customer’s demand triggers a future change.

14. Billing. A customer’s bill is first calculated according to the total rates and conditions listed above.

The following adjustments are made depending on the option applicable to the customer:

a. UDC Bundled Service Customers receive supply and delivery services solely from the Utility. The customer’s bill is based on the Total Rates set forth above. The EECC component is determined by multiplying the EECC price for this schedule during the last month by the customer’s total usage.

b. Direct Access (DA) and Community Choice Aggregation (CCA) Customers purchase

energy from a non-utility provider and continue to receive delivery services from the Utility. The bills for a DA and CCA Customer will be calculated as if they were a UDC Bundled Service Customer, then crediting the bill by the amount of the EECC component, as determined for a UDC Bundled Customer, and including the appropriate Cost Responsibility Surcharge (CRS) if applicable.

Nothing in this service schedule prohibits a marketer or broker from negotiating with customers the

method by which their customer will pay the CTC charge. 15. Temporary Service. When service is turned on for cleaning and/or showing of an unoccupied

premise above 20 kW facility, the minimal usage shall be billed under Schedule A, until a new tenant begins service. Should usage exceed 20kW at any time for cleaning and/or showing, the customer shall be billed the rates on this schedule.

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7C5 Issued by Date Filed Apr 19, 2010 Advice Ltr. No. 2165-E Lee Schavrien Effective May 19, 2010 Senior Vice President Decision No. Regulatory Affairs Resolution No.

SPECIAL CONDITIONS (Continued) 16. Multiple Meters on Single Premise. When a single corporate entity owns a contiguous property, not

divided by any public right of way or property owned by another entity, all within the same governmental agency’s jurisdiction, and the Utility has more than one meter serving that property, then, at the customer’s request the Utility will for the additional fees and conditions set forth in this Special Condition bill all of the usage at some, or all, of the meters as though the whole premise were served through a single meter. As of September 21, 2004, for new customers to be eligible for combined billing, all meters must have the same billing components. These components include but are not limited to Large Customer CTC Adjustment, Large Customer Commodity Credit, Direct Access (DA) Cost Responsibility Surcharge, DA Utility Service Credit, DA Energy Charge and DA Franchise Fee Surcharge. Meter data will be combined for the purpose of billing UDC charges, as listed in the Rates Section of this tariff, but meter data is not allowed to be combined for the purpose of off setting any charges on SDG&E’s commodity rate schedules.. The customer must pay for the utility to install and maintain meters to record consumption in 15 minute intervals for all involved meters. The customer must also pay a distance adjustment fee determined by the utility that is based on the distance between each of the meters involved using normal utility position to determine that distance. The rate applied will be the Distance Adjustment Fee from the Rate Section of this tariff multiplied by 0.121.

17. Electric Emergency Load Curtailment Plan: As set forth in CPUC Decision 01-04-006, all

transmission level customers except essential use customers, OBMC participants, net suppliers to the electrical grid, or others exempt by the Commission, are to be included in rotating outages in the event of an emergency. A transmission level customer who refuses or fails to drop load shall be added to the next curtailment block so that the customer does not escape curtailment. If the transmission level customer fails to cooperate and drop load at SDG&E’s request, automatic equipment controlled by SDG&E will be installed at the customer’s expense per Electric Rule 2. A transmission level customer who refuses to drop load before installation of the equipment shall be subject to a penalty of $6/kWh for all load requested to be curtailed that is not curtailed. The $6/kWh penalty shall not apply if the customer’s generation suffers a verified, forced outage and during times of scheduled maintenance. The scheduled maintenance must be approved by both the ISO and SDG&E, but approval may not be unreasonably withheld.

18. Other Applicable Tariffs: Rules 21, 23 and Schedule E-Depart apply to customers with generators. 19. Generator Operation: The operation of a non-utility generator unless expressly authorized by tariff is

prohibited.

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A ~ Sempra Energy utility

GENERATING FACILITY INTERCONNECTION AGREEMENT (INADVERTENT EXPORT)

This Generating Facility Interconnection Agreement ("Agreement") is entered into by and between South Orange County Community College District (Producer'), and San Diego Gas & Electric Company ("SDG&E'), a California Corporation. Producer and SDG&E are sometimes also referred to in this Agreement jointly as "Parties" or individually as "Party." In consideration of the mutual promises and obligations stated in this Agreement and its attachments, the Parties agree as follows:

1. SCOPE, PURPOSE, AND RELATED AGREEMENT

1.1 This Agreement provides for Producer to interconnect and operate a Generating Facility in parallel with SDG&E's Distribution System to serve the electrical loads at the location identified in Section 2.4. To facilitate the operation of the Generating Facility, this Agreement also allows for the occasional and inadvertent export of power to SDG&E's Distribution System, as specifically agreed to herein. This Agreement does not constitute an agreement by SDG&E to provide retail electrical service to Producer. Such arrangements must be made separately between SDG&E and Producer.

2. SUMMARY AND DESCRIPTION OF PRODUCER'S GENERATING FACILITY

2.1 A description of the Generating Facility, including a summary of its significant components and a single-line diagram showing the general arrangement of how Producer's Generating Facility and loads are interconnected with SDG&E's Distribution System, are attached as Appendix A to and made a part of this Agreement.

2.2 Generating Facility identification number: 5035 (Assigned by SDG&E).

2.3 SDG&E's customer electric service account number: 1119562454 (Assigned by SDG&E).

2.4 Name and address used by SDG&E to locate the electric service account(s) used to interconnect the Generating Facility with SDG&E's Distribution System:

Saddleback Community College District 28000 Marguerite Pkwy. Mission Viejo, CA 92692

2.5 The Gross Nameplate Rating of the Generating Facility is 1500 kW.

2.6 The Net Nameplate Rating of the Generating Facility is 1320 kW.

2.7 The annual energy production of the Generating Facility is expected to be 8,238,000 kWh.

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2.8 The maximum (instantaneous) and inadvertent level of power that may be exported by the Generating Facility to SDG&E's Distribution System is 300 kW.

2.9 The Generating Facility's expected date of Initial Operation is June 1, 2003. The expected date of Initial Operation shall be within two years of the date of this Agreement.

2.10 For the purpose of securing certain tariff charge exemptions available under the California Public Utilities Code ("PU Code"), Producer hereby declares that the Generating Facility:

(a) xx: does / 0 does not meet the requirements for "Cogeneration" as such term is used in Section 218.5 of the PU Code.

(b) 0 does / 0 does not meet the requirements for "Distributed Energy Resource Generation" as such term is used in Section 353.1 ofthe PU Code.

3. DOCUMENTS INCLUDED

This Agreement includes the following exhibits, which are specifically incorporated herein and made a part of this Agreement.

Appendix A - Description of Generating Facility and Single-Line Diagram (Supplied by Producer)

Appendix B - A copy of an agreement addressing interconnection facility finanCing and ownership (When applicable)

Appendix C - Producer's warranty that the Generating Facility meets the requirements for a "Cogeneration facility" pursuant to Section 218.5 of the Public Utilities Code (When applicable)

Appendix D - Producer's warranty that the Generating Facility meets the requirements for "Distributed Energy Resources Generation" as defined in Section 353.1 of the Public Utilities Code (When applicable)

Appendix E - Specific Conditions and Limitations for Inadvertent Deliveries (Supplied by Producer)

4. TERM AND TERMINATION

4.1 This Agreement shall become effective as of the last date entered in Section 16 of this Agreement. The Agreement shall continue in full force and effect until the earliest date that one of the following events occurs:

(a) The Parties agree in writing to terminate the Agreement, or

(b) Unless otherwise agreed in writing by the Parties, at 12:01 A.M. on the day following the date the electric service account through which Producer's Generating Facility is Interconnected to SDG&E's Distribution System is closed or terminated, or

(c) At 12:01 A.M. on the 61 51 day after Producer or SDG&E provides written Notice pursuant to Section 9 of this Agreement to the other Party of Producer or SDG&E's intent to terminate this Agreement.

4.2 Producer may elect to terminate this Agreement pursuant to the terms of Section 4.1 (c) for any reason. SDG&E may elect to terminate this Agreement pursuant to the terms of Section 4.1 (c) for one or more of the following reasons:

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(a) A change in applicable tariffs as approved or directed by the Commission or a change in any local, state or federal law, statute or regulation, either of which materially alters or otherwise affects SDG&E's ability or obligation to perfonn SDG&E's duties under this Agreement; or,

(b) Unless otherwise agreed in writing by the Parties, Producer fails to take all corrective actions specified in SDG&E's Notice that Producer's Generating Facility is out of compliance with the tenns of this Agreement within the time frame set forth in such Notice; or,

(c) Producer fails to interconnect and operate the Generating Facility per the tenns of this Agreement prior to 120 days after the date set forth in Section 2.7 of this Agreement as the Generating Facility's expected date of Initial Operation; or,

(d) Producer abandons the Generating Facility. SDG&E shall deem the Generating Facility to be abandoned if SDG&E detennines, in its sole opinion, the Generating Facility is non-operational and Producer does not provide a substantive response to SDG&E's Notice of its intent to tenninate this Agreement as a result of Producer's apparent abandonment of the Generating Facility affinning Producer's intent and ability to continue to operate the Generating Facility.

4.3 Notwithstanding any other provisions of this Agreement, SDG&E shall have the right to unilaterally file with the Commission, pursuant to the Commission's rules and regulations, an application to tenninate this Agreement.

4.4 Any agreements attached to and incorporated into this Agreement shall tenninate concurrently with this Agreement unless the Parties have agreed otherwise in writing.

5. GENERA liNG FACILITY OPERA liON

5.1 Producer is responsible for operating the Generating Facility in compliance with all of SDG&E's tariffs, including but not limited to SDG&E's Rule 21, and any other regulations and laws governing the Interconnection of the Generating Facility.

5.2 The electric power produced by Producer's Generating FaCility shall be used to serve electrical loads connected to the electric service account that SDG&E uses to interconnect Producer's Generating Facility. Producer shall not use the Generating Facility to serve electrical loads that will cause Producer to be considered an "electrical corporation" as such tenn is used in Section 218 of the California Public Utilities Code.

5.3 If, notwithstanding Producer's efforts to regulate the electrical output of the Generating Facility, electric power flows from the Generating Facility to SDG&E's Distribution System, SDG&E shall attempt in good faith to receive such power. In no event shall the delivery of electric power to SDG&E's Distribution System exceed the amounts, duration, frequency of occurrence, or other limitations speCified in Appendix E, hereto. If Producer does not regulate its Generating Facility in compliance with the limitations set forth in Appendix E, SDG&E may require Producer to disconnect its Generating Facility from SDG&E's Distribution System until Producer demonstrates to SDG&E's sole satisfaction that Producer has taken adequate measures to regulate the output of its Generating Facility and control its deliveries of power to SDG&E. Further, should SDG&E detennine that Producer's operation of the Generating Facility is causing an unsafe condition or is adversely affecting SDG&E's ability to utilize its Distribution System in any manner, even if Producer's deliveries of electric power to SDG&E's Distribution System are within the limitations specified in Appendix E, SDG&E may require Producer to temporarily or permanently reduce or cease deliveries of electric power to SDG&E's Distribution System. Alternatively, the Parties may agree to other corrective measures so as to mitigate the effect of electric power flowing from the Generating Facility to SDG&E's Distribution System. Producer's failure to comply with the tenns of this Section shall

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constitute a material breach of this Agreement and SDG&E may initiate termination in accordance with the terms of Section 4.2(b).

5.4 SDG&E's agreement to accept electric power from Producer's Generating Facility is solely an accommodation. This Agreement does not provide for, or otherwise obligate SDG&E to measure, purchase, transmit, distribute, or store the electrical power delivered to SDG&E's Distribution System by Producer.

5.5 Producer shall not deliver reactive power to SDG&E's Distribution System unless the Parties have agreed otherwise in writing.

5.6 The Generating Facility shall be operated with all of Producer's Protective Functions in service whenever the Generating Facility is operated in parallel with SDG&E's Distribution System. Any deviation from these requirements may occur only when the Parties have agreed to such deviations in writing.

6. INTERCONNECTION FACILITIES

6.1 Producer and/or SDG&E, as appropriate, shall provide Interconnection Facilities that adequately protect SDG&E's Distribution System, personnel, and other persons from damage or injury which may be caused by the operation of Producer's Generating Facility.

6.2 Producer shall be solely responsible for the costs, deSign, purchase, construction, operation, and maintenance of the Interconnection Facilities that Producer owns.

6.3 If the provisions of SDG&E's Rule 21, or any other tariff approved by the Commission, require SDG&E to own and operate a portion of the Interconnection Facilities, Producer and SDG&E shall promptly execute an agreement that establishes and allocates responsibility for the deSign, installation, operation, maintenance, and ownership of the Interconnection Facilities. This agreement shall be attached to and made a part of this Agreement as Appendix B.

7. LIMITATION OF LIABILITY

Each Party's liability to the other Party for any loss, cost, claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from any act or omission in its performance of this agreement, shall be limited to the amount of direct damage actually incurred. In no event shall either Party be liable to the other Party for any indirect, special, consequential, or punitive damages of any kind whatsoever.

8. INSURANCE

8.1 In connection with Producer's performance of its duties and obligations under this Agreement, Producer shall maintain, during the term of this Agreement, general liability insurance with a combined single limit of not less than:

(a) Two million dollars ($2,000,000) for each occurrence ifthe Gross Nameplate Rating of Producer's Generating Facility is greater than one hundred (100) kW;

(b) One million dollars ($1,000,000) for each occurrence ifthe Gross Nameplate Rating of Producer's Generating Facility is greater than twenty (20) kWand less than or equal to one hundred (100) kW; and

(c) Five hundred thousand dollars ($500,000) for each occurrence if the Gross Nameplate Rating of Producer's Generating Facility is twenty (20) kW or less.

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(d) Two hundred thousand dollars ($200,000) for each occurrence if the Gross Nameplate Rating of Producer's Generating Facility is ten (10) kW or less and Producer's Generating Facility is connected to an account receiving residential service from SDG&E.

Such general liability insurance shall include coverage for "Premises-Operations, Owners and Contractors Protective, Products/Completed Operations Hazard, Explosion, Collapse, Underground, Contractual Liability, and Broad Form Property Damage including Completed Operations."

8.2 The general liability insurance required in Section 8.1 shall, by endorsement to the policy or policies, (a) include SDG&E as an additional insured; (b) contain a severability of interest clause or cross-liability clause; (c) provide that SDG&E shall not by reason of its inclusion as an additional insured incur liability to the insurance carrier for payment of premium for such insurance; and (d) provide for thirty (30) calendar days' written notice to SDG&E prior to cancellation, termination, alteration, or material change of such insurance.

8.3 If Producer's Generating Facility is connected to an account receiving residential service from SDG&E and the requirement of Section 8.2(a) prevents Producer from obtaining the insurance required in Section 8.1, then upon Producer's written Notice to SDG&E in accordance with Section 9.1, the requirements of Section 8.2(a) shall be waived.

8.4 Evidence of the insurance required in Section 8.2 shall state that coverage provided is primary and is not in excess to or contributing with any insurance or self-insurance maintained by SDG&E.

8.5 Producer agrees to furnish the required certificates and endorsements to SDG&E prior to Initial Operation. SDG&E shall have the right to inspect or obtain a copy of the original policy or policies of insurance.

8.6 If Producer is self-insured with an established record of self-insurance, Producer may comply with the following in lieu of Sections 8.1 through 8.4:

(a) Producer shall provide to SDG&E, at least thirty (30) calendar days prior to the date of Initial Operation, evidence of an acceptable plan to self-insure to a level of coverage equivalent to that required under Section 8.1.

(b) If Producer ceases to self-insure to the level required hereunder, or if Producer is unable to provide continuing evidence of Producer's ability to self-insure, Producer agrees to immediately obtain the coverage required under Section 8.1.

8.7 All insurance certificates, statements of self insurance, endorsements, cancellations, terminations, alterations, and material changes of such insurance shall be issued and submitted to the following:

9. NOTICES

San Diego Gas & Electric Company Attention: Electric & Gas Procurement

8315 Century Park Court, Suite 21 D San Diego, CA 92123-1593

9.1 Any written notice, demand, or request required or authorized in connection with this Agreement ("Notice'') shall be deemed properly given if delivered in person or sent by first class mail, postage prepaid, to the person specified below:

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If to SDG&E: San Diego Gas & Electric Company Attention: Electric & Gas Procurement 8315 Century Park Court, Suite 21D San Diego, CA 92123-1593

Phone: (619) 696 - 2000 Fax: (858) 650 - 6190

If to Producer: Saddleback College Community College District Attention: John Ozurovich, Director of Facilities & Maintenance Address: 28000 Marguerite Parkway City: Mission Viejo, CA 92692 Phone: (949) 582-4880 FAX: (949) 364-9461

9.2 A Party may change its address for Notices at any time by providing the other Party Notice of the change in accordance with Section 9.1.

9.3 The Parties may also designate operating representatives to conduct the daily communications, which may be necessary or convenient for the administration of this Agreement. Such designations, including names, addresses, and phone numbers may be communicated or revised by one Party's Notice to the other.

10. REVIEW OF RECORDS AND DATA

10.1 SDG&E shall have the right to review and obtain copies of Producer's operations and maintenance records, logs, or other information such as, unit availability, maintenance outages, circuit breaker operation requiring manual reset, relay targets and unusual events pertaining to Producer's Generating Facility or its Interconnection with SDG&E's Distribution System.

10.2 Producer authorizes SDG&E to release to the California Energy Commission ("CEC") and/or the California Public utilities Commission ("Commission") information regarding the Generating Facility, including the Producer's name and location, and the size, location and operational characteristics of the generating facility, as requested from time to time pursuant to the CEC's or Commission's rules and regulations.

11. ASSIGNMENT

Producer shall not voluntarily assign its rights nor delegate its duties under this Agreement without SDG&E's written consent. Any assignment or delegation Producer makes without SDG&E's written consent shall not be valid. SDG&E shall not unreasonably withhold its consent to Producer's assignment of this Agreement.

12. NON-WAIVER

None of the provisions of this Agreement shall be considered waived by a Party unless such waiver is given in writing. The failure of a Party to insist in anyone or more instances upon strict performance of any of the provisions of this Agreement or to take advantage of any of its rights hereunder shall not be construed as a waiver of any such provisions or the relinquishment of any such rights for the future, but the same shall continue and remain in full force and effect.

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13. GOVERNING LAW, JURISDICTION OF COMMISSION, INCLUSION OF SDG&E's TARIFF SCHEDULES, DEFINED TERMS

13.1 This Agreement shall be interpreted, governed, and construed under the laws of the State of California as if executed and to be performed wholly within the State of California without giving effect to choice of law provisions that might apply to the law of a different jurisdiction.

13.2 This Agreement shall, at all times, be subject to such changes or modifications by the Commission as it may from time to time direct in the exercise of its jurisdiction.

13.3 The interconnection and services provided under this Agreement shall at all times be subject to the terms and conditions set forth in the tariffs applicable to the electric service provided by SDG&E. Copies of such tariffs are available at SDG&E's Internet site: www.sdge.com or by request to SDG&E and are incorporated into this Agreement by this reference.

13.4 Notwithstanding any other provisions of this Agreement, SDG&E shall have the right to unilaterally file with the Commission, pursuant to the Commission's rules and regulations, an application for change in tariffs, rates, charges, classification, service, or any agreement relating thereto.

13.5 When initially capitalized, whether in the singular or in the plural, the terms used herein shall have the meanings assigned to them either in this Agreement or in SDG&E's Rule 1 or Rule 21, Section H. If any term is defined in both Rule 1 and Rule 21, the definition in Rule 21 shall prevail.

14. AMENDMENTS AND MODIFICATION

This Agreement can only be amended or modified by a written agreement signed by both Parties. SDG&E shall determine in its sole discretion whether prior Commission approval is required for such amendments or modifications.

15. ENTIRE AGREEMENT

This Agreement, including any incorporated tariffs and rules, contains the entire agreement and understanding between the Parties, their agents, and employees as to the subject matter of this Agreement. Each Party also represents that in entering into this Agreement; it has not relied on any promise, inducement, representation, warranty, agreement or other statement not set forth in this Agreement, or in the incorporated tariffs and rules.

16. SIGNATURES

IN WITNESS WHEREOF, the Parties hereto have caused two originals of this Agreement to be executed by their duly authorized representatives. This Agreement is effective as of the last date set forth below. .

7

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PRODUCER'S NAME

By: ~ Name: ~ufo?Fch Title: Director of Facilities & Maint.

Date: ~('\....-~(o"}

SAN DIEGO GAS & ELECTRIC COMPANY

By:

Name:

Title:

Date:

1II§4f "'A~7 ~4Pk~~ec../ M&A ~ C!IPI/~;r ,..(.P~«,

Q'-/f:5-o;l

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APPENDIX A

DESCRIPTION OF GENERATING FACILITY AND SINGLE-LINE DIAGRAM

(Supplied by Producer)

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APPENDIXB (When applicable)

INTERCONNECTION FACILITIES FINANCING AND OWNERSHIP

AGREEMENT

(Provided by SDG&E)

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APPENDIXC (When applicable)

PRODUCER'S WARRANTY THAT THE GENERATING FACILITY IS A "COGENERATION FACILITY" PURSUANT TO SECTION 218.5 OF THE CALIFORNIA PUBLIC UTILITIES CODE

For the purpose of securing the Competition Transition Charge exemption available under Section 372 of the PU Code, Producer hereby declares that the Generating Facility meets the requirements for "Cogeneration" as such term is used in Section 218.5 of the PU Code ("Cogeneration Requirements") .

Producer warrants that, beginning on the date of Initial Operation and continuing throughout the term ofthis Agreement, the Generating Facility shall continue to meet the Cogeneration Requirements. If Producer becomes aware that its Generating Facility has ceased to meet the Cogeneration Requirements, Producer shall promptly provide SDG&E with Notice of such change pursuant to Section 9.1 of the Agreement. If at any time during the term of this Agreement SDG&E determines in its sole discretion that Producer's Generating Facility may no longer meet the Cogeneration Requirements, SDG&E may require Producer to provide evidence that the Generating Facility continues to meet the Cogeneration Requirements within 15 business days of SDG&E's request for such evidence. Additionally, SDG&E may periodically (typically, once per year) inspect Producer's Generating Facility and/or require documentation from Producer to monitor the Generating Facility's compliance with the Cogeneration Requirements. If SDG&E determines in its sole judgment that Producer either failed to provide evidence in a timely manner or that it provided insufficient evidence that its Generating Facility continues to meet the Cogeneration Requirements, then the Cogeneration status of the Generating Facility shall be deemed ineffective until such time as Producer again demonstrates to SDG&E's reasonable satisfaction that the Generating Facility meets the requirements for a Cogeneration facility (the "Cogeneration Status Change").

SDG&E shall revise its records and the administration of this Agreement to reflect the Cogeneration Status Change and provide Notice to Producer of the Cogeneration Status Change pursuant to Section 9.1 of this Agreement. Such Notice shall specify the effective date of the Cogeneration Status Change. This date shall be the first day of the calendar year for which SDG&E determines in its sole discretion that the Generating Facility first ceased to meet the Cogeneration Requirements. SDG&E shall invoice the Producer's electric service account through which the Generating Facility is Interconnected with SDG&E's Distribution System for Competition Transition Charges ("CTCs") that were not previously billed during the period between the effective date of the Status Change and the date of the Notice in reliance upon Producer's representations that the Generating FaCility complied with the Cogeneration Requirements and therefore was eligible for the exemption from CTCs available under Section 372 of the PU Code.

Any amounts to be paid or refunded by Producer, as may be invoiced by SDG&E pursuant to the terms of this warranty, shall be paid to SDG&E within 30 days of Producer's receipt of such invoice.

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APPENDIX D (When applicable)

PRODUCER'S WARRANTY THAT THE GENERATING FACILITY IS A "DISTRIBUTED ENERGY RESOURCES GENERATION" FACILITY PURSUANT TO SECTION 353.1 OF THE

CALIFORNIA PUBLIC UTILITIES CODE

For the purpose of securing the tariff charge exemption available under Section 353.3 of the PU Code, Producer hereby declares that the Generating Facility meets the requirements for "Distributed Energy Resources Generation" as such term is used in Section 353.1 of the PU Code ("DERG Requirements') .

Producer warrants that, beginning on the date of Initial Operation and continuing throughout the term of this Agreement, its Generating Facility shall continue to meet the DERG Requirements. If Producer becomes aware that the Generating Facility has ceased to meet the DERG Requirements, Producer shall promptly provide SDG&E with Notice of such change pursuant to Section 9.1 of the Agreement. If at any time during the term of this Agreement SDG&E determines in its sole discretion that Producer's Generating Facility may no longer meet the DERG Requirements, SDG&E may require Producer to provide evidence that the Generating Facility continues to meet the DERG Requirements within 15 business days of SDG&E's request for such evidence. Additionally, SDG&E may periodically (typically, once per year) inspect Producer's Generating Facility and/or require documentation from Producer to monitor the Generating Facility's compliance with the DERG Requirements. If SDG&E determines in its sole judgment that Producer either failed to provide evidence in a timely manner or that it provided insufficient evidence that its Generating Facility continues to meet the DERG Requirements, then the Distributed Energy Resources Generation status of the Generating Facility shall be deemed ineffective until such time as Producer again demonstrates to SDG&E's reasonable satisfaction that the Generating Facility meets the requirements for a Distributed Energy Resources Generation facility (the "DERG Status Change').

SDG&E shall revise its records and the administration of this Agreement to reflect the DERG Status Change and provide Notice to Producer of the DERG Status Change pursuant to Section 9.1 of this Agreement. Such Notice shall specify the effective date of the DERG Status Change. This date shall be the first day of the calendar year for which SDG&E determines in its sole discretion that the Generating Facility first ceased to meet the DERG Requirements. SDG&E shall invoice the Producer electric service account through which the Generating Facility is Interconnected with SDG&E's Distribution System for any tariff charges that were not previously billed during the period between the effective date of the DERG Status Change and the date of the Notice in reliance upon Producer's representations that the Generating Facility complied with the DERG Requirements and therefore was eligible for the exemption from tariff charges available under Section 353.3 of the PU Code.

Any amounts to be paid or refunded by Producer, as may be invoiced by SDG&E pursuant to the terms of this warranty, shall be paid to SDG&E within 30 days of Producer's receipt of such invoice.

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AppendixE

Specific Conditions and Limitations For Inadvertent Deliveries

Inadvertent deliveries of power from Saddleback Community College to SDGE will be limited to a maximum of300 kW by the following protection scheme:

• The primary method of control is a load following program controlling the college output to a minimum of 60 kW import power from SDGE. Under certain conditions, i.e. a large load being secured, imported power will drop below this value and in some cases will flow in the export direction.

• Limitations on the amount of power exported will be controlled as follows: o Beckwith protection relay

• Setting A will be set at 30 kW import power for 30 seconds. This will ensure that power is not exported continuously.

• Setting B will be set at 300 kW export power for 2 seconds.

o SEL 351 protection relay • Setting A will be set at 165 kW export power for 10 seconds. This

will limit the export of power during a normal transient due to a large load tripping off and will provide sufficient time for the control system to recover from such inadvertent trips.

• Setting B will be set to 300 kW export power for 2 seconds.

The maximum number of export excursions per day will be maintained below 10. The expected number of export excursions per day will be 2, during the two period when the air conditioning compressor shuts down.

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addendum no. 1 - socccd · addendum no. 1 date: may 10, 2013 ... waukesha l7042 gsi c-14437/2 10...

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