CALGreen · California Green Building Standards Code (CALGreen)
Consultation with local electric service provider and EDR/PV sizing notes
Homeowners: If your city wants to count extra rooftop solar to meet a green-building energy target, the city must first check with the power company to make sure that size of solar can be safely and legally connected — the city can’t force a solar system bigger than the utility will allow.
Last reviewed: July 6, 2026
What the code requires — 2-4 sentences
Local jurisdictions that plan to adopt reduced EDR targets based on using solar photovoltaic (PV) systems larger than the Energy Code baseline must consult with the local electric service provider to confirm the PV sizing will be acceptable to the utility. The jurisdiction shall not require onsite PV systems that are larger than the local electric service provider will allow to be interconnected. See § A4.203.1.3.
Always check with the electric service provider before adopting a PV-based EDR reduction — the jurisdiction may not mandate PV capacity the utility will not interconnect. § A4.203.1.3
Requirements in detail
Key defined terms (first mention)
- § A4.203.1.3 — the controlling clause in CALGreen for this topic.
- EDR — Hourly Source Energy Rating used by the performance approach (see § A4.203.1.1).
- PV — solar photovoltaic system (onsite generation sizing is the subject of the consultation).
- local electric service provider — the utility or entity that owns/operates the distribution system and controls interconnection rules.
What the jurisdiction must do
- Consult the local electric service provider early in the ordinance/adoption process when the proposed EDR target depends on onsite PV larger than the Energy Code baseline. § A4.203.1.3
- Confirm the specific PV sizing (kW or kW DC), interconnection limits, export/anti-islanding requirements, and any protective-device or transformer limitations that could prevent interconnection at the proposed size. CALGreen requires consultation but does not specify utility technical limits — those are utility-determined. § A4.203.1.3
- Do not require PV sizes that exceed the utility’s allowable interconnection size for the project’s service configuration; if the utility limits the size, the jurisdiction must lower its requirement accordingly. § A4.203.1.3
Decision-relevant dimensions (quick reference table)
| Decision question | Typical decision-relevant value / item | Code Reference |
|---|---|---|
| When is consultation required? | When adopting reduced EDR targets based on PV systems larger than the California Energy Code baseline | § A4.203.1.3 |
| What must be confirmed with the utility? | PV sizing for interconnection, export limits, required protective devices, distribution capacity or transformer limits, special facilities agreements | § A4.203.1.3 |
| Can a jurisdiction require PV larger than utility will allow? | No — jurisdiction shall not require onsite PV systems larger than the local electric service provider will allow to be interconnected | § A4.203.1.3 |
| Where EDR is defined / calculated? | Hourly Source Energy Rating (EDR) computed by Energy Commission–compliant software (see A4.203.1.1) | § A4.203.1.1 |
How to conduct the consultation (recommended practical steps)
- Provide the utility with the proposed PV sizing (kW DC), anticipated site export, service voltage and service-connection details. CALGreen requires consultation but leaves the method to the jurisdiction. § A4.203.1.3
- Request written confirmation of interconnection feasibility, limits, and any required system modifications (transformer upgrades, anti-islanding schemes, revenue metering changes). Utility practice (example: PG&E Greenbook) shows utilities commonly document special facilities agreements and interconnection requirements.
- If the utility will not interconnect at the proposed size without upgrades, the jurisdiction must revise its required PV sizing or identify allowable alternatives (CALGreen does not prescribe which alternatives must be used). § A4.203.1.3
Exceptions & special cases
- CALGreen itself does not list technical exceptions to the consultation requirement; it simply requires consultation and forbids mandating PV sizes the utility will not allow. § A4.203.1.3
- Utilities sometimes offer special facilities agreements or protective-device installations to accommodate larger generation; those are utility-specific solutions (example: PG&E procedures) and may require cost allocation, study, or additional infrastructure. CALGreen requires consultation but does not require utilities to provide upgrades.
- Where a utility’s interconnection rules vary by service type (single‑phase vs. three‑phase, meter location, aggregate exported energy), the consultation must reflect the actual service configuration for the proposed project. § A4.203.1.3
Common mistakes
- Assuming the Energy Code’s PV baseline equals the maximum PV a utility will interconnect — the utility may have lower limits. CALGreen requires consultation to avoid this misconception. § A4.203.1.3
- Waiting until plan check or construction to consult the utility — consultation should occur during ordinance development or project design when EDR targets are set. § A4.203.1.3
- Requiring a fixed kW PV mandate without specifying allowable alternatives or conditions if the utility refuses interconnection; CALGreen prohibits forcing PV sizes the utility won’t allow. § A4.203.1.3
- Confusing EDR target-setting (CALGreen Appendix A4 performance rules) with interconnection capacity rules — EDR is a compliance metric (see § A4.203.1.1) while interconnection is utility jurisdiction.
Worked example — concrete scenario with numbers
Scenario: A city wants to adopt a voluntary Tier that reduces a building’s required EDR by assuming an onsite PV system sized at 12 kW DC for a typical 4‑unit multifamily building.
- Designer confirms proposed service: single‑phase 200 A, rooftop PV 12 kW DC, expected export < 5 kW.
- City consults the local electric service provider per § A4.203.1.3 to determine interconnection feasibility. § A4.203.1.3
- Utility responds: the distribution transformer and service configuration limit customer‑side interconnection to 8 kW DC without equipment upgrades or a special facilities agreement. (Utility may document options and costs — see utility guidance examples.)
- Outcome: The city must not adopt a requirement that forces 12 kW DC PV; the PV sizing used to meet the reduced EDR target must be adjusted to ≤ 8 kW DC (or the city must allow an alternative compliance path). CALGreen does not specify the alternative — it only requires consultation and prohibits mandating above-allowable sizing. § A4.203.1.3
Notes: The numeric utility limit (8 kW) in this example is hypothetical; CALGreen requires consultation to get the actual utility number for the specific project and service. § A4.203.1.3
Related provisions
- § A4.203.1.1 — Hourly Source Energy Rating (EDR) calculation and software-based EDR adjustments (defines EDR used in the performance approach).
- § A4.203.1.2 — Prerequisite options and required efficiency measures that accompany the EDR performance approach.
- § A4.106.8 — EV charging readiness requirements (related electrical service planning and raceway/panel capacity considerations).
- Section 5.410.2.5 (Systems manual / Documentation and training) — Requires listing of local electrical service provider information in the Systems Manual; useful for documenting consultations and utility contacts.
Code references
Grounded in the retrieved California Green Building Standards Code (CALGreen) — click a citation to read the verbatim passage:
CALGreen § 108.1 High relevance — show source text
108.1** Items in this section are necessary to address innovative
concepts or local environmental conditions.||||||| |Item 1|
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| |Item 3||||||| |ENERGY EFFICIENCY||||||| |General||||||| |4.201.1 Building meets or exceeds the requirements of the_California_
_Building Energy Efficiency Standards_3.||2|2|||| |Performance Approach for Newly
Constructed Buildings||||||| |**A4.203.1.1 Hourly Source Energy Rating (EDR1).**EDR1 ratings for
building design shall be computed by Energy Compliant software and
shall reduce the EDR1 required by the software by the compliance
margins specified in Table A4.203.1.1.||2|2|||| |**A4.203.1.2 Prerequisite options.In addition, a minimum of two of
the efficiency measures specified in Sections A4.203.1.2.1 through
A4.203.1.2.8 will be required to be met.
· Roof Deck Insulation or Ducts in Conditioned Space.
· High-performance Walls.
· Compact Hot Water Distribution System.
· Drain Water Heat Recovery.
· High Performance Vertical Fenestration.
· Heat Pump Water Heater Demand Management.
· Battery Storage System Controls.
· **Heat Pump Space and Water Heating.||2|2|||| |**A4.203.1.3 Consultation with local electric service provider.**Local
jurisdictions considering adoption of reduced EDR targets based on
using solar photovoltaic (PV) systems larger than required by the
California Energy Code shall consult with the local electric service
provider to ensure that that PV system sizing required to comply with
the EDR targets will be acceptable to the local electric service
provider.||2|2||||2025 CALIFORNIA GREEN BUILDING STANDARDS CODE APPENDIX A4-25
on Jul 18, 2025 11:14 AM (CDT) THEREUNDER.
APPENDIX A4 — RESIDENTIAL VOLUNTARY MEASURES
SECTION A4.602—RESIDENTIAL OCCUPANCIES APPLICATION CHECKLIST—continued
CALGreen § 203.1.2.3 High relevance — show source text
A4.203.1.2.3 Compact hot water distribution system. Meet the requirements for installation of Compact Hot Water Distribution Systems specified in the Title 24, Part 6, Reference Appendix RA3.6.5.
A4.203.1.2.4 Drain water heat recovery. Meet the requirements for installation of Drain Water Heat Recovery specified in Title 24, Part 6, Reference Appendix RA4.4.21.
A4.203.1.2.5 High performance vertical fenestration. Meet the climate zone dependent U -factor and Solar Heat Gain Coefficient (SHGC) as rated in accordance with Title 24, Part 6, Section 110.6, and shall have a maximum U -factor of 0.21 in Climate Zones 1 − 16, maximum SHGC of 0.23 in Climate Zones 2, 4, and 6 − 14, and maximum SHGC of 0.20 in Climate Zone 15.
Exception to A4.203.1.2.5: Fenestration in Climate Zones 1, 3, 5, and 16 is not required to comply with the maximum SHGC requirements.
A4.203.1.2.6 Heat pump water heater demand management. For buildings with heat pump water heating, meet the requirements for installation of controls specified by Title 24, Part 6, Reference Appendix JA13.3.3.
A4.203.1.2.7 Battery storage system controls. For buildings with battery storage systems, meet the requirements for installation of controls specified by Title 24, Part 6, Reference Appendix JA12 for either the Time-of-Use Control or Advanced Demand Flexibility Control option.
A4.203.1.3 Consultation with local electric service provider. Local jurisdictions considering adoption of reduced LSC targets based on using solar photovoltaic (PV) systems larger than required by the California Energy Code shall consult with the local electric service provider to ensure that PV system sizing required to comply with the LSC targets will be acceptable to the local electric service provider. The local jurisdiction shall not require onsite PV systems that are larger than the local electric service provider will allow to be interconnected.
A4.203.1.4 Outdoor luminaires. Outdoor luminaires installed for new multifamily buildings, hotels, and motels shall meet the following requirements.
A4.203.1.4.1 Outdoor pole-mounted and arm-mounted luminaires shall be installed with tilting not greater than 10 degrees, or the outdoor luminaires shall be installed with arm-mount or tenon-mount capable of tilting less than or within 10 degrees.
Exceptions to Section A4.203.1.4:
- Lighting for one- and two-family dwellings and townhouses with attached private garages.
- Lighting for building facades, public monuments, public art, statues and vertical surfaces of bridges.
- Lighting not permitted by a health or life safety statute, ordinance or regulation to be a cutoff luminaire.
- Temporary outdoor lighting.
- Lighting required and regulated by the Federal Aviation Administration or the Coast Guard.
- Lighting for public streets, roadways, highways, and traffic signage lighting, including lighting for driveway entrances occurring in the public right-of-way. Luminaires that illuminate the public right of way including publicly maintained or utility-maintained sidewalks and bikeways.
- Lighting for sports and athletic fields, and children’s playgrounds.
CALGreen § 203.1.3 High relevance — show source text
A4.203.1.3 Consultation with local electric service provider. Local jurisdictions considering adoption of reduced LSC targets based on using solar photovoltaic (PV) systems larger than required by the California Energy Code shall consult with the local electric service provider to ensure that PV system sizing required to comply with the LSC targets will be acceptable to the local electric service provider. The local jurisdiction shall not require onsite PV systems that are larger than the local electric service provider will allow to be interconnected.
A4.203.1.4 Outdoor luminaires. Outdoor luminaires installed for new multifamily buildings, hotels, and motels shall meet the following requirements.
A4.203.1.4.1 Outdoor pole-mounted and arm-mounted luminaires shall be installed with tilting not greater than 10 degrees, or the outdoor luminaires shall be installed with arm-mount or tenon-mount capable of tilting less than or within 10 degrees.
Exceptions to Section A4.203.1.4:
- Lighting for one- and two-family dwellings and townhouses with attached private garages.
- Lighting for building facades, public monuments, public art, statues and vertical surfaces of bridges.
- Lighting not permitted by a health or life safety statute, ordinance or regulation to be a cutoff luminaire.
- Temporary outdoor lighting.
- Lighting required and regulated by the Federal Aviation Administration or the Coast Guard.
- Lighting for public streets, roadways, highways, and traffic signage lighting, including lighting for driveway entrances occurring in the public right-of-way. Luminaires that illuminate the public right of way including publicly maintained or utility-maintained sidewalks and bikeways.
- Lighting for sports and athletic fields, and children’s playgrounds.
- Lighting for industrial sites, including but not limited to, rail yards, maritime shipyards and docks, piers and marinas, chemical and petroleum processing plants, and aviation facilities.
- Lighting of tunnels, bridges, stairs, wheelchair elevator lifts for American with Disabilities Act (ADA) compliance, and ramps that are not parking garage ramps.
- In theme parks: outdoor lighting only for themes and special effects.
- Lighting for outdoor theatrical and other outdoor live performances, provided that these lighting systems are additions to area lighting systems and are controlled by a multi-scene or theatrical cross-fade control station accessible only to authorized operators.
- Outdoor lighting systems for qualified historical buildings, as defined in the California Historical Building Code (Title 24, Part 8), if they consist solely of historical lighting components or replicas of historical lighting components. If lighting systems for qualified historical buildings contain some historical lighting components or replicas of historical components, combined with other lighting components, only those historical or historical replica components are exempt. All other outdoor lighting systems for qualified historical buildings shall not be exempted.
APPENDIX A4-10 2025 CALIFORNIA GREEN BUILDING STANDARDS CODE
on Jul 18, 2025 11:14 AM (CDT) THEREUNDER.
APPENDIX A4 — RESIDENTIAL VOLUNTARY MEASURES
SECTION A4.204 — REQUIREMENTS FOR ALTERATIONS TO EXISTING BUILDINGS
A4.204.1 Energy efficiency. Alterations to existing residential buildings shall comply with Sections A4.204.1.1 and A4.204.1.2.
**A4.204.1.1 Altered space-conditioning system serving existing single-family dwelling units – mechanical cooling.
CALGreen § 203.1.2.1 High relevance — show source text
In addition, a minimum of two of
the efficiency measures specified in Sections A4.203.1.2.1 through
A4.203.1.2.8 will be required to be met.
· Roof Deck Insulation or Ducts in Conditioned Space.
· High-performance Walls.
· Compact Hot Water Distribution System.
· Drain Water Heat Recovery.
· High Performance Vertical Fenestration.
· Heat Pump Water Heater Demand Management.
· Battery Storage System Controls.
· **Heat Pump Space and Water Heating.||2|2|||| |**A4.203.1.3 Consultation with local electric service provider.**Local
jurisdictions considering adoption of reduced EDR targets based on
using solar photovoltaic (PV) systems larger than required by the
California Energy Code shall consult with the local electric service
provider to ensure that that PV system sizing required to comply with
the EDR targets will be acceptable to the local electric service
provider.||2|2||||2025 CALIFORNIA GREEN BUILDING STANDARDS CODE APPENDIX A4-25
on Jul 18, 2025 11:14 AM (CDT) THEREUNDER.
APPENDIX A4 — RESIDENTIAL VOLUNTARY MEASURES
SECTION A4.602—RESIDENTIAL OCCUPANCIES APPLICATION CHECKLIST—continued
FEATURE OR MEASURE LEVELS
APPLICANT TO SELECT ELECTIVE MEASURESCol3 Col4 VERIFICATIONS
ENFORCING AGENCY TO SPECIFY
VERIFICATION METHODCol6 Col7 FEATURE OR MEASURE Mandatory Prerequisites and electives1 Prerequisites and electives1 Enforcing
Agency
AllInstaller or
Designer
AllThird
party
AllFEATURE OR MEASURE Mandatory Tier 1 Tier 2 Tier 2 Tier 2 Tier 2 WATER EFFICIENCY AND CONSERVATION Indoor Water Use 4.303.1Plumbing fixtures (water closets and urinals) and fittings
(showerheads, faucets and pre-rinse spray valves) installed in
residential buildings shall comply with the prescriptive requirements
of Sections 4.303.1.1 through 4.303.1.4.5. 4.303.2 Submeters for multifamily building and dwelling units in
**mixed-use residential/commercial buildings.California Green Building Standards Code (CALGreen) Medium relevance — show source text
INPUT RATING LIMITS IN THOUSANDS OF BTU PER HOUR**| |VENT
HEIGHT
_H _
(feet)|CONNECTOR
RISE
_R _
(feet)|FAN|FAN|NAT|FAN|FAN|NAT|FAN|FAN|NAT| |VENT
HEIGHT
_H _
(feet)|CONNECTOR
RISE
_R _
(feet)|Min|Max|Max|Min|Max|Max|Min|Max|Max| |6|2
4
6|NA
NA
NA|NA
NA
NA|NA
NA
NA|NA
NA
NA|NA
NA
NA|NA
NA
NA|NA
NA
NA|NA
NA
NA|NA
NA
NA| |8|2
4
6|NA
471
478|NA
2737
3018|NA
1800
2180|NA
560
568|NA
3319
3665|NA
2180
2640|NA
662
669|NA
3957
4373|NA
2590
3130| |10|2
4
6|NA
486
494|NA
2887
3169|NA
1890
2290|NA
581
589|NA
3502
3849|NA
2280
2760|NA
686
694|NA
4175
4593|NA
2710
3270| |15|2
4
6|NA
523
533|NA
3197
3470|NA
2060
2510|NA
624
634|NA
3881
4216|NA
2490
3030|NA
734
743|NA
4631
5035|NA
2960
3600| |20|2
4
6|NA
554
567|NA
3447
3708|NA
2180
2650|NA
661
671|NA
4190
4511|NA
2630
3190|NA
772
785|NA
5005
5392|NA
3130
3790| |30|2
4
6|NA
619
632|NA
3840
4080|NA
2365
2875|NA
728
741|NA
4861
4976|NA
2860
3480|NA
847
860|NA
5606
5961|NA
3410
4150| |50|2
4CALGreen § 8.8 Medium relevance — show source text
details: see Note 8 figure.|8.8 tons|3 hrs
32
min|||7|1, 3, 14|31/2| |B-11-RC-5|11″|24″ wide × 11″ deep reinforced concrete “T”
beam (4250 psi); details: see Note 9 figure.|8.8 tons|3 hrs
3 min|||7|1, 3, 14|3| |B-11-RC-6|11″|Concrete flange: 4″ deep × 2' wide (4895 psi)
concrete; concrete beam: 7″ deep × 61/2″
wide; “I” beam reinforcement; 10″ × 41/2″ ×
25 lbs R.S.J.; 1″ cover on flanges; flange rein-
forcement:3/8″ diameter bars at 6″ pitch
parallel to “T”; 1/4″ diameter bars perpendic-
ular to “T”; beam reinforcement: 4″ × 6″ No.
13 SWG wire mesh; span: 11' restrained;
details: see Note 10 figure.|10 tons|6 hrs|||7|1, 4|6| |B-11-RC-7|11″|Concrete flange: 6″ deep × 1' 61/2″ wide (3525
psi) concrete; concrete beam: 5″ deep × 8″
wide precast concrete blocks 83/4″ long; “I”
beam reinforcement; 7″ × 4″ × 16 lbs R.S.J.;
2″ cover on bottom; 11/2″ cover on top;
flange reinforcement: two rows1/2″ diameter
rods parallel to “T”; beam reinforcement:1/8″
wire mesh perpendicular to “T”; span: 1′3″
simply supported; details: see Note 11
figure.|3.9 tons|4 hrs|||7|1, 2|4| |B-11-RC-8|11″|Concrete flange: 4″ deep × 2' wide (3525 psi)
concrete; concrete beam 7″ deep × 41/2″
wide (scaled from drawing); “I” beam rein-
forcement; 10″ × 41/2″ × 25 lbs R.S.J.; no
concrete cover on bottom; flange reinforce-
ment:3/8″ diameter bars at 6 pitch parallel to
“T”;1/4″ diameter bars perpendicular to “T”;
span: 11′ restricted; details: see Note 12
figure.|10 tons|4 hrs|||7|1, 2|4| |B-11-RC-9|111/2″|24″ wide × 111/2″ deep reinforced concrete
“T” beam (4390 psi); details: see Note 13
figure.|8.8 tons|3 hrs
24
min|||7|1, 3|31/3|For SI: 1 inch = 25.4 mm, 1 foot = 305 mm, 1 pound = 0.004448 kN, 1 pound per square inch = 0.00689 MPa, 1 ton = 8.896 kN.
Notes:
CALGreen § 11-17. Medium relevance — show source text
- Detail A, “Cable Entrance Window,” on Page 11-17.
One Cable Hanger for Each Conductor No Top Hats or Junction Boxes Allowed with Provisions to Tie the Cable to the
18” Max. from Top of Switchgear, Continuous
Moisture Barrier, Open Top and Bottom
See Note 2
No Top Hats or Jun Each Conductor the Cable to the nction Boxes A Allowed 42” Min.
See
Note 2
and
Detail A
Pull Section
See Note 3
ervice Entrance Point
tchgear, Continuous
t, No Boxes Allowed
he Cable to the
m Highest Cable
for Drip Loop
p and BottomTermination
Section
60” Min.Cable-Terminating
Facilities
60” Min.
72” Max.
Standar
Pull SeFront View (Side Entry)
Figure 11-7 Additional Side or Back Switchgear Pull Section–High Entry
2022 – 2023 11-16
Section 11, Electric Switchboards: 601 Volts Through 25,000 Volts and Primary Services
11.5. (continued)
Top Col2 24”
2
Cable Protective Insulation
Material On All Inside Edges4” Enclosure Side Wall
Detail A–Cable Entrance Window
Notes in reference to Figure 11-7.
Ensure that the height and depth of the additional pull section are exactly the same as the terminating section. The width must be a minimum of 42 inches.
The height of the cable entrance window above the top of the pad is 3 inches maximum. Ensure that the window size is a 24 inches wide by 24 inches tall. Insulate all inside edges of the window opening to prevent damage to the cables. See Detail A above..
Cables must not lie on the concrete pad or ground. The applicant must provide a cable support system to keep the cables off the ground. Otherwise, the applicant must supply cable blocks using PG&E Material Code 362118.
11-17 2022 – 2023
Section 11, Electric Switchboards: 601 Volts Through 25,000 Volts and Primary Services
This Page Intentionally Left Blank
2022 – 2023 11-18
A PPENDIX A A CRONYMS & G LOSSARY
Appendix A Acronyms and Glossary
Acronyms
A ampere, amps
ac alternating current
AHJ authority having jurisdiction
AIC amperes interrupting capacity
ANSI American National Standards Institute
AWG American wire gauge
Btu British thermal unit
CCR Code of California Regulations
CDF California Department of Forestry and Fire Protection
CGT California Gas Transmission
CL centerline
CPUC California Public Utilities Commission
CT current transformer
DA direct access
DASMMD Direct Access Standards for Metering and Meter Data
DASR direct access service request
dc direct current
DG distributed generation
DOT U.S. Department of Transportation
EFV excess flow valve
ESP energy service provider
EUSERC Electric Utilities Service Equipment Requirements Committee
G.O. General Order
GRS galvanized rigid steel
GT&D Gas Transmission and Distribution
HDD Horizontal Directional Drilling
HDPE high-density polyethylene
A−1 2022 – 2023
Appendix A: Acronyms and Glossary
CALGreen § 8-40 Medium relevance — show source text
. . . . . . . . . . . . . 8-40
APPENDIX A4 RESIDENTIAL
VOLUNTARY MEASURES. . . . . . . . . . . . . . . . . APPENDIX A4-3
A4.1 Planning and Design . . . . . . . . . . . . . . . . . APPENDIX A4-3 A4.2 Energy Efficiency . . . . . . . . . . . . . . . . . . . . APPENDIX A4-9 A4.3 Water Efficiency and Conservation . . . APPENDIX A4-13 A4.4 Material Conservation and Resource Efficiency . . . . . . . . . . . . . . . . . . . . . . . . APPENDIX A4-15 A4.5 Environmental Quality . . . . . . . . . . . . . . APPENDIX A4-19 A4.6 Tier 1 and Tier 2 . . . . . . . . . . . . . . . . . . . . APPENDIX A4-21
Division A4.6—Residential Occupancies Application Checklist . . . . . . . . . . . . . APPENDIX A4-23 A4.7 Residential Model Ordinance . . . . . . . . . APPENDIX A4-31
APPENDIX A5 NONRESIDENTIAL
VOLUNTARY MEASURES. . . . . . . . . . . . . . . . . APPENDIX A5-3
A5.1 Planning and Design . . . . . . . . . . . . . . . . . APPENDIX A5-3 A5.2 Energy Efficiency . . . . . . . . . . . . . . . . . . . APPENDIX A5-13 A5.3 Water Efficiency and Conservation . . . APPENDIX A5-19 A5.4 Material Conservation and Resource Efficiency . . . . . . . . . . . . . . . . . . . . . . . . APPENDIX A5-25 A5.5 Environmental Quality . . . . . . . . . . . . . . APPENDIX A5-35 A5.6 Voluntary Tiers . . . . . . . . . . . . . . . . . . . . . APPENDIX A5-41 A5.601 CALGren Tier 1 and Tier 2. . . . . . . . . . APPENDIX A5-41
A5.602 CALGreen Verification Guidelines Mandatory Measures Checklist . . . . . . . . . . . . . . . APPENDIX A5-44
A5.602.1 CALGreen Verification Guidelines
Tier 1 Checklist . . . . . . . . . . . . . . . . . APPENDIX A5-48
A5.602.2 CALGreen Verification Guidelines
Tier 2 Checklist . . . . . . . . . . . . . . . . . APPENDIX A5-55
APPENDIX A6 VOLUNTARY STANDARDS FOR HEALTH
CALGreen § 1.25 Medium relevance — show source text
- Because of reliability and safety reasons only flooded lead acid (calcium, antimony) and Nickel−Cadmium (NiCd) batteries are acceptable in switchgear installations.
094676 Page 10 of 16 Rev. #00: 3/25/2022
OH: Services UG: Services Primary Electric Service Requirements Greenbook
- It is required for the third party customer to provide the following documentation to PG&E for review and acceptance by the Substation Engineering Department:
A. Complete FORM AT−1, “Third Party Interconnection Battery Information Sheet and Acceptance Document” (https://www.pge.com/includes/docs/pdfs/shared/rates/tariffbook/ferc/tih/app_t.pdf), located on pages 4 thru 5 in Appendix T on the Transmission Interconnection Handbook webpage.
B. Type of Battery (Vented Lead Acid−VLA or NiCd). Monoblock (multiples cells in a jar) batteries from C & D, EnerSys or other vendors will be acceptable. Battery racks must be designed to withstand loading based on IEEE 693 (High Seismic).
C. Detail information of load including continuous and momentary. No minimum requirement− Smallest flooded acid may be the limitation.
D. Battery sizing calculation based on IEEE Standard 485−2010 (IEEE recommended Practice for Sizing Large Lead Storage Batteries for Generating Stations and Substations) or IEEE Standard 1115−2014 (IEEE recommended Practice for Sizing Nickel−Cadmium Batteries for Stationary application) and minimum 8 hours discharge rate using manufacturer software (to ensure proper discharge curve is used) using aging factor of 1.25 and design margin of 1.1 to be clearly shown on the calculation. Charger sizing calculation based on battery size with recharge time of 12 hours assuming charger will support the continuous load as well as recharges the battery at the same time.
E. When battery is installed proof of three (3) hour discharge testing to ensure battery has the capacity to support the load and trip; per IEEE Standard 450−2010 (Voltage measurements should be taken every 15 minutes throughout the testing).
F. Documentation showing what kind of maintenance will be done (Monthly, Quarterly, and Yearly etc.).
G. Monitoring of minimum battery low voltage by separate voltage relay or through charger and provide critical audible and visual alarm for the monitoring system.
Section 15 Preferred Service Arrangement Figures
The following pages provide figures showing the preferred service arrangements for overhead and underground primary services.
Rev. #00: 3/25/2022 094676 Page 11 of 16
OH: Services UG: Services Primary Electric Service Requirements Greenbook
PG&E Equipment
Notes:
PL PL
PL PL
PG&E will install a protective device under a special facilities agreement if there are extenuating circumstances that prevent the customer from installing one. This is an exception and will be handled on case−by−case basis.
PG&E will own and maintain substructures in the franchise area and the customer will own and maintain substructures on private property
California Green Building Standards Code (CALGreen) Medium relevance — show source text
Upgraded Panel
- For upgraded panels where the new specified size of service conductor will fit in the existing conduit, it is not necessary to upgrade the conduit to the currently specified size and number for the new panel if all of the following are met:
A. The maximum conduit fill ratio is not exceeded.
B. The calculated cable pulling tensions along the conduit route is within limits of the new cable.
C. Copper or larger size Aluminum cable can handle full load in existing number of conduits. See Table 1 and Table 2 below.
Table 1 Service Cabled Size Allowed in Existing Conduit When Upgrading Single Phase Panels
Existing Service
Equipment
Rating (amps)New Upgrade
Service
Equipment
Rating (amps)Minimum
Allowed Existing
Conduit Size
and NumberAluminum or Copper Cable
Required to Serve Maximum
Load AWG or kcmil1Col5 Existing Service
Equipment
Rating (amps)New Upgrade
Service
Equipment
Rating (amps)Minimum
Allowed Existing
Conduit Size
and Number(Per Phase) Neutral 100 200 1−3” 1−4/0 Al 1−1/0 Al 200 400 1−3” 1−750 Al 1−4/0 Al 400 600 1−4” 1−1000 Cu2,3 1−250 Cu 1Mixing Aluminum and Copper cable runs for the same service is not allowed. 2 Limited to 50 feet of cable between the transformer secondary spades and the customer’s gear connection point. For greater distances, an appropriately rated PG&E approved pad-mounted termination enclosure is allowed if installed per the requirements listed in the Greenbook. For either type of installation, the PG&E installed cable length must not exceed 50 feet. 3 Center conduit underneath middle hot leg to allow flexibility to terminate the conductor.063928 Page 4 of 9 Rev. #26: 03−25−22
Methods and Requirements for Installing Non-Residential Underground Electric Services 0 − 600 Volts to Customer-Owned Facilities
UG-1: Services Greenbook EDM
Table 2 Service Cable Size Allowed in Existing Conduit When Upgrading Three Phase Panels
CALGreen § 93.3 Medium relevance — show source text
Gas Design Standard J-20, “Rotary Meter Capacity – At Standard and Elevated Delivery Pressures”
Utility Standard TD-4801S, “Service Replacement Criteria”
Appendices
Appendix A, “Pressure Drop Across EFVs”
Appendix B, “Calculating Equivalent Lengths of Plastic Pipe”
Appendix C, “EFV Installation and Replacement Matrix”
Attachments
Attachment 1, "Excess Flow Valve (EFV) Calculator"
Printed copies of this document might be out of date. The Technical Information Library (TIL) has the current version.
Page 14 of 19 “PG&E” refers to Pacific Gas and Electric Company, a subsidiary of PG&E Corporation.
©2021 Pacific Gas and Electric Company. All rights reserved.
PG&E Internal Information
Excess Flow Valves A-93.3
Publication Date: 10/20/2021 Effective Date: 01/01/2022 Rev. 9c
Revision Notes
Revision 9c has the following changes:
- Updated Section 3 as follows:
a. In Step 3.6.A, deleted any mention of Honeywell Perfection EFVs (except in Step 3.6.A.4), GasBreaker, and plastic Lyall. Added “with plain ends,” “with socket ends,” and “incorporated into plastic electrofusion couplings.”
b. Added new step (Step 3.10) to refer to Appendix A.
- Completely revised Section 4, including the following:
a. Grouped plastic EFVs by connection type rather than by manufacturer.
b. Added manufacturer's part numbers to the tables.
c. Added three additional GasBreaker EFVs with plain ends.
d. Merged GasBreaker EFVs with plain ends with Honeywell Perfection EFVs with plain ends under one material code for the same size and flow series. Maximum protected length of 1¼″ IPS 2600 and 2 IPS 5000 Honeywells were reduced to align with GasBreaker.
e. Added MAXITROL as a new EFV manufacturer.
Added to Step 7.7 and Step 7.8 that adhesive stickers are not required if not supplied in the bag with the EFV.
Removed option to keep original EFV in place if or when transferring a service to a new main.
Merged cells in Appendix C (row 11, columns 3 and 4).
Added new Attachment 1 (Excel) to assist in sizing the EFVs.
Revision 9b (Publication Date: 04/01/2021; Effective Date: 06/15/2021) has the following changes:
Added GasBreaker Model 51 plastic EFVs now approved for use.
Advanced table numbering throughout for new Table 4.
Revision 9a (Publication Date 03/17/2021, Effective Date 06/15/2021) has the following changes:
- Added new Step 2.1.A to clarify what is meant by a new service line in Table 1.
Printed copies of this document might be out of date. The Technical Information Library (TIL) has the current version.
PG&E Internal Information “PG&E” refers to Pacific Gas and Electric Company, a subsidiary of PG&E Corporation.
©2021 Pacific Gas and Electric Company. All rights reserved.
Page 15 of 19
Excess Flow Valves A-93.3
Frequently asked questions
What exactly must be asked of the utility?
Ask whether the proposed PV kW (or site export), service voltage/type, and intended interconnection method can be accepted without upgrades; request written limits, required protective measures, and any required agreements. CALGreen mandates consultation but not a specific question list. § A4.203.1.3
If the utility requires upgrades, can the jurisdiction still require the larger PV?
No — the jurisdiction cannot require onsite PV systems larger than the utility will allow to be interconnected. The jurisdiction must revise its requirement or allow alternatives. § A4.203.1.3
Does CALGreen specify how to size PV for EDR calculations?
No — EDR sizing and reductions are determined through the performance approach and software (see § A4.203.1.1). CALGreen requires consultation only when PV larger than Energy Code baselines is proposed to support reduced EDR targets.
Can utilities charge for studies or upgrades to allow larger PV?
Yes — utilities commonly require interconnection studies or special facilities agreements and may charge for upgrades; CALGreen does not prohibit utilities from requiring such actions. Utility practice examples show studies and agreements are typical.
Who should the local jurisdiction involve when doing the consultation?
Include local planning/building staff, the jurisdiction’s energy/ sustainability lead, the project designer/engineer, and the utility’s interconnection or account services representative. CALGreen requires the consultation but not the stakeholder list. § A4.203.1.3
More in California Green Building Standards Code (CALGreen)
- Administration (Chapter 1)
- Nonresidential Voluntary Measures (Appendix A5 — divisions A5.1–A5.6, electives & verification)
- Residential Mandatory Measures — Planning & Design; Energy; Water; Materials; Environmental Quality (Chapter 4)
- Definitions (Chapter 2)
- Voluntary Standards for Health Facilities (Appendix A6 / OSHPD guidance)
- Green Building – scope, mixed occupancies, phased projects (Chapter 3)
- Residential Voluntary Measures (Appendix A4 — divisions A4.1–A4.6, tiers & model ordinance)
- Nonresidential Mandatory Measures — Planning & Design; Energy; Water; Materials; Environmental Quality (Chapter 5)
- Compliance verification, construction documents & checklists (Section 102, Chapter 7, Appendix checklists)
- Referenced Organizations and Standards (Chapter 6)
- Voluntary Tiers and CALGreen Tier 1 / Tier 2 (performance tiers, thresholds)
- Installer and Special Inspector Qualifications (Chapter 7)
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