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Chapter 480-100 WAC

Last Update: 6/7/23

ELECTRIC COMPANIES

WAC Sections

PART I—GENERAL PROVISIONS
HTMLPDF480-100-001Purpose.
HTMLPDF480-100-003Application of rules.
HTMLPDF480-100-008Exemptions from rules in chapter 480-100 WAC.
HTMLPDF480-100-013Additional requirements.
HTMLPDF480-100-018Severability.
HTMLPDF480-100-023Definitions.
HTMLPDF480-100-028Tariffs and special contracts.
HTMLPDF480-100-033Distribution line extension tariff.
PART II—CONSUMER RULES
HTMLPDF480-100-103Information to consumers.
HTMLPDF480-100-108Application for service.
HTMLPDF480-100-113Residential services deposit requirements.
HTMLPDF480-100-118Nonresidential service deposit requirements.
HTMLPDF480-100-123Refusal of service.
HTMLPDF480-100-128Disconnection of service.
HTMLPDF480-100-133Reconnecting service after disconnection.
HTMLPDF480-100-138Payment arrangements.
HTMLPDF480-100-143Winter low-income payment program.
HTMLPDF480-100-148Service responsibility.
HTMLPDF480-100-153Protection and disclosure of customer information.
HTMLPDF480-100-163Service entrance facilities.
HTMLPDF480-100-168Access to premises; identification.
HTMLPDF480-100-173Electric utility responsibility for complaints and disputes.
HTMLPDF480-100-178Billing requirements and payment date.
HTMLPDF480-100-179Electronic information.
HTMLPDF480-100-183Complaint meter tests.
HTMLPDF480-100-188Payment locations.
HTMLPDF480-100-193Posting of tariffs for public inspection and review.
HTMLPDF480-100-194Publication of proposed tariff changes to increase charges or restrict access to services.
HTMLPDF480-100-195Notice of tariff changes other than increases in recurring charges and restrictions in access to services.
HTMLPDF480-100-197Adjudicative proceedings where public testimony will be taken.
HTMLPDF480-100-198Notice verification and assistance.
HTMLPDF480-100-199Other customer notice.
PART III—FINANCIAL RECORDS AND REPORTING RULES
HTMLPDF480-100-203Accounting system requirements.
Subpart A: General Rules
HTMLPDF480-100-207Filing information.
HTMLPDF480-100-209Additional reports.
HTMLPDF480-100-213Expenditures for political or legislative activities.
HTMLPDF480-100-223Advertising.
HTMLPDF480-100-228Retention and preservation of records and reports.
Subpart B: Financial Transaction Reporting Requirements
HTMLPDF480-100-242Issuing securities.
HTMLPDF480-100-244Transferring cash or assuming obligations.
HTMLPDF480-100-245Affiliated interests—Contracts or arrangements.
HTMLPDF480-100-248Transfers of property.
Subpart C: Annual Reporting Requirements
HTMLPDF480-100-252Federal Energy Regulatory Commission (FERC) Form No. 1.
HTMLPDF480-100-257Commission basis report.
HTMLPDF480-100-262Securities report.
HTMLPDF480-100-264Affiliated interest and subsidiary transactions report.
HTMLPDF480-100-268Essential utilities services contracts report.
Subpart D: Quarterly Reporting Requirement
HTMLPDF480-100-275Actual results for Washington operations report.
PART IV—LEASE OF UTILITY FACILITIES
HTMLPDF480-100-282Application for approval of lease of utility facilities.
HTMLPDF480-100-287Form of lease application.
PART V—METERING RULES
HTMLPDF480-100-308Meter location.
HTMLPDF480-100-313Meter charges.
HTMLPDF480-100-318Meter readings, multipliers, and test constants.
HTMLPDF480-100-328Meter identification.
HTMLPDF480-100-333Initial accuracy of electric meters.
HTMLPDF480-100-338Accuracy requirements for electric meters.
HTMLPDF480-100-343Statement of meter test procedures.
HTMLPDF480-100-353Meter history records.
PART VI—SAFETY AND STANDARDS RULES
HTMLPDF480-100-358Instrument transformers.
HTMLPDF480-100-363Portable indicating instruments.
HTMLPDF480-100-368Standard frequency.
HTMLPDF480-100-373Standard voltage and permissible variation.
HTMLPDF480-100-378Accuracy of test standards.
HTMLPDF480-100-383Reports of accidents.
HTMLPDF480-100-388Electric service reliability definitions.
HTMLPDF480-100-393Electric service reliability monitoring and reporting plan.
HTMLPDF480-100-398Electric service reliability reports.
PART VII—GREENHOUSE GAS EMISSIONS
HTMLPDF480-100-405Electrical company generation resource compliance with the greenhouse gas emissions performance standard.
HTMLPDF480-100-415Electrical company applications for commission determination outside of a general rate case of electric generation resource compliance with greenhouse gas emissions performance standard.
HTMLPDF480-100-425Electrical company applications for exemption from the greenhouse gas emissions performance standard.
HTMLPDF480-100-435Electrical company deferral of costs associated with long-term financial commitments—Notice and reporting.
HTMLPDF480-100-505Smart grid technology report.
PART VIII—PLANNING AND IMPLEMENTATION
HTMLPDF480-100-600Purpose.
HTMLPDF480-100-605Definitions.
HTMLPDF480-100-610Clean energy transformation standards.
HTMLPDF480-100-620Content of an integrated resource plan.
HTMLPDF480-100-625Integrated resource plan development and timing.
HTMLPDF480-100-630Integrated resource planning advisory groups.
HTMLPDF480-100-640Content of a clean energy implementation plan (CEIP).
HTMLPDF480-100-645Process for review of CEIP and updates.
HTMLPDF480-100-650Reporting and compliance.
HTMLPDF480-100-655Public participation in a clean energy implementation plan (CEIP).
HTMLPDF480-100-660Incremental cost of compliance.
HTMLPDF480-100-665Enforcement.
PART IX—ADOPTION BY REFERENCE
HTMLPDF480-100-999Adoption by reference.
DISPOSITION OF SECTIONS FORMERLY CODIFIED IN THIS TITLE
480-100-010Application of rules. [Order R-5, § 480-100-010, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-011.
480-100-011Application of rules. [Order R-29, § 480-100-011, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-016Saving clause. [Order R-29, § 480-100-016, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-020Saving clause. [Order R-5, § 480-100-020, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-016.
480-100-021Glossary. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-021, filed 12/13/94, effective 1/13/95; WSR 87-23-028 (Order R-279, Cause No. U-87-590-R), § 480-100-021, filed 11/12/87; WSR 84-23-030 (Order R-220, Cause No. U-84-63), § 480-100-021, filed 11/15/84; Order R-29, § 480-100-021, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-026Tariffs. [Order R-29, § 480-100-026, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-030Definitions of terms as used in these rules. [Order R-5, § 480-100-030, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-021.
480-100-031Accounting. [Statutory Authority: RCW 80.01.040. WSR 90-01-058 (Order R-313, Docket No. U-89-3099-R), § 480-100-031, filed 12/15/89, effective 1/15/90; WSR 89-12-070 (Order R-302, Docket No. U-89-2641-R), § 480-100-031, filed 6/7/89; Order R-29, § 480-100-031, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-032Accounting—Political information and political education activities. [Statutory Authority: RCW 80.01.040. WSR 86-04-072 (Order R-251, Cause No. U-85-78), § 480-100-032, filed 2/5/86.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-036Finance—Securities, affiliated interests, transfer of property. [Order R-29, § 480-100-036, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-040Tariffs. [Order R-5, § 480-100-040, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-026.
480-100-041Information to consumers. [Statutory Authority: RCW 80.04.160. WSR 81-03-060 (Order R-158, Cause No. U-80-106), § 480-100-041, filed 1/20/81; Order R-84, § 480-100-041, filed 6/30/76; Order R-29, § 480-100-041, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-043Advertising. [Statutory Authority: RCW 80.04.160. WSR 81-03-060 (Order R-158, Cause No. U-80-106), § 480-100-043, filed 1/20/81.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-046Application for service. [Order R-29, § 480-100-046, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-050Classification of accounts. [Order R-5, § 480-100-050, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71.
480-100-051Establishment of credit. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-051, filed 12/13/94, effective 1/13/95; WSR 87-23-028 (Order R-279, Cause No. U-87-590-R), § 480-100-051, filed 11/12/87; WSR 86-07-032 (Order R-256, Cause No. U-85-81), § 480-100-051, filed 3/14/86; Order R-84, § 480-100-051, filed 6/30/76; Order R-29, § 480-100-051, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-056Refusal of service. [Statutory Authority: RCW 80.04.160. WSR 81-03-060 (Order R-158, Cause No. U-80-106), § 480-100-056, filed 1/20/81; Order R-29, § 480-100-056, filed 7/15/71.] Repealed by WSR 01-24-076 (General Order No. R-495, Docket No. UE-990473), filed 12/3/01, effective 1/3/02. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-060Annual reports. [Order R-5, § 480-100-060, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71.
480-100-061Contract for service. [Order R-29, § 480-100-061, filed 7/15/71.] Repealed by WSR 01-09-002 (Docket No. U-991301, General Order No. R-481), filed 4/4/01, effective 5/5/01. Statutory Authority: RCW 80.04.160 and 80.01.040.
480-100-066Distribution extensions. [Order R-29, § 480-100-066, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-070Information for customers. [Order R-5, § 480-100-070, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-041.
480-100-071Discontinuance of service. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-071, filed 12/13/94, effective 1/13/95; WSR 88-07-070 (Order R-284, Cause No. U-87-1525-R), § 480-100-071, filed 3/18/88; WSR 87-23-028 (Order R-279, Cause No. U-87-590-R), § 480-100-071, filed 11/12/87; WSR 84-23-030 (Order R-220, Cause No. U-84-63), § 480-100-071, filed 11/15/84. Statutory Authority: RCW 80.04.160. WSR 81-03-060 (Order R-158, Cause No. U-80-106), § 480-100-071, filed 1/20/81; Order R-84, § 480-100-071, filed 6/30/76; Order R-29, § 480-100-071, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-072Payment arrangements and responsibilities. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-072, filed 12/13/94, effective 1/13/95; WSR 87-23-028 (Order R-279, Cause No. U-87-590-R), § 480-100-072, filed 11/12/87; WSR 84-23-030 (Order R-220, Cause No. U-84-63), § 480-100-072, filed 11/15/84.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-076Service responsibilities. [Order R-29, § 480-100-076, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-080Record of complaints. [Order R-5, § 480-100-080, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-096.
480-100-081Service entrance facilities. [Order R-29, § 480-100-081, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-086Meter location. [Order R-29, § 480-100-086, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-090Filing of records and reports. [Order R-5, § 480-100-090, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-211.
480-100-091Access to premises. [Order R-29, § 480-100-091, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-096Complaints and disputes. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-096, filed 12/13/94, effective 1/13/95; Order R-84, § 480-100-096, filed 6/30/76; Order R-29, § 480-100-096, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-100Application for service. [Order R-5, § 480-100-100, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-046.
480-100-101Form of bills. [Order R-84, § 480-100-101, filed 6/30/76; Order R-29, § 480-100-101, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-106Dispute as to billing. [Order R-29, § 480-100-106, filed 7/15/71.] Repealed by Order R-84, filed 6/30/76.
480-100-110Contract for service. [Order R-5, § 480-100-110, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-061.
480-100-111Refund for inaccurate metering. [Order R-29, § 480-100-111, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-116Responsibility for delinquent accounts. [Order R-29, § 480-100-116, filed 7/15/71.] Repealed by WSR 01-24-076 (General Order No. R-495, Docket No. UE-990473), filed 12/3/01, effective 1/3/02. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-120Deposits. [Order R-5, § 480-100-120, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-051.
480-100-121Meter charges. [Order R-29, § 480-100-121, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-126Meter readings. [Order R-29, § 480-100-126, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-130Discontinuance of service by customer. [Order R-5, § 480-100-130, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-071.
480-100-131Identification of meters. [Statutory Authority: RCW 81.01.040 (1) and (4) [ 80.01.040 (1) and (4)]. WSR 81-15-094 (Order R-165, Cause No. 4-81-30), § 480-100-131, filed 7/22/81; Order R-29, § 480-100-131, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-136Initial accuracy of meters. [Order R-29, § 480-100-136, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-140Discontinuance of service by utility. [Order R-5, § 480-100-140, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-071.
480-100-141Accuracy of watthour meters. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-141, filed 12/13/94, effective 1/13/95. Statutory Authority: RCW 81.01.040 (1) and (4) [ 80.01.040 (1) and (4)]. WSR 81-15-094 (Order R-165, Cause No. 4-81-30), § 480-100-141, filed 7/22/81; Order R-29, § 480-100-141, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-146Accuracy of demand meters. [Order R-29, § 480-100-146, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-150Fraudulent use of service. [Order R-5, § 480-100-150, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-071.
480-100-151Instrument transformers. [Order R-29, § 480-100-151, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-156Multipliers and test constants. [Order R-29, § 480-100-156, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-160Responsibility for delinquent accounts. [Order R-5, § 480-100-160, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-116.
480-100-161Portable indicating instruments. [Order R-29, § 480-100-161, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-166Dispute as to accuracy of meters. [Order R-29, § 480-100-166, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-170Refusal of service. [Order R-5, § 480-100-170, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-056.
480-100-171Complaint meter test. [Order R-29, § 480-100-171, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-176Statement of meter test procedures. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-176, filed 12/13/94, effective 1/13/95. Statutory Authority: RCW 81.01.040 (1) and (4) [ 80.01.040 (1) and (4)]. WSR 81-15-094 (Order R-165, Cause No. 4-81-30), § 480-100-176, filed 7/22/81; Order R-29, § 480-100-176, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-180Special metering, record of output, etc. [Order R-5, § 480-100-180, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-076.
480-100-181Meter history records. [Order R-29, § 480-100-181, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-186Standard frequency. [Order R-29, § 480-100-186, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-190Change in character of service. [Order R-5, § 480-100-190, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-076.
480-100-191Standard voltage and permissible variation. [Order R-29, § 480-100-191, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-196Voltage tests. [Order R-29, § 480-100-196, filed 7/15/71.] Repealed by WSR 81-15-094 (Order R-165, Cause No. 4-81-30), filed 7/22/81. Statutory Authority: RCW 81.01.040 (1) and (4) [ 80.01.040 (1) and (4)].
480-100-200Changes in use. [Order R-5, § 480-100-200, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-076.
480-100-201Accuracy of test standards. [Statutory Authority: RCW 81.01.040 (1) and (4) [ 80.01.040 (1) and (4)]. WSR 81-15-094 (Order R-165, Cause No. 4-81-30), § 480-100-201, filed 7/22/81; Order R-29, § 480-100-201, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-206Reports of accidents. [Order R-29, 480-100-206, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-208Financial reporting requirements. [Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 2003 c 296. WSR 04-05-031 (Docket No. A-031232, General Order No. R-512), § 480-100-208, filed 2/11/04, effective 3/13/04. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 02-18-033 (Docket No. A-020379, General Order No. R-501), § 480-100-208, filed 8/26/02, effective 9/26/02. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-208, filed 5/3/01, effective 6/3/01.] Repealed by WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), filed 2/28/05, effective 3/31/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353.
480-100-210Adequacy and continuity of service. [Order R-5, § 480-100-210, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-076.
480-100-211Filing of records and reports and the preservation of records. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-211, filed 12/13/94, effective 1/13/95; Order R-29, § 480-100-211, filed 7/15/71.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-218Securities, affiliated interests, and transfers of property. [Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-218, filed 5/3/01, effective 6/3/01.] Repealed by WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), filed 2/28/05, effective 3/31/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353.
480-100-220Distribution extensions. [Order R-5, § 480-100-220, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-066.
480-100-230Service entrance facilities. [Order R-5, § 480-100-230, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-081.
480-100-238Integrated resource planning. [Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 06-03-001 (Docket Nos. UE-030311 and UG-030312, General Order No. R-526), § 480-100-238, filed 1/4/06, effective 2/4/06; WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-238, filed 5/3/01, effective 6/3/01.] Repealed by WSR 21-07-074, filed 3/17/21, effective 4/17/21. Statutory Authority: RCW 80.01.040, 80.04.160, chapters 80.28, 19.280, and 19.405 RCW.
480-100-240Standard frequency. [Order R-5, § 480-100-240, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-186.
480-100-250Standard voltage and permissible variation. [Order R-5, § 480-100-250, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-191.
480-100-251Least cost planning. [Statutory Authority: RCW 80.01.040. WSR 87-11-045 (Order R-273, Cause No. U-86-141), § 480-100-251, filed 5/19/87.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-260Voltage tests. [Order R-5, § 480-100-260, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-196.
480-100-270Form of bills. [Order R-5, § 480-100-270, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-101.
480-100-280Record of billings. [Order R-5, § 480-100-280, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-106.
480-100-290Dispute as to bills. [Order R-5, § 480-100-290, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-086.
480-100-300Meter location. [Order R-5, § 480-100-300, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-086.
480-100-310Access to premises. [Order R-5, § 480-100-310, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-091.
480-100-311Business offices and payment agencies. [Statutory Authority: RCW 80.01.040. WSR 95-01-051 (Order R-423, Docket No. UE-940084), § 480-100-311, filed 12/13/94, effective 1/13/95.] Repealed by WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), filed 5/3/01, effective 6/3/01. Statutory Authority: RCW 80.01.040 and 80.04.160.
480-100-320Identification of employees. [Order R-5, § 480-100-320, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-091.
480-100-330Meter charges. [Order R-5, § 480-100-330, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-121.
480-100-340Meter readings. [Order R-5, § 480-100-340, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-126.
480-100-350Initial accuracy of meters. [Order R-5, § 480-100-350, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-136.
480-100-360Meter seals. [Order R-5, § 480-100-360, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-136.
480-100-370Meter history record. [Order R-5, § 480-100-370, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-181.
480-100-380Multipliers and test constants. [Order R-5, § 480-100-380, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-156.
480-100-390Accuracy of watthour meters. [Order R-5, § 480-100-390, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-141.
480-100-400Accuracy of demand meters. [Order R-5, § 480-100-400, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-146.
480-100-410Instrument transformers. [Order R-5, § 480-100-410, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-151.
480-100-420Portable indicating instruments. [Order R-5, § 480-100-420, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-161.
480-100-430Meter testing. [Order R-5, § 480-100-430, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-176.
480-100-440Record of meter tests. [Order R-5, § 480-100-440, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-181.
480-100-450Dispute as to accuracy of meters. [Order R-5, § 480-100-450, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-166.
480-100-460Free complaint meter test. [Order R-5, § 480-100-460, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-171.
480-100-470Fee for extra-complaint meter tests. [Order R-5, § 480-100-470, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-171.
480-100-480Complaint reports. [Order R-5, § 480-100-480, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-171.
480-100-490Refund for inaccurate metering. [Order R-5, § 480-100-490, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-111.
480-100-500Identification of meters. [Order R-5, § 480-100-500, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-131.
480-100-510Testing facilities. [Order R-5, § 480-100-510, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71.
480-100-520Accuracy of test standards. [Order R-5, § 480-100-520, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-201.
480-100-530Report of accidents. [Order R-5, § 480-100-530, filed 6/6/69, effective 10/9/69.] Repealed by Order R-29, filed 7/15/71. See WAC 480-100-206.

PDF480-100-001

Purpose.

The legislature has declared that operating as an electric utility in the state of Washington is a business affected with the public interest and that such utilities should be regulated. The purpose of these rules is to administer and enforce chapter 80.28 RCW by establishing rules of general applicability and requirements for:
• Consumer protection;
• Financial records and reporting;
• Electric metering; and
• Electric safety and standards.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-001, filed 5/3/01, effective 6/3/01.]


PDF480-100-003

Application of rules.

(1) The rules in this chapter apply to any electric utility that is subject to the jurisdiction of the commission under RCW 80.04.010 and chapter 80.28 RCW. These rules also include various requirements of the utility's customers and applicants.
(2) The tariff provisions filed by utilities must conform with these rules. If the commission accepts a tariff that conflicts with these rules, the acceptance does not constitute a waiver of these rules unless the commission specifically approves the variation consistent with WAC 480-100-008, Exemptions from rules in chapter 480-100 WAC. Tariffs that conflict with these rules without approval are superseded by these rules.
(3) Any affected person may ask the commission to review the interpretation of these rules by a utility or customer by posing an informal complaint under WAC 480-07-910, Informal complaints, or by filing a formal complaint under WAC 480-07-370, Pleading and briefs—Application for authority—Protests.
(4) No deviation from these rules is permitted without written authorization by the commission. Violation will be subject to penalties as provided by law.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 03-24-028 (General Order R-510, Docket No. A-010648), § 480-100-003, filed 11/24/03, effective 1/1/04; WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-003, filed 5/3/01, effective 6/3/01.]


PDF480-100-008

Exemptions from rules in chapter 480-100 WAC.

The commission may grant an exemption from the provisions of any rule in this chapter in the same manner and consistent with the standards and according to the procedures set forth in WAC 480-07-110 (Exceptions from and modifications to the rules in this chapter; special rules).
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-008, filed 2/28/05, effective 3/31/05. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 03-24-028 (General Order R-510, Docket No. A-010648), § 480-100-008, filed 11/24/03, effective 1/1/04; WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-008, filed 5/3/01, effective 6/3/01.]


PDF480-100-013

Additional requirements.

(1) These rules do not relieve any electric utility from any of its duties and obligations under the laws of the state of Washington.
(2) The commission retains the authority to impose additional or different requirements on any electric utility in appropriate circumstances, consistent with the requirements of law.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-013, filed 5/3/01, effective 6/3/01.]


PDF480-100-018

Severability.

If any provision of this chapter or its application to any person or circumstance is held invalid, the remainder of the chapter or the application of the provision to other persons or circumstances is not affected.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-018, filed 5/3/01, effective 6/3/01.]


PDF480-100-023

Definitions.

"Account and usage information" means customer information contained in the records a utility keeps for each customer to provide and bill for utility service including, but not limited to, the customer's name, account number, address where service is provided, customer contact information, services the utility is providing or has provided to the customer, energy usage, customer financial information, bills the utility has issued, payment history, and medical or low-income status.
"Affiliated interest" means a person or corporation as defined in RCW 80.16.010.
"Aggregate data" means any collection of customer data by a utility from which identifiable customer information has been removed or modified so that the information cannot be attributed to any individual customer.
"Applicant" means any person, corporation, partnership, government agency, or other entity that applies, or is named in an application as a person having joint responsibility, for service with an electric utility or who reapplies for service at a new or existing location after service has been disconnected if the utility requires the person to reapply for service.
"Business day" means Monday through Friday, 8:00 a.m. until 5:00 p.m., except for official state holidays.
"Commission" means the Washington utilities and transportation commission.
"Control" means the possession, direct or indirect, of the power to direct or cause the direction of the management and policies of a company, whether through the ownership of voting shares, by contract, or otherwise.
"Customer" means any person, corporation, partnership, government agency, or other entity that has applied, or is named as a person having joint responsibility, for service and that has been accepted, and is currently receiving or is entitled to receive such service. "Customer" for purposes of this chapter may also include a person or other entity whose service has been involuntarily disconnected and that person or entity then seeks to have the utility reconnect service.
"Customer information" means private customer information and proprietary customer information as defined in RCW 19.29A.010 and personal information as defined in chapter 19.255 RCW.
"Electric utility (utility)" means any business entity (e.g., corporation, company, association, joint stock association, or partnership) or person, including a lessee, trustee, or court appointed receiver that is subject to the commission's jurisdiction and that owns, controls, operates, or manages any electric plant for hire in Washington.
"Primary purpose" means a business need to provide regulated utility services as required by state or federal law, or as specifically authorized in the utility's effective tariff or by the commission.
"Subsidiary" means any company in which the electric utility owns directly or indirectly five percent or more of the voting securities, unless the utility demonstrates it does not have control of that company.
"Written consent" means permission or authorization in writing, whether electronic or paper.
Other terms. Terms used in this chapter and defined in the public service laws of Washington (i.e., principally Title 80 RCW) have the same meaning here as in the statutes. Terms not defined in these rules or the applicable statutes have the meaning generally accepted in the electric industry, or their ordinary meaning if there is no meaning generally accepted in the electric industry.
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapter 80.28 RCW. WSR 20-16-077 (Docket U-180525, General Order R-600), § 480-100-023, filed 7/29/20, effective 8/29/20. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-023, filed 2/28/05, effective 3/31/05. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-023, filed 5/3/01, effective 6/3/01.]


PDF480-100-028

Tariffs and special contracts.

An electric utility must publish its rate schedules and rules and regulations governing service, and file special contracts, in accordance with chapter 480-80 WAC, Utilities general—Tariffs, price lists, and contracts.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-028, filed 5/3/01, effective 6/3/01.]


PDF480-100-033

Distribution line extension tariff.

Each electric utility must file, as a part of its tariff, a distribution line extension rule setting forth the conditions under which it will extend its facilities to make service available to an applicant.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-033, filed 5/3/01, effective 6/3/01.]


PDF480-100-103

Information to consumers.

(1) An electric utility must make available at each of its listed business offices information regarding rates, rules, and regulations needed for its customers and applicants to obtain adequate and efficient service.
(2) The utility must maintain a toll-free telephone number available for its applicants and customers during business hours to receive information relating to services and rates, to accept and process orders for service, to explain charges on customer bills, to adjust charges made in error, to respond to customer inquiries and complaints, and to generally act as representatives of the utility.
(3) The utility must provide to each applicant relevant rate information and a brochure that explains the rights and responsibilities of a utility customer. The brochure must include, at a minimum, information about the utility's regular business hours, the utility's mailing address, the utility's toll-free number, the twenty-four hour emergency number(s), and an explanation of the utility's processes to establish credit, deposits, billing, delinquent accounts, disconnection of service initiated by the utility, cancellation of service by the customer, the dispute resolution process, and the commission's informal complaint procedures to be followed if the customer remains dissatisfied with the utility's dispute process. The utility may provide this information in an electronic format consistent with provisions in this chapter governing the use of electronic information.
(4) At least once each year, the utility must directly advise each of its customers how to obtain:
(a) A copy of the consumer brochure described in subsection (3) of this section;
(b) A copy of the customer's applicable rate information;
(c) A copy of the electric rules, chapter 480-100 WAC; and
(d) A copy of the utility's current rates and regulations.
(5) The utility must provide an applicant, upon request, the high and low bills for the requested service premises during the prior calendar year, if such data is available.
(6) The utility must provide a customer, upon request, a detailed account of the customer's actual electric usage at the service premises for the previous twelve-month period, if such data is available.
(7) The utility must provide customers information comparing energy usage for the current month and same billing month of the previous year, if available, either on the customers' bills or upon request, as follows:
(a) Number of days in billing period;
(b) Kilowatt hours used; and
(c) Average kilowatt hours used per day.
(8) The utility must provide the commission with electronic or paper copies of all pamphlets, brochures, and bill inserts of regulated service information at the same time the utility delivers such material to its customers.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 11-06-032 (Docket U-100523, General Order R-563), § 480-100-103, filed 2/25/11, effective 3/28/11; WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-103, filed 5/3/01, effective 6/3/01.]


PDF480-100-108

Application for service.

(1) When an applicant orders service from an electric utility, the applicant will be responsible for conforming to the rules and regulations that are in effect and on file with the commission.
(2) The utility may require the following information when an applicant applies for service:
(a) The applicant's name, address, and telephone number, and an alternative contact telephone number, if applicable, of the responsible party at the service premises;
(b) The date the service is requested to be effective;
(c) The type of service requested, such as residential or commercial service, and the type of equipment to be served at the service premises;
(d) Proof of identification. The utility must allow the applicant to choose from a list, provided by the utility, of at least five sources of identification. The list must include a current driver's license or other picture identification; and
(e) Any additional information the utility may reasonably require for billing or service.
(3) The utility must offer, if available, a service-order tracking number so the customer can easily identify the service request in subsequent interactions with the utility.
(4) The utility must provide the following service dates to the applicant:
(a) For service at a location where utility service facilities exist and will not have to be modified in any way to serve the applicant, the utility must provide a service date at the time of application. If the utility becomes aware that the service date cannot be met, it must notify the applicant on or prior to the service date;
(b) For service at a location where utility service facilities do not exist or require modification, the utility will provide the following service dates:
(i) Upon request by the applicant, prior to signing a service agreement, the utility must provide a range of dates by which service can be made available;
(ii) Upon signing a service agreement with the applicant, the utility must provide a date by which service will be made available. If the utility becomes aware that the service date cannot be met, it must notify the applicant on or prior to the service date.
(5) A customer may not resell electricity unless specifically authorized in the utility's tariff.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-108, filed 5/3/01, effective 6/3/01.]


PDF480-100-113

Residential services deposit requirements.

(1) Deposit criteria for current residential customers. An electric utility may collect a deposit from its own customers for residential service only if:
(a) At any time during the prior twelve months, the utility has sent the customer three or more delinquency notices;
(b) The utility has disconnected the customer's residential service for nonpayment; or
(c) There is a prior customer living at the residence who owes a past-due bill to the utility for service at that address.
(2) Deposit criteria for residential applicants. A utility may collect a deposit from an applicant for residential service only if:
(a) The applicant has met any of the conditions described in subsection (1) of this section as a prior customer of the utility or as a customer of another electric utility;
(b) The applicant is not able to demonstrate continuous employment during the prior twelve consecutive months and neither is currently employed nor has a regular source of income;
(c) The applicant does not own or is not purchasing the premises to be served;
(d) There is a prior customer living at the residence who owes a past-due bill to the utility at that address; or
(e) The applicant has an unpaid, overdue balance owing to any electric or gas utility for residential service.
(3) Deposit amount. Deposits required for a customer or location must not exceed:
(a) Two-twelfths of the estimated annual billings for utilities billing monthly; or
(b) Three-twelfths of estimated annual billings for utilities billing bimonthly.
(4) Deposit payment arrangements. The utility must allow an applicant or customer the option of paying fifty percent of the deposit prior to service, and paying the remaining balance in equal amounts over the next two months, on the dates mutually agreed upon between the applicant or customer and the utility. The utility and applicant or customer may make other mutually acceptable deposit payment arrangements.
(5) Alternative to deposit. The utility must allow any applicant or customer who indicates an inability to pay a deposit:
(a) To prepay any service initiation fees and reasonably estimated regular service charges or budget billings at periods corresponding to the utility's regular billing periods for the length of time during which a deposit would ordinarily be required. The utility must then bill the applicant or customer in a normal fashion; or
(b) To furnish a satisfactory guarantor. A guarantor will be considered satisfactory if the guarantor has at least established credit with the utility as outlined in this section. A utility may, at its discretion, accept a guarantor that does not meet the requirements of this section. If the customer has been disconnected, the guarantor is responsible for the amount stated on the disconnection notice, not to exceed the amount of the deposit as defined in subsection (3) of this section unless the guarantor has agreed to guarantee an additional amount as specified in subsection (7) of this section; or
(c) To notify the utility of the inability to pay a deposit as provided in WAC 480-100-143, Winter low-income payment program; or
(d) The opportunity to provide a reference from a similar utility that can quickly and easily be checked if the conditions in subsection (1) of this section cannot be met.
(6) Transfer of deposit. When a customer moves to a new address within the utility's service territory, the deposit plus accrued interest, less any outstanding balance owing from the old address, must be transferred to the new address or refunded.
(7) Additional deposit. If a deposit or additional deposit amount is required after the service is established, the reasons must be specified to the customer in writing. Any request for a deposit or additional deposit amount must comply with the standards outlined in subsection (1) of this section. If the original deposit was secured by a guarantor and the guarantor does not agree to be responsible for the additional deposit amount, the customer will be held responsible for paying the additional deposit.
(8) Deposit payment date. Any deposit or additional deposit amount required after service is established is due and payable not earlier than 5:00 p.m. of the sixth business day after notice, if the deposit requirement notice is mailed from within the states of Washington, Oregon, or Idaho, or the ninth business day if mailed from outside the states of Washington, Oregon, and Idaho. If the utility delivers the notice to the customer in person, the deposit or additional deposit amount is due and payable not earlier than 5:00 p.m. of the sixth business day from the date of delivery.
(9) Interest on deposits. Utilities that collect customer deposits must pay interest on those deposits calculated:
(a) For each calendar year, at the rate for the one-year Treasury Constant Maturity calculated by the U.S. Treasury, as published in the Federal Reserve's Statistical Release H.15 on January 15 of that year. If January 15 falls on a nonbusiness day, the utility will use the rate posted on the next following business day; and
(b) From the date of deposit to the date of refund or when applied directly to the customer's account.
(10) When refund of deposits is required. A utility must apply deposits plus accrued interest to the customer's account, or refund deposits plus accrued interest when there has been satisfactory payment, as defined in (a) of this subsection, or when service is terminated.
(a) "Satisfactory payment" means a customer has paid for service for twelve consecutive months in a prompt and satisfactory manner as evidenced by the following:
(i) The utility has not started a disconnection process against the customer; and
(ii) The utility has sent no more than two delinquency notices to the customer.
(b) Termination of service. When service is terminated, the utility must return to the customer the deposit amount plus accrued interest, less any amounts due the utility by the customer.
(11) How deposits are refunded. A utility must refund any deposit plus accrued interest as indicated by the customer at the time of deposit, or as modified by the customer on a later date, using one of the following methods:
(a) A check issued and mailed to the customer no later than fifteen days following completion of twelve months of satisfactory payment, as described above; or
(b) A credit applied to the customer's account for service beginning in the thirteenth month.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 02-21-066 (Docket No. A-020405, General Order No. R-504), § 480-100-113, filed 10/16/02, effective 1/1/03. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-113, filed 5/3/01, effective 6/3/01.]


PDF480-100-118

Nonresidential service deposit requirements.

(1) Deposit criteria for nonresidential customers. A utility may require an applicant for nonresidential service to demonstrate that the applicant is a satisfactory credit risk by reasonable means appropriate under the circumstances.
(2) Deposit amount. Deposits required for a customer or location must not exceed:
(a) Two-twelfths of the estimated annual billings for utilities billing monthly; or
(b) Three-twelfths of estimated annual billings for utilities billing bimonthly.
(3) Transfer of deposit. When a customer moves to a new address within the utility's service territory, the deposit plus accrued interest, less any outstanding balance owing from the old address, must be transferred to the new address or refunded.
(4) Additional deposit. If a deposit or additional deposit amount is required after the service is established, the reasons must be specified to the customer in writing. Any request for a deposit or additional deposit amount must comply with the standards outlined in subsection (1) of this section. If the original deposit was secured by a guarantor and the guarantor does not agree to be responsible for the additional deposit amount, the customer will be held responsible for paying the additional deposit.
(5) Deposit payment date. Any deposit or additional deposit amount required after service is established is due and payable not earlier than 5:00 p.m. of the sixth business day after notice, if the deposit requirement notice is mailed from within the states of Washington, Oregon, or Idaho, or the ninth business day if mailed from outside the states of Washington, Oregon, and Idaho. If the utility delivers the notice to the customer in person, the deposit or additional deposit amount is due and payable not earlier than 5:00 p.m. of the sixth business day from the date of delivery.
(6) Interest on deposits. Utilities that collect customer deposits must pay interest on those deposits calculated:
(a) For each calendar year, at the rate for the one-year Treasury Constant Maturity calculated by the U.S. Treasury, as published in the Federal Reserve's Statistical Release H.15 on January 15 of that year. If January 15 falls on a nonbusiness day, the utility will use the rate posted on the next following business day; and
(b) From the date of deposit to the date of refund or when applied directly to the customer's account.
(7) When refund of deposits is required. A utility must apply deposits plus accrued interest to the customer's account, or refund deposits plus accrued interest when there has been satisfactory payment, as defined in (a) of this subsection, or when service is terminated.
(a) "Satisfactory payment" means a customer has paid for service for twelve consecutive months in a prompt and satisfactory manner as evidenced by the following:
(i) The utility has not started a disconnection process against the customer; and
(ii) The utility has sent no more than two delinquency notices to the customer.
(b) Termination of service. When service is terminated, the utility must return to the customer the deposit amount plus accrued interest, less any amounts due the utility by the customer.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 02-21-066 (Docket No. A-020405, General Order No. R-504), § 480-100-118, filed 10/16/02, effective 1/1/03. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-118, filed 5/3/01, effective 6/3/01.]


PDF480-100-123

Refusal of service.

(1) An electric utility may refuse requests to provide service to a master meter in a building with permanent occupants when all of the following conditions exist:
(a) The building or property has more than one dwelling unit;
(b) The occupants control a significant part of the electricity used in the individual units; and
(c) It is cost-effective for the occupants to have the utility purchase and install individual meters considering the long-run benefits of measuring and billing each occupant's electric use separately.
(2) The utility may refuse to provide new or additional service if:
(a) Providing service does not comply with government regulations or the electric industry accepted standards concerning the provision of service;
(b) In the utility's reasonable judgment, the applicant's or customer's installation of wiring or electrical equipment is considered hazardous or of such a nature that safe and satisfactory service cannot be provided;
(c) The applicant or customer does not comply with the utility's request that the applicant or customer provide and install protective devices, when the utility, in its reasonable judgment deems such protective devices are necessary to protect the utility's or other customers' properties from theft or damage;
(d) After reasonable efforts by the responsible party, all necessary rights of way, easements, approvals, and permits have not been secured; or
(e) The customer is known by the utility to have tampered with or stolen the utility's property, used service through an illegal connection, or fraudulently obtained service and the utility has complied with WAC 480-100-128(2), disconnection of service.
(3) An electric utility may not refuse to provide new or additional service to a residential applicant or residential customer who has a prior obligation. A prior obligation is the dollar amount, excluding deposit amounts owed, the utility has billed to the customer and for which the utility has not received payment at the time the service has been disconnected for nonpayment. The utility must provide service once the customer or applicant has paid all appropriate deposit and reconnection fees. This subsection does not apply to customers that have been disconnected for failure to honor the terms of a winter low-income payment program.
(4) The utility may not refuse to provide service to an applicant or customer because there are outstanding amounts due from a prior customer at the same premises, unless the utility can determine, based on objective evidence, that a fraudulent act is being committed, such that the applicant or customer is acting in cooperation with the prior customer with the intent to avoid payment.
(5) The utility may refuse to provide new or additional service for reasons not expressed in subsections (1) and (2) of this section, upon prior approval of the commission. The commission may grant the request upon determining that the utility has no obligation to provide the requested service under RCW 80.28.110. Prior to seeking commission approval, the utility must work with the applicant or customer requesting service to seek resolution of the issues involved.
(6) Any applicant or customer who has been refused new or additional service may file with the commission an informal complaint under WAC 480-07-910, Informal complaints; or a formal complaint under WAC 480-07-370, Pleadings—General.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 03-24-028 (General Order R-510, Docket No. A-010648), § 480-100-123, filed 11/24/03, effective 1/1/04; WSR 01-24-076 (General Order No. R-495, Docket No. UE-990473), § 480-100-123, filed 12/3/01, effective 1/3/02.]


PDF480-100-128

Disconnection of service.

(1) Customer-directed. A utility may require customers to give at least three days' advance notice of customer-directed disconnection when the utility uses dispatched utility personnel to disconnect service. The utility may require up to twenty-four hours advance notice of customer-directed disconnection from customers serviced via a meter with remote disconnect capability. The customer is not responsible for usage after the requested date for disconnection of service, provided the customer gave the utility the notice required in this rule and the utility's tariff. If the customer moves from the service address and fails to request that service be disconnected, the customer will be responsible for paying for service taken at that service address until the utility can confirm the date that the customer vacated the premises and the utility can access the meter, if necessary, or that a new responsible party is taking service at that address.
(2) Utility-directed with notice. After notifying the customer as required in subsection (4) of this section, the utility may disconnect service for any one of the following conditions:
(a) The customer has delinquent charges associated with regulated electric service, including any required deposit; however, the utility may not disconnect service when the customer has met the requirements of subsection (8) of this section for medical conditions or emergencies, or has agreed to and maintains agreed-upon payment arrangements with the utility, as described in WAC 480-100-143, Winter low-income payment program;
(b) Electric service the utility provides is being used for purposes or properties other than those specified in the customer's service application;
(c) Flat-rate service for nonmetered load has increased electric use without the utility's approval;
(d) The customer refuses to allow, or utility representatives are otherwise unable to obtain, access to the customer's premises as required in WAC 480-100-168, Access to premises; identification;
(e) Violation of utility rules, service agreements, or filed tariff(s); or
(f) Equipment is being used that detrimentally affects the utility's service to its other customers or may result in detrimental impacts to the safety of those customers or other persons, customers' equipment or property, or utility service.
(3) A utility may not disconnect electric service for amounts that the customer may owe the utility for nonregulated service.
(4) Disconnection notification requirements. The utility must notify a customer as provided in this subsection before disconnecting the customer's service, except as described in subsection (7) of this section.
(a) The utility must provide at least two separate disconnection notices to the customer.
(i) The utility must provide the first disconnection notice in writing by delivery of a paper copy to the service premises. The utility must either mail a paper copy of the notice or deliver the notice to the service premises by attaching the notice to the customer's primary door. The notice must be mailed or delivered to the premises at least eight business days before the disconnection date. If the notice is mailed from outside the states of Washington, Oregon, or Idaho, the utility must mail the notice eleven days before the disconnection date. In addition, the utility must provide an electronic copy of the notice, if the utility has such contact information for the customer and the customer has consented to electronic delivery of notices from the utility, at the time the utility mails or delivers the paper copy of the notice.
(ii) The utility must provide the second disconnection notice electronically (if the utility has such contact information and customer consent to electronic delivery of notices) at least two business days before the disconnection date and by one of the three options listed below:
(A) Delivered notice. The utility must deliver a paper copy of the second notice to the service premises and attach it to the customer's primary door at least two business days before the disconnection date.
(B) Mailed notice. The utility must mail a paper copy of the second notice at least three business days before the disconnection date unless mailed outside of the states of Washington, Oregon, or Idaho, in which case the utility must mail the notice no less than six business days before the disconnection date.
(C) Telephone notice. The utility must attempt at least two times to contact the customer by telephone during regular business hours at least three business days before the disconnection date to enable sufficient time to send a timely written notice if the utility is unable to speak with the customer by telephone. The utility must keep a log or record of the calls for a minimum of ninety calendar days showing the telephone number called, the time of the call, and details of the results of each attempted call. If the utility is unable to speak with the customer by telephone, the utility must deliver or mail a paper copy of the second notice as provided in (a)(ii)(A) or (B) of this subsection.
(b) Each disconnection notice must include all relevant information about the disconnection action including:
(i) The cause for disconnection, the amount owed for regulated electric service, and how to avoid disconnection including, but not limited to, the availability of, and how to apply for, energy assistance, low-income assistance, exemptions for low-income assistance and medical conditions or emergencies, and a payment plan as required under WAC 480-100-138 Payment arrangements;
(ii) All relevant information about any charges that the utility is assessing or that it may assess;
(iii) The utility's name, address, and toll-free telephone number by which a customer may contact the utility to discuss the pending disconnection of service;
(iv) If the notices are for nonpayment and the utility is scheduling disconnection during the late fall and winter between November 15th and March 15th, the utility must advise the customer of the payment plan option in WAC 480-100-143 Winter low-income payment program; and
(v) If the utility may be disconnecting service via a remote disconnection device, the notice must include a statement that the utility may disconnect the customer's service without a final visit from utility personnel.
(c) If the utility discovers that an issued notice does not contain the information required under (b) of this subsection, or if the information in the notice is inaccurate, the utility must issue another notice to the customer as described in (a)(i) or (ii) of this subsection, as applicable, and must recalculate the scheduled disconnection date to the extent necessary to ensure that the utility complies with the minimum prior notice requirements.
(d) If the utility does not disconnect service within ten business days from the disconnection date stated in a disconnection notice under (a)(i) or (ii) of this subsection, the utility must restart the disconnection notice process required in (a) of this subsection unless the customer and the utility have agreed to a payment arrangement.
(e) A utility with combined accounts for both natural gas and electric service may disconnect the electric service in compliance with these rules if the reason for the disconnection applies or is attributable to that service. The utility may disconnect the natural gas service in compliance with chapter 480-90 WAC if the reason for the disconnection applies or is attributable to that service. The utility must state which service it intends to disconnect and any measures the customer needs to undertake to retain the other service. If the utility seeks to disconnect both services, the utility must distinctly identify both services it intends to disconnect.
(f) When the service address is different from the billing address, the utility must determine if the customer of record and the service user are the same party. If they are not the same party, the utility must provide notice to the service user as described in (a) of this subsection prior to disconnecting service.
(g) Except in case of danger to life or property, the utility may not disconnect service on Saturdays, Sundays, legal holidays, or on any other day on which the utility cannot reestablish service on the same or following day.
(h) Any representative the utility dispatches in connection with service disconnection must accept payment of a delinquent account at the service address, but will not be required to give change for cash paid in excess of the amount due and owing. The utility must credit any over-payment to the customer's account. The utility may charge a fee for the disconnection visit to the service address if provided for in the utility's tariff.
(i) When the utility provides service through a master meter, or when the utility has reasonable grounds to believe it is providing service to a person other than the customer of record, the utility must undertake reasonable efforts to inform the occupants of the service address of the impending disconnection. Upon request of one or more service users, where service is to a person other than the customer of record, the utility must allow at least five days past the original disconnection date to permit the service users to arrange for continued service.
(j) Medical facilities. The utility must take the following additional steps when the utility is aware that it is providing service to specified types of medical facilities.
(i) If the utility is providing service to a hospital, medical clinic, ambulatory surgery center, renal dialysis facility, chemical dependency residential treatment facility, or other medical care facility licensed or certified by the department of health (DOH), the utility must provide a notice of pending disconnection to the DOH secretary and to the customer. Upon request of the DOH secretary or designee, the utility must delay the disconnection for at least five business days past the original disconnection date to allow DOH to take the necessary steps to protect the interests of the patients residing at the facility.
(ii) If the utility is providing service to a nursing home, boarding home, adult family home, group care facility, intermediate care facility for individuals with intellectual disabilities, intensive tenant support residential property, crisis residential center for children, or residential care facility licensed or certified by the department of social and health services (DSHS), the utility must provide a notice of pending disconnection to the DSHS secretary and to the customer. Upon request of the DSHS secretary or designee, the utility must delay the disconnection for at least five business days past the original disconnection date to allow DSHS to take the necessary steps to protect the interests of the patients residing at the facility.
(iii) A utility may not remotely disconnect customers who the utility is aware provide the services described in (j)(i) and (ii) of this subsection, and the utility must take reasonable precautions to prevent any unauthorized disconnection of those customers.
(k) Any customer may designate a third party to receive a disconnection notice or notice of other matters affecting the customer's service. The utility must offer all customers the opportunity to make such a designation. If the utility has reasonable grounds to believe that a customer is not able to understand the effect of the disconnection, the utility must take reasonable steps to ascertain whether a third party, such as DSHS or other social services agency, is responsible for the customer's affairs. In either circumstance, the utility must delay service disconnection for at least five business days past the original disconnection date after issuing a disconnection notice to the third party. The utility must determine which social services agencies are appropriate and willing to receive the disconnection notice and the name and/or title of the person able to deal with the disconnection, and the utility must provide that information to the customer.
(5) For purposes of this section, the date of mailing a notice will not be considered the first day of the notice period.
(6) Remote disconnection. When disconnecting services remotely, the utility must:
(a) Disable remote disconnection functionality for medical facilities and critical infrastructure as identified in or pursuant to the Washington state military department's Washington state infrastructure protection plan; and limit the number of remote disconnections in a twenty-four hour period or take other reasonable measures to prevent unauthorized disconnections;
(b) Perform all remote disconnections for nonpayment between the hours of 8:00 a.m. and 12:00 p.m. and remotely disconnect service only if the utility provides customers with a reasonable opportunity to submit payment and have the utility reestablish service on the same day;
(c) Prior to involuntarily disconnecting a customer who has a medical certificate in accordance with subsection (8) of this section, visit the customer's premises and provide the customer with an opportunity to pay via appropriate methods including providing payment to the dispatched utility representative;
(d) Prior to disconnecting a customer for nonpayment who the utility is aware has received low-income assistance in the prior two years, visit the customer's premises and provide the customer with an opportunity to pay via appropriate methods including providing payment to the dispatched utility representative;
(e) If a site visit is not required to disconnect the service, the utility may not charge any fees for the disconnection.
(7) Utility-directed disconnection without prior notice.
(a) A utility may disconnect service without prior notice or without further prior notice under any of the following circumstances:
(i) After conducting a thorough investigation, the utility determines that the customer has tampered with or stolen the utility's property, has used service through an illegal connection, or has fraudulently obtained service. In any challenge to that determination, the utility has the burden of proving that fraud occurred. For the purpose of this section, a nonsufficient funds check or dishonored electronic payment alone will not be considered fraud.
(A) First offense. The utility may disconnect service without prior notice when it discovers theft, tampering, or fraud, unless the customer immediately pays all of the following:
(I) The tariffed rate for service that the utility estimates was used as a result of the theft, tampering, or fraud;
(II) All utility costs resulting from such theft, tampering, or fraud; and
(III) Any required deposit.
(B) Second offense. The utility may disconnect service without prior notice when it discovers further theft, tampering, or fraud. The utility may refuse to reconnect service to a customer who has been twice disconnected for theft, tampering, or fraud unless the commission determines otherwise.
(ii) After conducting a thorough investigation, the utility determines that the customer has vacated the premises;
(iii) The utility identifies a hazardous condition in the customer's facilities or in the utility's facilities serving the customer;
(iv) A customer pays a delinquent account with a check or electronic payment the bank or other financial institution has dishonored after the utility has issued notice as required in subsection (4) of this section;
(v) The customer has not kept any agreed-upon payment arrangement for payment of a delinquent balance after the utility has issued notice as required in subsection (4) of this section; or
(vi) The utility has determined a person has used service prior to applying for service. The utility must charge the person for service used in accordance with the utility's filed tariff. If the utility has reasonably sufficient grounds to conclude that the unauthorized usage is in good faith, the utility should notify the person and provide an opportunity to apply for service prior to disconnection.
(b) If the utility disconnects service without prior notice as authorized in this subsection, the utility must subsequently make a reasonable effort to notify the customer or affected person of the reason for the disconnection within five business days. Such notice must also describe the means by which the customer or person may dispute the utility's actions including, but not limited to, contacting the commission.
(c) This section should not be interpreted as relieving the customer or other person of civil or criminal responsibility.
(8) Medical conditions or emergencies. When the utility has cause to disconnect or has disconnected a residential service, it must postpone disconnection of service or must reinstate service for a grace period of five business days after receiving either verbal or written notification of the existence of a medical condition or emergency that requires electricity to continue to be provided. The utility must reinstate service during the same day if the customer contacts the utility prior to the close of the business day and requests a same-day reconnection. Otherwise, the utility must restore service by 12:00 p.m. the next business day. When service is reinstated the utility will not require payment of a reconnection charge and/or deposit prior to reinstating service but must bill all such charges on the customer's next regular bill or on a separate invoice.
(a) The utility may require that the customer, within five business days, submit written electronic or paper certification from a qualified medical professional stating that the disconnection of electric service would aggravate an existing medical condition of an occupant of the household. "Qualified medical professional" means a licensed physician, nurse practitioner, or physician's assistant authorized to diagnose and treat the medical condition without supervision of a physician. Nothing in this section precludes a utility from accepting other forms of certification, but the most the utility can require is written electronic or paper certification. If the utility requires such written certification, it may not require more than the following information:
(i) Residence location;
(ii) An explanation of how the current medical condition will be aggravated by disconnection of service;
(iii) A statement of how long the condition is expected to last; and
(iv) The title, signature, and telephone number of the person certifying the condition.
(b) The medical certification is valid only for the length of time the health endangerment is certified to exist but no longer than sixty days, unless renewed.
(c) A medical emergency does not excuse a customer from having to pay delinquent and ongoing charges. The utility may require the customer to do the following within a five business day grace period:
(i) Pay a minimum of ten percent of the delinquent balance;
(ii) Enter into an agreement to pay the remaining delinquent balance within one hundred twenty days; and
(iii) Agree to pay subsequent bills when due. Nothing in this section precludes the utility from agreeing to an alternate payment plan, but the utility must not require the customer to pay more than this subsection prescribes. The utility must send a notice to the customer confirming the payment arrangements within two business days of having reached the agreement.
(d) If the customer fails to provide a medical certificate in accordance with (a) of this subsection or ten percent of the delinquent balance within the five business days grace period, or if the customer fails to abide by the terms of the payment agreement, the utility may disconnect service after complying with the notice requirements in subsection (4)(a)(ii) of this section. If the utility previously provided a second disconnection notice to the customer, the utility must provide an additional second disconnection notice in compliance with the notice requirements in subsection (4)(a)(ii) of this section.
(9) Payments at a payment agency. Payment of any past-due amounts to a designated payment agency of the utility constitutes payment when the customer informs the utility of the payment and the utility has verified the payment. The utility must promptly verify the payment upon notification from the customer.
(10) Remedy and appeals. A utility may not disconnect service while the customer is pursuing any remedy or appeal provided by these rules or while engaged in discussions with the utility's representatives or with the commission. Any amounts not in dispute must be paid when due and any conditions posing a danger to health, safety, or property must be corrected. The utility must inform the customer of these provisions when referring the customer to a utility supervisor or to the commission.
(11) Disconnecting service during inclement weather. A utility must establish conditions in its tariff(s) under which the utility will cease nonvoluntary service disconnections during inclement weather events.
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapter 80.28 RCW. WSR 20-16-077 (Docket U-180525, General Order R-600), § 480-100-128, filed 7/29/20, effective 8/29/20. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-128, filed 5/3/01, effective 6/3/01.]


PDF480-100-133

Reconnecting service after disconnection.

(1) A utility must make every reasonable effort to restore a disconnected service within twenty-four hours, or within four hours for customers who the utility has remotely disconnected, or other time mutually agreeable between the customer and the company, after the customer has paid, or at the time the utility has agreed to bill, any applicable reconnection charge, and:
(a) The causes for disconnection not related to a delinquent account are removed and the customer pays any delinquent tariffed charges, plus any required deposit; or
(b) The customer has entered into an agreed-upon payment arrangement for a delinquent account and pays any required deposit as defined in WAC 480-100-113 Residential service deposit requirements or WAC 480-100-118 Nonresidential service deposit requirements; or
(c) The customer has paid all tariffed amounts due on the account that is not a prior obligation and the customer has paid any required deposit as defined in WAC 480-100-113 Residential service deposit requirements or WAC 480-100-118 Nonresidential service deposit requirements.
(2) If a site visit is not required to reconnect service, the utility may not charge any fees for the reconnection.
(3) The commission may require reconnection pending resolution of any dispute between the utility and the customer over the propriety of disconnection.
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapter 80.28 RCW. WSR 20-16-077 (Docket U-180525, General Order R-600), § 480-100-133, filed 7/29/20, effective 8/29/20. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-133, filed 5/3/01, effective 6/3/01.]


PDF480-100-138

Payment arrangements.

(1) If an electric utility is delayed in billing a residential customer, the utility must offer payment arrangements that are equal to the length of time the bill was delayed, unless the utility determines the customer used service prior to applying for service as outlined in WAC 480-100-128 (2)(f), Disconnection of service.
(2) The utility must offer all residential customers the option of an equal-payments plan.
(a) An equal-payments plan allows the customer to pay the same amount each month based on historical usage. If historical information is not available, the utility must base the amount on projected usage;
(b) The utility may refuse to offer an equal-payments plan to customers who have been removed from the equal-payments plan for nonpayment within the past six months or have more than a two-month past-due balance on their current account. However, the utility may offer the equal-payments plan to any customer when the utility believes this would be in the best interest of all parties concerned;
(3) The utility must provide a receipt to customers for all payments made in cash.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-138, filed 5/3/01, effective 6/3/01.]


PDF480-100-143

Winter low-income payment program.

(1) During the winter months, between November 15th and March 15th, an electric utility may not discontinue residential space heating service if the customer does all of the following:
(a) Notifies the utility of the inability to pay the bill and any required deposit. This notice should be provided within five business days of receiving a delinquency notice unless there are extenuating circumstances. If the customer does not notify the utility within five business days and service is disconnected, the customer can receive the protections of this chapter, by paying reconnection charges, if any, and by otherwise fulfilling the requirements of this section;
(b) Provides self-certification of household income for the prior twelve months to a grantee of the department of community, trade, and economic development or its successor. For the purposes of this section, the grantee is a contractor operating low-income energy assistance programs for the department of community, trade, and economic development. The grantee will determine that the household income is not higher than the maximum allowed for eligibility under the state's plan for low-income energy assistance. The grantee will, within thirty days, provide a dollar figure to the utility that is seven percent of the household income. For the purposes of this section, household income is defined as the total income of all household members as determined by the grantee. The grantee may verify information provided in the self-certification;
(c) Applies for home energy assistance from appropriate government and/or private sector organizations and certifies that any assistance received will be applied to the customer's current and future utility bills;
(d) Applies to the utility or other appropriate agencies for low-income weatherization assistance if such assistance is available for the dwelling;
(e) Agrees and abides by that agreement to:
(i) Pay by the following October 15th all amounts owed to the utility and pay for continued service; and
(ii) Pay a monthly payment during the winter period. The utility may not require payment of more than seven percent of the customer's monthly income. In addition, the customer must pay one-twelfth of any billings from the date application is made through March 15th. A customer may agree to pay a higher percentage of income during this period, but the customer's account will not be considered past-due unless payment during this period is less than seven percent of the monthly income plus one-twelfth of any past-due amounts accrued from the date application is made and thereafter. If the customer does not pay the past-due bill by the following October 15th, the customer will not be eligible for protections under this section until the past-due bill is paid;
(f) Notifies and provides documentation to the utility, if requested, that the customer has received any home heating assistance payment from government and/or private sector organizations after being approved for the plan. When the utility receives this information it must recalculate the payments for the customer; and
(g) Pays all amounts owed even if the customer moves.
(2) The utility:
(a) Must help the customer to fulfill the requirements under this section;
(b) Must transfer an account to a new residence when a customer who has established a plan under this section moves from one residence to another within the utility's service area;
(c) May disconnect service in accordance with WAC 480-100-128, Disconnection of service, if the customer has not kept the payment arrangements as described in subsection (1) of this section. The utility must include in the customer's disconnection notice:
(i) A description of the customer's duties outlined in subsection (1) of this section; and
(ii) An explanation that the utility must restore service if the customer contacts the utility and satisfies the other requirements of this section;
(d) May disconnect service for practices authorized by law other than for nonpayment as stated in this section;
(e) Must allow customers who qualified under subsection (1) of this section and who default on their payment plan and are disconnected in accordance with WAC 480-100-128, Disconnection of service, to reconnect and maintain the protection afforded under this chapter when the customer:
(i) Pays any reconnection charges; and
(ii) Pays all amounts that would have been due and owing on the date the service is reconnected; and
(f) Must provide a written copy of the extended payment plan to the customer.
(3) Any customer who has a past-due amount owing under this payment plan will not be eligible to reapply for a new extended payment plan unless authorized by the utility.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-143, filed 5/3/01, effective 6/3/01.]


PDF480-100-148

Service responsibility.

(1) Customer responsibility. The customer must notify the electric utility, in writing, prior to all changes to the customer's equipment or usage that will materially affect the service to be rendered. The customer must give such notice within a reasonable time so the utility can provide the necessary facilities and acquire additional power supply, if needed. The charge for such necessary facilities, if any, must be in accordance with the utility's filed tariff.
(2) Electric utility responsibility. Each electric utility:
(a) Must install and maintain monitoring equipment at appropriate locations within its system in order to determine the operating characteristics of the system. The commission may require the utility to provide additional equipment in connection with performing special investigations, if economically feasible;
(b) Must promptly notify all affected customers of any substantial change to the service that would affect the efficiency of operation or the adjustment of the customer's equipment. If an adjustment to the customer's equipment is necessary, the cost may be recovered in accordance with the utility's tariff, except that, when the customer has been notified of a change in service prior to receiving service or when such change is required by law, the customer must bear all costs in connection with making changes to the customer's own equipment.
(c) Must maintain its plant in such a condition that will enable it to furnish safe, adequate, and efficient service.
(d) Must make those efforts that are reasonable under the circumstances to avoid interruptions of service and, when such interruptions occur, to reestablish service with a minimum of delay. Interruptions as used in this subsection do not refer to the discontinuance of service to those customers receiving service under an interruptible service schedule.
When it is necessary for an electric utility to make repairs to or to change its facilities, the utility may, without incurring any liability, suspend service for such periods as may be reasonably necessary and in such a manner as to minimize the inconvenience to customers. When practicable, such interruption will be during the working hours regularly maintained by the utility. The utility must individually notify police and fire departments affected by such a suspension. All customers affected by a scheduled interruption associated with facilities other than meters, will be given notification through newspapers, radio announcements, or other means at least one day in advance.
(e) Must keep a record of all interruptions of service affecting a substantial number of customers, including in such record the location, the date and time, the duration, and, as accurately as possible, the cause of each interruption. Utilities must submit copies of such records to the commission upon request.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 02-21-066 (Docket No. A-020405, General Order No. R-504), § 480-100-148, filed 10/16/02, effective 11/16/02. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-148, filed 5/3/01, effective 6/3/01.]


PDF480-100-153

Protection and disclosure of customer information.

(1) A utility must use reasonable security practices and procedures to safeguard all customer information within the utility's possession or control from unauthorized access or disclosure.
(2) A utility may only collect and retain customer information that is reasonably necessary for the utility to perform duties directly related to the utility's primary purpose unless the utility has first obtained the customer's written consent to collect and retain customer information for another purpose.
(3) A utility may disclose customer information without written customer consent to an affiliate, subsidiary, or parent organization only to the extent necessary for the utility to perform duties directly related to the utility's primary purpose. The utility must obtain the customer's written consent to disclose customer information to an affiliate, subsidiary, or parent organization for any other purpose.
(4) A utility may disclose customer information to third parties only to the extent necessary for the utility to perform duties directly related to the utility's primary purpose unless the utility has first obtained the customer's written consent to disclose customer information to third parties for other specified purposes. The utility must require all third parties to which it provides access to customer information to have policies, procedures, and technological safeguards in place to protect customer information that are no less stringent than the utility's own standards.
(5) A utility is ultimately responsible for safeguarding customer information. The utility must ensure that it has and enforces contractual obligations with third parties, affiliates, subsidiaries, and parent organizations that require such entities to have and comply with policies, procedures, and technological safeguards sufficient to prevent the misuse or improper or unauthorized disclosure of customer information.
(6) A utility may not sell customer information. A utility may not otherwise disclose customer information except as provided in this rule. A utility may not disclose customer information to its affiliates, subsidiaries, parent organization, or any other third party for the purposes of marketing services or product offerings to a customer who does not already subscribe to that service or product, unless the utility has first obtained the customer's written consent. The utility must maintain a record of each customer's written consent as required in subsection (9) of this section.
(7) Nothing in this rule may be construed to preclude the utility from complying with demands for customer information as required by law, such as through a warrant or subpoena.
(8) If a customer discloses or directs the utility to disclose customer information to a third party other than in response to a request or requirement of the utility, the utility will not be responsible for the security of that information or its use or misuse by that third party.
(9) The utility must retain the following information for each written consent a customer gives to the utility for disclosure of customer information:
(a) The date and customer confirmation of consent to disclose customer information;
(b) A list of the affiliates, subsidiaries, parent organizations, or third parties to which the customer has authorized the utility to disclose customer information;
(c) Information provided to the customer about how the customer can revoke consent; and
(d) Verification that the consenting customer's name, service address, and account number match the utility record for such account.
(10) Subject to agreements a customer has made with third parties, a customer has the right to revoke, at any time, any previously granted consent for the utility to disclose customer information in the future to an affiliate, subsidiary, parent organization, or third party for purposes that are not necessary for the utility to perform duties directly related to the utility's primary purpose. The utility may require that any such revocation not be effective until up to ten business days after the customer submits that revocation to the utility.
(11) The utility must post and maintain its privacy policy on its website in a prominent location.
(a) The utility must notify new customers how they can access a copy of the utility's privacy policy upon initiating utility service.
(b) Whenever the utility amends its privacy policy it must notify existing customers by whatever method the utility uses to transmit the customers' bills.
(c) The utility must provide a written copy of its privacy policy upon customer request.
(d) Any notice regarding the utility's privacy policy must include a customer service phone number and website address where customers can direct additional questions or obtain additional information.
(12) This section does not prevent disclosure of the essential terms and conditions of special contracts as provided in WAC 480-80-143 Special contracts for gas, electric, and water companies.
(13) This section does not prevent the utility or its approved third parties from inserting any marketing information into the customer's billing package.
(14) The utility must provide a user-friendly website interface through which customers may access their own account and usage information without charge. The utility may implement reasonable procedures to verify the customer's identity before providing access to customer account and usage information through this interface.
(15) The utility must make a reasonable effort to respond to requests from customers for their own account and usage information within ten business days of the customer request.
(16) The utility must ensure that the information it collects, stores, uses, and discloses is reasonably accurate and complete and otherwise complies with applicable rules and tariffs regarding the quality of energy usage data.
(17) Each customer must have the opportunity to dispute the accuracy or completeness of the customer account and usage information the utility has collected for that customer. The utility must provide adequate procedures for customers to dispute the accuracy of their customer account and usage information and to request appropriate corrections or amendments.
(18) The utility must take all reasonable steps to destroy, or arrange for the destruction of, customer information in accordance with the utility's data retention policies and practices.
(19) The utility must notify customers of any security breach involving disclosure of personal information as defined in RCW 19.255.010 in accordance with that statute. If a security breach involves disclosure of customer information other than personal information as defined in RCW 19.255.010, the utility shall notify customers and the commission as soon as practicable of the breach and the measures the utility is taking to remedy the breach. The utility must take all reasonable measures including, but not limited to, cooperating fully with law enforcement agencies, to recover lost information and prevent the loss of further customer information.
(20) The utility must review at least annually the type of customer information the utility has collected and ensure collection and retention of that information is reasonably necessary for the utility to perform duties directly related to the utility's primary purpose or other purpose to which the customer has consented to the utility collecting that information.
(21) The utility may collect and release aggregate data to the extent reasonably necessary for the utility to perform duties directly related to the utility's primary purpose. The utility may collect and release aggregate data on energy usage to the extent necessary to comply with legal requirements, or to facilitate voluntary efforts, to promote energy efficiency, conservation, or generating resource management. The utility must have sufficient policies, procedures, and safeguards in place to ensure that any release of aggregate data does not allow any specific customer or customer information to be identified.
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapter 80.28 RCW. WSR 20-16-077 (Docket U-180525, General Order R-600), § 480-100-153, filed 7/29/20, effective 8/29/20. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 11-06-032 (Docket U-100523, General Order R-563), § 480-100-153, filed 2/25/11, effective 3/28/11. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.353. WSR 03-22-046 (Docket No. A-030832, General Order No. R-509), § 480-100-153, filed 10/29/03, effective 11/29/03. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-20-060 (Docket No. UE-990473, General Order No. R-489), § 480-100-153, filed 9/28/01, effective 10/29/01.]


PDF480-100-163

Service entrance facilities.

(1) An electric utility may require customers to:
(a) Provide service entrance facilities at the easiest access point to the utility's distribution system; and
(b) Comply with reasonable requirements to keep those facilities free from tampering or interference.
(2) In order to permit the required clearances, utilities may require their customers to provide a structurally sound point of attachment for the utility's service conductors pursuant to the National Electrical Code. Information about the National Electrical Code regarding the version adopted and where to obtain it is set out in WAC 480-100-999 Adoption by reference.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 02-18-033 (Docket No. A-020379, General Order No. R-501), § 480-100-163, filed 8/26/02, effective 9/26/02. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-163, filed 5/3/01, effective 6/3/01.]


PDF480-100-168

Access to premises; identification.

(1) Authorized representatives of an electric utility have the right to enter a customer's property during reasonable hours to perform necessary functions such as meter reading, maintenance, repairs, testing, installation, or removal of the utility's property. Utilities must provide photo identification to utility representatives who are authorized to enter customers' premises. Customers have the right to see the utility-provided identification of electric utility representatives before allowing entry to the customer's property.
(2) When performing maintenance, repairs, testing, installation, or removal of the utility's property, the utility must restore the customer's property as close as reasonably practicable to the condition prior to the utility's action, unless otherwise defined in the utility's tariff or through a separate agreement with the customer.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-168, filed 5/3/01, effective 6/3/01.]


PDF480-100-173

Electric utility responsibility for complaints and disputes.

(1) When an electric utility receives a complaint from a customer or an applicant for service, the utility must acknowledge receipt of the complaint and:
(a) Upon request, identify the utility's contact to the complainant;
(b) Investigate the complaint promptly as required by the particular case;
(c) Report the results of the investigation to the complainant;
(d) Take corrective action, if warranted, as soon as possible under the circumstances;
(e) If the complainant is dissatisfied with the results or decision, inform the complainant that the decision may be appealed to a supervisor at the utility; and
(f) If the complainant is dissatisfied after speaking with the utility's supervisor, the supervisor must inform the complainant of the complainant's right to file a complaint with the commission and provide the commission's address and toll-free telephone number.
(2) Applicants, customers, or their representatives may file with the commission:
(a) An informal complaint as described in WAC 480-07-910, Informal complaints; or
(b) A formal complaint against the utility as described in WAC 480-07-370, Pleadings—General.
(3) When the commission refers an informal complaint to the utility, the utility must:
(a) Investigate and report the results to the commission within two business days. The commission may grant an extension of time for responding to the complaint, if requested and warranted;
(b) Keep the commission informed of progress toward the solution and the final result; and
(c) Respond to the commission's request for additional informal complaint information within three business days of the request or at a date specified by the commission. The commission may grant an extension of time for responding to the complaint, if requested and warranted.
(4) Each electric utility must keep a record of all complaints for at least three years and, upon request, make them readily available for commission review. The record must contain:
(a) The complainant's name and address;
(b) The date and nature of the complaint;
(c) The action taken;
(d) The final result; and
(e) All official documents regarding the complaint.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 03-24-028 (General Order R-510, Docket No. A-010648), § 480-100-173, filed 11/24/03, effective 1/1/04; WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-173, filed 5/3/01, effective 6/3/01.]


PDF480-100-178

Billing requirements and payment date.

(1) Customer bills must:
(a) Be issued at intervals not to exceed two one-month billing cycles, unless the utility can show good cause for delaying the issuance of the bill. The utility must be able to show good cause if requested by the commission;
(b) Show the total amount due and payable;
(c) Show the date the bill becomes delinquent if not paid;
(d) Show the utility's business address, business hours, and a toll-free telephone number and an emergency telephone number by which a customer may contact the utility;
(e) Show the beginning and ending meter readings for the current billing period, the current monthly or bimonthly read date, as applicable, and the total amount of kilowatt hours used for the billing cycle, provided that the customer bill must provide the meter readings and read date for the final reading for the applicable monthly or bimonthly billing cycle; the bill need not include interval readings, although the utility must provide customers with access to their usage data in accordance with WAC 480-100-153;
(f) Show the amount of kilowatt hours used for each billing rate, the applicable billing rates per kilowatt hour, the basic charge or minimum bill;
(g) Show the amount of any municipal tax surcharges or their respective percentage rates, if applicable;
(h) Clearly identify when a bill has been prorated. A prorated bill must be issued when service is provided for a fraction of the billing period. Unless otherwise specified in the utility's tariff, the charge must be prorated in the following manner:
(i) Flat-rate service must be prorated on the basis of the proportionate part of the period the service was rendered;
(ii) Metered service must be billed for the amount metered. The basic or minimum charge must be billed in full.
(i) Clearly identify when a bill is based on an estimation.
(i) The utility must detail its method(s) for estimating customer bills in its tariff;
(ii) The utility may not estimate for more than four consecutive months, unless the cause of the estimation is inclement weather, terrain, or a previous arrangement with the customer;
(j) Clearly identify determination of maximum demand. A utility providing service to any customer on a demand basis must detail in its filed tariff the method of applying charges and of ascertaining the demand.
(2) The minimum time allowed for payment after the bill's mailing date must be fifteen days, if mailed from within the states of Washington, Oregon, or Idaho, or eighteen days if mailed from outside the states of Washington, Oregon, and Idaho.
(3) The utility must allow a customer to change a designated payment-due date when the customer has a satisfactory reason for the change. A satisfactory reason may include, but is not limited to, adjustment of a designated payment-due date to parallel receipt of income. The preferred payment date must be prior to the next billing date.
(4) With the consent of the customer, a utility may provide billings in electronic form if the bill meets all the requirements for the use of electronic information in this chapter. The utility must maintain a record of the consent as a part of the customer's account record, and the customer may change from electronic to printed billing upon request, as provided in this chapter. The utility must complete the change within two billing cycles of the request.
(5) Corrected bills:
(a) A utility must issue a corrected bill upon finding that an underbilling or overbilling occurred as a result of a meter failure, meter malfunction, meter with unassigned energy usage, or any other situation where energy usage was not billed or was inaccurately billed. The utility must use the rates and rate schedule in effect during the billing period(s) covered by the corrected bill. The utility must issue the corrected bill within sixty days from the date the utility discovered that an account had been underbilled or overbilled. Except as provided in subsection (7) of this section, when a utility's investigation finds that it has underbilled energy usage, it may not collect underbilled amounts for any period greater than six months from the date the error occurred. The maximum period for which utilities are required to adjust bills for overbilling is six years.
(b) For the purposes of this rule:
(i) A meter failure or malfunction is defined as: A mechanical malfunction or failure that prevents the meter or any ancillary data collection or transmission device from registering or transmitting the actual amount of energy used. A meter failure or malfunction includes, but is not limited to, a stopped meter, a meter that is faster or slower than the metering tolerance specified in WAC 480-100-338, or an erratic meter.
(ii) An unassigned energy usage meter is defined as a meter that is installed at a valid service address and accurately records energy usage during a period of time where there was no active electric service account at that premises.
(c) A utility must develop and maintain procedures that establish practices for the prompt identification, repair and replacement of meters that are not functioning correctly and for identification of unassigned usage meters. The objective of such procedures shall be to mitigate the number of underbilling occurrences that exceed six months in duration. These procedures must address, at a minimum:
(i) Practices to prevent the issuance of corrected bills due to incorrect prorated bills, improperly assigned meters, incorrectly installed meters, incorrect billing rate schedules, incorrect billing multipliers, or any other event that may affect billing accuracy.
(ii) Processes for the investigation of meter issues include, but are not limited to, stopped, slowed, and erratic usage meters.
(iii) Processes for the investigation of meter usage from unidentified usage meters.
(6) For the purpose of this rule, a corrected bill may take the form of a newly issued bill or may be reflected as a line item adjustment on a subsequent monthly or bimonthly bill. When a corrected bill is issued, the utility must provide the following information on the corrected bill, in a bill insert, letter, or any combination of methods that clearly explains all the information required to be sent to the customer:
(a) The reason for the bill correction;
(b) A breakdown of the bill correction for each month included in the corrected bill;
(c) The total amount of the bill correction that is due and payable;
(d) The time period covered by the bill correction; and
(e) When issuing a corrected bill for underbilling, an explanation of the availability of payment arrangements in accordance with WAC 480-100-138(1) payment arrangements.
(7) Exceptions to billing correction rules:
(a) Corrected bills related to an underbilling due to tampering or interference with the utility's property, use of the utility's service through an illegal connection, or the fraudulent use of a utility's service, are exempt from the six-month restriction set forth in subsection (5)(a) of this section.
(b) Adjustments for underbilling of nonresidential customers will be limited to six months. However, the utility may extend this period for good cause if a longer period is appropriate due to circumstances such as the complexity of specific accounts, changing metering configurations, load changes of large industrial customers, special meter configuration involving current transformers, or wiring reconfiguration by the customer. Utilities must report to the commission within sixty days the reasons for any adjustments longer than six months.
(c) The utility may choose not to issue a corrected bill to recover underbilled amounts less than fifty dollars.
(8) An estimated meter read made in accordance with subsection (1)(i) of this section is not considered a meter failure or malfunction or a situation where energy usage was inaccurately billed. A bill true-up (correction) based on an actual meter reading after one or more estimated bills is not considered a corrected bill for purposes of subsection (5)(a) of this section.
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapter 80.28 RCW. WSR 20-16-077 (Docket U-180525, General Order R-600), § 480-100-178, filed 7/29/20, effective 8/29/20. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 16-06-038 (Docket U-144155, General Order R-586), § 480-100-178, filed 2/23/16, effective 3/25/16; WSR 11-06-032 (Docket U-100523, General Order R-563), § 480-100-178, filed 2/25/11, effective 3/28/11; WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-178, filed 5/3/01, effective 6/3/01.]


PDF480-100-179

Electronic information.

With the prior consent (as defined in subsection (2) of this section) of the customer or applicant, a utility may provide the following by electronic means, instead of in paper copy sent to the customer's mailing address:
• Bills;
• Notices of tariff revisions; and
• Bill inserts containing information required to be provided to customers or applicants by statute, rule, or commission order.
The provision of this electronic information to a customer will be considered compliant with any statute, rule, commission order, or tariff provision that refers to the mailing of bills, notices of tariff revisions or bill inserts when a customer has consented to receive the information in electronic form as agreed to by the customer. The electronic form must provide a link to the electronic information, or otherwise advise the customer of the electronic location of such information.
(1) Format of electronic communications. All information provided in electronic form must meet the requirements for format, due dates, calculation of due dates, minimum time frames, and any other requirements specified in this chapter. Electronic information will be treated the same as documents that are mailed from a location within the state of Washington for the purposes of calculating due dates and minimum time frames.
(2) Obtaining and documenting customer consent. The utility must obtain prior written or electronic consent to provide bills, notices of tariff revisions and bill inserts in electronic form (customer consent). The customer consent must be obtained directly from the customer of record and comply with the following:
(a) The consent section on the document, screen, or web page may also offer the customer separate, individual opportunities to consent to:
(i) Paperless billing offered by the utility.
(ii) Automatic payment services offered by the utility, including one-time payment services or other automatic payment services.
(iii) Equal payment plan.
For electronic consent, the customer consent section must be prominent on the web page and clearly distinguishable from any other content on the screen or page. No information other than as provided in this section, may be combined in the same customer consent section except utility contact information. The consent section must not have consent boxes or spaces already filled in. The customer must personally check each box or space giving his or her consent to one or more services. Each service requires a separate, affirmative consent.
(b) The utility must retain a record of the customer's consent to receive electronic communications as a part of the customer's account records as evidence of the customer's consent to receive selected documents in electronic form, or to participate in paperless billing service.
(c) Documentation of the customer consent must be made available to the customer and to the commission at no charge, if requested.
(d) At a minimum, the customer consent must include the following:
(i) The name, service address, and account number that exactly matches the utility record for such account;
(ii) The customer's opt-in decision to receive electronic information;
(iii) Confirmation that the customer understands the utility will provide, upon request but subject to the limitations in this section, a paper copy of any document sent electronically at no additional charge and that the customer may opt out of receiving information electronically at any time and revert to paper format through the mail at no additional charge;
(iv) Confirmation that the customer understands it is their responsibility to notify the utility of any change to their email or other electronic address; and
(v) Confirmation that the customer understands that in addition to the paperless bills they may receive all notices regarding service, including notices of the utility's request to increase rates and changes in service, in electronic form.
(3) Distribution of electronic notices.
(a) Electronic notices of proposed tariff changes, including increased rates or restriction of access to services, and public hearings will be marked prominently "important notice regarding your electric service." (Note: For combined service customers the caption must read "electric and gas services.")
(b) If the utility elects to send the notices of proposed tariff changes or public hearings separate from the bill, it will also include a copy of the electronic notice with the electronic bill as an attachment or link. The attachment or link will include the electronic address designated by the commission where customers may file public comment(s) regarding the proposed tariff changes or restriction of access to service.
(4) Documents requiring paper delivery. The following documents may not be provided solely by electronic means:
(a) Notices of disconnection; and
(b) Information regarding the winter moratorium on disconnection of low-income heating customers, including written copies, if any, of extended payment plans under the winter low-income payment program.
(5) Limit on changes to information format. A utility is not obligated to provide both paper documents and electronic information to a customer on a continuous basis. A utility may limit a customer who has consented to electronic delivery to three requests for paper documents in a twelve-month period. A utility may require that a customer who requests an electronic bill also receive all bill inserts electronically. If a customer is unable to properly receive, view or understand electronic information provided by the utility, the utility may refuse to provide that information in electronic form.
(6) Specialized electronic format. When a utility provides electronic billing information in a specialized format, such as, but not limited to, the electronic data interchange (EDI), where the utility incurs a cost that is offset by not sending statements using mail, the utility may offer customers the choice of the specialized format or paper bill. In the event of a disputed bill, the customer may request and the utility shall provide customers receiving bills in a specialized format with billing details understandable by a person who will be reviewing the bills.
(7) Undeliverable electronic information.
(a) If any electronic information allowed in this rule is returned to the utility as undeliverable or the utility is made aware by other means that such electronic information did not reach the customer, the utility must take the following steps to ascertain and correct the problem causing the return of the information as undeliverable. It must, within the time specified in (c) of this subsection, either resend the electronic information to the customer-provided electronic address or contact the customer by telephone.
(b) If the utility fails to correct the problem within the required time, it must send the customer the information by mail and return the customer to mail notification. It also must include in the mailed information an explanation that the email address or other electronic address is not functioning and indicate that future information will be sent via mail until the customer provides to the utility a functioning email or other functioning electronic address.
(c) The utility must take steps required in (a) and (b) of this subsection by either:
(i) The business day following the receipt of the undeliverable message; or
(ii) If the utility extends the bill due date by five business days, within five business days.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 11-06-032 (Docket U-100523, General Order R-563), § 480-100-179, filed 2/25/11, effective 3/28/11.]


PDF480-100-183

Complaint meter tests.

(1) An electric utility must test and report to the customer the accuracy of a meter within twenty business days after receiving an initial request from a customer. The utility must allow the customer to order one meter test free of charge during a twelve-month period. The utility may appeal to the commission to waive the responsibility of performing the meter test, to request an extension to perform the meter test, or to be allowed to charge for the meter test. If the customer disputes the accuracy of the meter, the customer must allow the utility access for meter testing.
(2) The customer may, at the customer's option, either witness the meter test or designate a representative to witness the test. The customer may require the meter to be sealed upon removal in the presence of the customer or the customer's representative. The seal must not be broken until the test is made in the presence of the customer or the customer's representative, or until permission to break the seal has been granted by the commission. The utility must report the results of the meter test to the customer.
(3) A customer may request the utility to perform additional meter tests within twelve months of the last meter test, but additional meter tests will not delay disconnection of service under WAC 480-100-128(9), Disconnection of service. The utility must immediately inform the customer of any additional meter test charges. If the customer elects to have the meter test performed, the utility must perform the test and report the test results to the customer within twenty business days. If the additional meter test results show the meter is performing accurately as defined in WAC 480-100-338, Accuracy requirements for electric meters, the utility may charge the customer for performing the additional meter tests. The charge of the meter test must be listed in the utility's tariff. The utility may not charge the customer for any additional meter test that shows the meter is performing outside acceptable tolerance levels as defined in WAC 480-100-338, Accuracy requirements for electric meters.
(4) If the customer disputes any meter test result, the utility or the customer may contact the commission to review the complaint. When the commission has notified the utility that a complaint has been received regarding the customer's meter, the utility may not change the meter in any manner unless authorized by the commission. If the utility violates this provision, the commission may consider it as supporting the customer's dispute since the change might affect the proof of the dispute. The commission may require the utility to perform an additional test and report the test results to the commission within ten business days.
(5) If a meter test reveals a meter error greater than specified as acceptable in WAC 480-100-338, Accuracy requirements for electric meters, the utility must repair or replace the meter at no cost to the customer. The utility must adjust the bills to the customer based on the best information available to determine the appropriate charges. The utility must offer payment arrangements in accordance with WAC 480-100-138(2), Payment arrangements.
(a) If the utility can identify the date the customer was first billed from a defective meter, the utility must refund or bill the customer for the proper usage from that date;
(b) If the utility cannot identify the date the customer was first billed from a defective meter, the utility must refund or bill the customer for the proper usage, not to exceed six months.
(6) Reports. The commission may require the utility to provide meter test results to the commission in response to a customer's complaint. These reports must contain the name or address of the customer, the meter manufacturer's name, the manufacturer's and utility's meter number, the size or capacity of the meter, the date the meter was tested, the reading of the meter when tested, the accuracy of the meter as found, and the accuracy of the meter after adjustment.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-183, filed 5/3/01, effective 6/3/01.]


PDF480-100-188

Payment locations.

(1) An electric utility must provide payment agencies in locally accessible locations where applicants and customers can make payments at no charge to the applicants and customers. Payment agencies must clearly post and maintain regular business hours.
(2) The utility and its payment agencies must provide receipts for any cash payments made by applicants or customers.
(3) The utility must provide written or electronic notice to the commission's consumer affairs section at least thirty days prior to the closing of any business office, customer service center, or payment agency. In the event that a payment agency is closed on less than thirty days' notice, written or electronic notification is required as soon as the utility becomes aware of the closure. At a minimum, the following information is required:
(a) The communities affected by the closing;
(b) The date of the closing;
(c) A listing of other methods and facility locations available for payment of cash or urgent payments; and
(d) A listing of other methods and locations for obtaining business office and customer service center services.
(4) The utility must include on its regularly scheduled bills a statement referring its customers to a toll-free number for updated payment agency locations.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-188, filed 5/3/01, effective 6/3/01.]


PDF480-100-193

Posting of tariffs for public inspection and review.

Each electric utility offering service under tariff must make available for public inspection and review all tariffs governing its provision of service, as required by RCW 80.28.050. To comply with this requirement, a utility must fulfill the provisions of either subsection (1) or (2) of this section.
(1) Web, telephone, and mail access. The utility must:
(a) Maintain a complete copy of its tariff or tariffs and all proposed tariff changes on an Internet website accessible to the public using generally available browser software;
(b) Provide a toll-free telephone number by which customers and applicants can obtain assistance during normal business hours from a company agent qualified to assist the customer in locating, interpreting, and applying tariff provisions;
(c) Upon written or oral request by any customer or applicant, deliver at no charge a copy of any current, proposed or most recently canceled tariff page that relates to the customer's or applicant's service; and
(d) Include on each customer bill and notice the address of the tariff website and the toll-free telephone number.
(2) Physical access. The utility must make available for public inspection and copying a complete copy of its tariff or tariffs, all most recently canceled tariff sheets, and all proposed tariff changes at one or more offices in each county where it offers service, except that: A single office may serve more than one county if the office is within twenty miles of all customers in the county where no tariff is posted. The utility must provide at each office either an agent qualified to assist the customer in locating, interpreting, and applying tariff provisions or access to such an agent by a toll-free telephone number.
[Statutory Authority: RCW 80.01.040 and 80.04.180. WSR 02-11-081 (Docket No. U-991301, General Order No. R-498), § 480-100-193, filed 5/14/02, effective 6/17/02. Statutory Authority: RCW 80.04.160 and 80.01.040. WSR 01-09-002 (Docket No. U-991301, General Order No. R-481), § 480-100-193, filed 4/4/01, effective 5/5/01.]


PDF480-100-194

Publication of proposed tariff changes to increase charges or restrict access to services.

Each electric utility offering service under tariff must publish or provide electronically all proposed changes to its tariff for at least thirty days, as required by RCW 80.28.060. For any proposed tariff change that would increase recurring or per-occurrence charges or restrict access to services (e.g., discontinue a service, or limit access to service by imposing a new usage level on existing services), a utility must fulfill the requirements of subsection (1), (2), or (3) of this section. For any other proposed tariffs, the utility must fulfill the requirements of WAC 480-100-195. The utility will not be required to accomplish publication under this section if it has agreed to suspend its tariff filing and to provide notice as provided under WAC 480-100-197. The utility may provide the information in an electronic format consistent with provisions in this chapter governing the use of electronic information.
(1) Thirty-day notice to individual customers. To comply under this method, the utility must, at least thirty days before the stated effective date of the proposed change, mail or provide electronically the posting to each customer that would be affected by the proposed change. The posting must include the information listed in subsection (4) of this section. The utility may provide this information in an electronic format consistent with provisions in this chapter governing the use of electronic information.
(2) Published notice. To comply under this method, the utility must, at least thirty days before the stated effective date of the proposed change, publish notice of the proposed change within the geographical areas where it offers service. To meet minimum publication requirements, a utility must:
(a) Distribute copies of the published notice to community agencies and organizations in the geographic area where it offers service for posting and publication by the agency or organization. The utility must include in its distribution list any agency or organization that requests these notices;
(b) Cause to be printed in large print, as a paid advertisement, a complete copy of the published notice in the daily newspaper of general circulation with the greatest number of subscribers in each geographic area or each of the areas affected by the proposed tariff;
(c) Provide to the news editor of every newspaper, television station, and radio station in the geographic area within which it offers service a news release or public service announcement summarizing the published notice. The release or announcement must include a toll-free number that customers can use to obtain more information from the electric utility. The commission will maintain a list of area newspapers, television, and radio stations and will provide it on request to any utility; and
(d) Post a complete copy of the published notice on an Internet website accessible to the public using generally available browser software.
(3) Reduced publication with shortened notice to individual customers. To comply under this method, the utility must:
(a) Mail or provide electronically the posting to each customer that would be affected by the proposed change at least fifteen days before the stated effective date of the proposed change. The utility may provide this information in an electronic format consistent with provisions in this chapter governing the use of electronic information;
(b) At the time of the utility's filing with the commission, distribute copies of the published notice in the same manner as provided in subsection (2)(a) of this section;
(c) At the time of the utility's filing with the commission, provide news media notice in the same manner as provided in subsection (2)(c) of this section; and
(d) At the time of the utility's filing with the commission, post a complete copy of the published notice in the same manner as provided in subsection (2)(d) of this section.
(4) Content of postings. The published notice required by this rule must include, when applicable:
(a) The date the notice is issued;
(b) The utility's name and address;
(c) A brief explanation of the reason(s) the utility has requested the rate change (e.g., increase in labor costs, recovery of new plant investment, and increased office expenses, such as postage and customer billing);
(d) A comparison of current and proposed rates by service;
(e) An example showing the monthly increase of the average customer's bill based on the proposed rates (e.g., "based on the proposed rates, a typical electric customer using an average of 1,500 kwhs per month would see an average monthly increase of $10.38.");
(f) When the rates will be billed (i.e., monthly or bimonthly);
(g) The requested effective date and, if different, the implementation date;
(h) A statement that the commission has the authority to set final rates that may vary from the utility's request, which may be either higher or lower depending on the results of the investigation;
(i) A description of how customers may contact the utility if they have specific questions or need additional information about the proposal; and
(j) Public involvement language. A utility may choose from:
(i) Commission-suggested language that is available from the commission's designated public affairs officer; or
(ii) Utility-developed language that must include the commission's mailing address, toll-free number, and docket number, if known, and a brief explanation of:
(A) How to participate in the commission's process by mailing or faxing a letter, or submitting an email; and
(B) How to contact the commission for process questions or to be notified of the scheduled open meeting at which the proposal will be considered by the commission.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 11-06-032 (Docket U-100523, General Order R-563), § 480-100-194, filed 2/25/11, effective 3/28/11. Statutory Authority: RCW 80.01.040 and 80.04.180. WSR 02-11-081 (Docket No. U-991301, General Order No. R-498), § 480-100-194, filed 5/14/02, effective 6/17/02.]


PDF480-100-195

Notice of tariff changes other than increases in recurring charges and restrictions in access to services.

(1) This section applies to tariff changes for other than those that are subject to WAC 480-100-194.
(2) A utility that files a tariff change to increase any charge that a customer may incur without being quoted a rate or price (e.g., late payment fees, insufficient fund charges, or a one-time charge) must provide notice to each affected customer on or with the first bill after the change becomes effective.
(a) At a minimum, the notice must include the effective date, a clear description of changes to rates or services and a utility contact number where customers may seek additional information.
(b) Methods of notice permitted include a bill insert, bill message, printing on the billing envelope, a separate mailing to all affected customers or, if the utility has the capability and the customer has authorized, by email.
(3) A utility that files a tariff change that decreases rates, including promotions that temporarily waive recurring or nonrecurring charges, or that changes terms or conditions without restricting access to the service, must publish the change in the manner it posts tariffs under WAC 480-100-193.
[Statutory Authority: RCW 80.01.040 and 80.04.180. WSR 02-11-081 (Docket No. U-991301, General Order No. R-498), § 480-100-195, filed 5/14/02, effective 6/17/02.]


PDF480-100-197

Adjudicative proceedings where public testimony will be taken.

(1) For adjudicated proceedings, when scheduling a hearing to take testimony from the public, the timing, location, and amount of notice to the public or to customers will be addressed in the prehearing conference order.
(2) The notice must include all information contained in WAC 480-100-194(4), except the public involvement information in WAC 480-100-194 (4)(j). A utility must include either of the following public involvement language:
(a) Commission-suggested language that is available from the commission's designated public affairs officer; or
(b) Utility-developed language that must include the commission's mailing address, toll-free number, docket number, and a brief explanation:
(i) How to participate in the commission's process by mailing or faxing a letter, or submitting an email;
(ii) How to contact the commission for process questions; and
(iii) The date, time and location of the public hearing.
(3) Methods of notice permitted include a bill insert, bill message, printing on the billing envelope, a separate mailing to all affected customers or, if the utility has the capability and the customer has authorized, by email.
(4) In addition to each affected customer, a utility must notify at least one newspaper of general circulation, and at least one radio station and at least one television station in the area or each of the areas affected.
[Statutory Authority: RCW 80.01.040 and 80.04.180. WSR 02-11-081 (Docket No. U-991301, General Order No. R-498), § 480-100-197, filed 5/14/02, effective 6/17/02.]


PDF480-100-198

Notice verification and assistance.

(1) Within ten days of making a filing requiring posting, publication, or customer notice under WAC 480-100-194, 480-100-195, or 480-100-197, but no sooner than when the tariff is filed with the commission, a utility must file a statement with the commission's records center that the required notice has been posted, published, and/or mailed. The declaration must include:
(a) The methods used to post, publish, and/or give notice to customers;
(b) When and how the notice was posted, published, and/or issued to customers;
(c) How many customers are affected; and
(d) A copy of the notice.
(2) A utility may request assistance from the commission's designated public affairs officer with efforts to comply with WAC 480-100-193 through 480-100-197.
[Statutory Authority: RCW 80.01.040 and 80.04.180. WSR 02-11-081 (Docket No. U-991301, General Order No. R-498), § 480-100-198, filed 5/14/02, effective 6/17/02.]


PDF480-100-199

Other customer notice.

The commission may require notice to customers of tariff changes other than those described in these rules when the commission determines that additional customer education is needed.
[Statutory Authority: RCW 80.01.040 and 80.04.180. WSR 02-11-081 (Docket No. U-991301, General Order No. R-498), § 480-100-199, filed 5/14/02, effective 6/17/02.]


PDF480-100-203

Accounting system requirements.

(1) Electric utilities in the state of Washington must use the uniform system of accounts applicable to major and nonmajor electric utilities as published by the Federal Energy Regulatory Commission (FERC) in Title 18 of the Code of Federal Regulations, Part 101. Information about the Code of Federal Regulations regarding the version adopted and where to obtain it is set out in WAC 480-100-999, Adoption by reference.
(2) Electric utilities having multistate operations must maintain records in such detail that the costs of property located and business done in the state of Washington can be readily ascertained in accordance with geographic boundaries.
(3) Any deviation from the uniform system of accounts, as prescribed by the FERC, will be accomplished only after due notice and order of this commission.
(4) This rule does not supersede any commission order regarding accounting treatments.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 02-18-033 (Docket No. A-020379, General Order No. R-501), § 480-100-203, filed 8/26/02, effective 9/26/02. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-203, filed 5/3/01, effective 6/3/01.]


PDF480-100-207

Filing information.

(1) Filing. The commission records center will accept any filing under WAC 480-100-242 (Issuing securities) delivered in person, by mail, telefacsimile, or electronic mail message. The commission records center will accept all other reports required in Part III in person, by mail, or when procedures are in place, electronic mail message.
(2) Commission may require additional information. The commission may require pertinent information in addition to that specified by statute or in this chapter.
(3) Information by reference. When any information required to support a filing is on file with the commission, it is sufficient to make specific reference to the information indicating the proceeding, report, or other filing that contains the referenced information.
(4) When information is unavailable. If any required information is unavailable at the time of the filing, the filing must include the reason why the information is not available and state when it will be available.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 05-17-026 (Docket No. A-021178 and TO-030288, General Order No. R-522), § 480-100-207, filed 8/5/05, effective 9/5/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-207, filed 2/28/05, effective 3/31/05.]


PDF480-100-209

Additional reports.

Part III does not supersede any reporting requirement specified in a commission order or limit the commission's ability to request additional information.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-209, filed 2/28/05, effective 3/31/05.]


PDF480-100-213

Expenditures for political or legislative activities.

(1) The commission will not allow either direct or indirect expenditures for political or legislative activities for rate-making purposes.
(2) For purposes of this rule, political or legislative activities include, but are not limited to:
(a) Encouraging support or opposition to ballot measures, legislation, candidates for a public office, or current public office holders;
(b) Soliciting support for or contributing to political action committees;
(c) Gathering data for mailing lists that are generated for the purposes of encouraging support for or opposition to ballot measures, legislation, candidates for public office, or current office holders, or encouraging support for or contributions to political action committees;
(d) Soliciting contributions or recruiting volunteers to assist in the activities set forth in (a) through (c) of this subsection.
(3) Political or legislative activities do not include activities directly related to appearances before regulatory or local governmental bodies necessary for the utility's operations.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-213, filed 5/3/01, effective 6/3/01.]


PDF480-100-223

Advertising.

(1) The commission will not allow expenses for promotional or political advertising for rate-making purposes. The term "promotional advertising" means advertising to encourage any person or business to select or use the service or additional services of an electric utility, to select or install any appliance or equipment designed to use the electric utility's service, or to influence consumers' opinions of the electric utility.
The term "political advertising" means any advertising for the purpose of influencing public opinion with respect to legislative, administrative, or electoral matters, or with respect to any controversial issue of public importance.
(2) As used in this section, the terms "promotional advertising" and "political advertising" do not include:
(a) Advertising which informs customers how to conserve energy or how to reduce peak demand for energy;
(b) Advertising required by law or by regulation, including advertising under Part 1 of Title II, of the National Energy Conservation Policy Act;
(c) Advertising regarding service interruptions, safety measures, or emergency conditions;
(d) Advertising concerning employment opportunities with the electric utility;
(e) Advertising which promotes the use of energy efficient appliances, equipment, or services;
(f) Announcements or explanations of existing or proposed tariffs or rate schedules; and
(g) Notices of meetings or commission hearings concerning electric utility rates and tariffs.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-223, filed 5/3/01, effective 6/3/01.]


PDF480-100-228

Retention and preservation of records and reports.

(1) Each electric utility must retain all records and reports for three years unless otherwise specified by the publication referenced in subsection (2) of this section. No records may be destroyed prior to the expiration of the time specified by the publication referenced in subsection (2) of this section.
(2) The commission adopts the publication, Regulations to Govern the Preservation of Records of Electric, Gas, and Water Companies, published by the National Association of Regulatory Utility Commissioners as the standards for utility records retention. Information about the Regulations to Govern the Preservation of Records of Electric, Gas, and Water Companies regarding the version adopted and where to obtain it is set out in WAC 480-100-999, Adoption by reference.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-228, filed 5/3/01, effective 6/3/01.]


PDF480-100-242

Issuing securities.

For the purpose of this section:
"Securities" means stocks, stock certificates, other evidence of interest or ownership, bonds, notes other than those notes exempted from reporting under RCW 80.08.043, or other evidence of indebtedness, or any obligation or liability as guarantor subject to reporting under RCW 80.08.130.
(1) Before an electric utility issues a security, it must file with the commission:
(a) A description of the purposes for which the issuance will be made, including a certification by an officer authorized to do so, that the proceeds from any such financing is for one or more of the purposes allowed by RCW 80.08.030;
(b) A description of the proposed issuance, including the terms of financing; and
(c) A statement as to why the transaction is in the public interest.
(2) A commission order is not required for such a filing. The utility may request a written order affirming that the utility has complied with the requirements of RCW 80.08.040. The utility must submit the request for a commission order, along with the information required in subsection (1) of this section, at least fifteen business days before the requested effective date for the order. Requests for supplemental orders may be exempt from the fifteen business day requirement.
(3) Filing a Registration Statement with the Securities and Exchange Commission using a shelf registration process does not constitute issuance of a security, and therefore a filing with the commission is not required under the provisions of RCW 80.08.040. A shelf registration filing is defined under the General Rules and Regulations promulgated under the Securities Act of 1933, Rule 415 - Delayed or Continuous Offering and Sale of Securities.
(4) An authorized representative must sign and date the filing and include a certification or declaration that the information is true and correct under penalty of perjury as set forth in chapter 9A.72 RCW. The certificate or declaration must be in substantially the following form:
"I certify (or declare) under penalty of perjury under the laws of the State of Washington that the foregoing is true and correct."
(5) Filings under this section may be submitted with portions designated confidential pursuant to WAC 480-07-160 (Confidential information).
(6) Within sixty days after the issuance of any securities, except for dividend reinvestment and employee benefit plans, a utility must file with the commission a verified statement:
(a) Outlining the final terms and conditions of the transaction; and
(b) Setting forth actual proceeds from the issuance and, to the extent known, the disposition of proceeds stating the final amount to be used for each purpose allowed by RCW 80.08.030.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 05-17-026 (Docket No. A-021178 and TO-030288, General Order No. R-522), § 480-100-242, filed 8/5/05, effective 9/5/05.]


PDF480-100-244

Transferring cash or assuming obligations.

(1) At least five business days before an electric utility whose corporate/issuer rating is not in one of the four highest rating categories of either Standard & Poor's L.L.C. or Moody's Investors Service, Inc., or its subsidiary transfers cash to any of its affiliated interests or subsidiaries or assumes an obligation or liability of any of its affiliated interests or any of its subsidiaries, the utility must report to the commission an estimate of the amount to be transferred and the terms of the transaction when the transaction will exceed thresholds described in (a) or (b) of this subsection.
(a) The utility must report if the cumulative transactions to a subsidiary or affiliated interest for the prior twelve months exceed a threshold of two percent, which is based on the utility's common shareholders equity.
(b) When the threshold in (a) of this subsection has been reached, the utility must report each subsequent transaction exceeding a threshold of one percent for the prior twelve-month period, which is based on the utility's common shareholders equity.
A utility's common shareholder equity is determined according to the latest annual report filed pursuant to WAC 480-100-252 (Federal Energy Regulatory Commission (FERC) Form No. 1). Information about the FERC Form No. 1 regarding the version adopted and where to obtain it is set out in WAC 480-100-999 (Adoption by reference).
(2) The reporting requirements in subsection (1) in this section do not include payments for:
(a) Federal and state taxes;
(b) Goods, services, or commodities, including fuel supplies (e.g., gas, coal, or oil);
(c) Transactions, attributed to the regulated entity, previously approved or ordered by the commission, other regulatory agencies, or the court;
(d) Dividends to the extent the level of such dividends over a twelve-month period does not exceed the larger of:
(i) Net income during such period; or
(ii) The average level of dividends over the preceding three years; or
(e) Sweep or cash management accounts used to transfer funds to or from a subsidiary or affiliate as part of the customary and routine cash management functions between or among the utility and its subsidiary or affiliate.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-244, filed 2/28/05, effective 3/31/05.]


PDF480-100-245

Affiliated interests—Contracts or arrangements.

Prior to the effective date of any contract or arrangement described in RCW 80.16.020, each electric utility must file a verified copy or a verified summary, if unwritten, of contracts or arrangements, except transactions provided at tariff rates, with any affiliated interest. Prior to the effective date of any modification or amendment, the utility must file verified copies of the modifications or amendments to the contracts or arrangements. If the contract or arrangement is unwritten, the utility must file a verified summary of any modification or amendment. The commission may institute an investigation and disapprove the contract or arrangement if the commission finds the utility has failed to prove that it is reasonable and consistent with the public interest.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-245, filed 2/28/05, effective 3/31/05.]


PDF480-100-248

Transfers of property.

Before selling, leasing, or assigning any of its property or facilities which are necessary or useful in the performance of its duties to the public, or before acquiring property or facilities of another public utility, an electric utility must obtain from the commission an order authorizing such transaction in accordance with chapters 80.12 RCW (Transfers of property) and 480-143 WAC (Commission general—Transfers of property).
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 05-17-026 (Docket No. A-021178 and TO-030288, General Order No. R-522), § 480-100-248, filed 8/5/05, effective 9/5/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-248, filed 2/28/05, effective 3/31/05.]


PDF480-100-252

Federal Energy Regulatory Commission (FERC) Form No. 1.

(1) Each electric utility must use the annual report form (FERC Form No. 1) promulgated by the Federal Energy Regulatory Commission in Title 18 of the Code of Federal Regulations, Part 141, for purposes of this report to the commission. Data required by RCW 80.04.080 (Annual reports), but not included in the FERC Form No. 1, must also be submitted with the annual report. The utility must submit the annual report for the preceding calendar year, along with the regulatory fee, by May 1st of each year. If not presented in the prescribed FERC Form No. 1, the annual report must include the following data per customer class for the calendar year: Revenues, average customer count, and total unit sales. Information about the FERC Form No. 1 regarding the version adopted and where to obtain it is set out in WAC 480-100-999 (Adoption by reference).
(2) Each utility must also submit to this commission, in essentially the same format and content as the FERC Form No. 1, a report that documents the costs incurred and the property necessary to furnish utility service to its customers and the revenues obtained in the state of Washington. The report must include the following data per customer class for the calendar year: Revenues, average customer count, and total unit sales.
(3) Combination and multistate utilities must submit with the annual report their cost allocation methods necessary to develop results of operations for the state of Washington. Approval of cost allocation methods for rate-making purposes is accomplished only by commission order.
(4) The total utility results of operations reported by each utility in its annual report to the commission must agree with the results of operations shown on the utility's books and records.
(5) Regulatory fees. The electric utility annual regulatory fee is set by statute at one-tenth of one percent of the first $50,000 of gross intrastate operating revenue plus four-tenths of one percent of any gross intrastate operating revenue in excess of $50,000.
(a) The maximum regulatory fee is assessed each year, unless the commission issues an order establishing the regulatory fee at an amount less than the statutory maximum.
(b) The minimum regulatory fee that an electric utility must pay is $20.
(c) The $20 minimum regulatory fee is waived for any electric utility with less than $20,000 in gross intrastate operating revenue.
(d) The commission does not grant extensions for payment of regulatory fees.
(e) If a company does not pay its regulatory fee by May 1st, the commission will assess an automatic late fee of two percent of the amount due, plus one percent interest for each month the fee remains unpaid.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.01.010, and 84.24.010. WSR 22-22-073 (Docket U-220271, General Order R-605), § 480-100-252, filed 10/31/22, effective 12/1/22. Statutory Authority: RCW 80.01.040(4), 81.04.160, and 34.05.353. WSR 06-08-057 (Docket A-060085, General Order No. R-531), § 480-100-252, filed 3/31/06, effective 5/1/06. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-252, filed 2/28/05, effective 3/31/05.]


PDF480-100-257

Commission basis report.

(1) Commission basis reports are due within four months of the end of a utility's fiscal year.
(2) The intent of the commission basis report is to depict the electric operations of an electric utility under normal temperature and power supply conditions during the reporting period. The commission basis report must include:
(a) Booked results of electric operations and rate base, and all the necessary adjustments as accepted by the commission in the utility's most recent general rate case or subsequent orders;
(b) Results of operations adjusted for any material out-of-period, nonoperating, nonrecurring, and extraordinary items or any other item that materially distorts reporting period earnings and rate base; and
(c) Booked revenues and power supply expenses adjusted to reflect operations under normal temperature and power supply conditions before the achieved return on rate base is calculated.
(3) Commission basis reports should not include adjustments that annualize price, wage, or other cost changes during a reporting period, nor new theories or approaches that have not been previously addressed and resolved by the commission.
(4) Each utility must submit the basis of any cost allocations and the allocation factors necessary to develop the commission basis results of electric operations for the state of Washington.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-257, filed 2/28/05, effective 3/31/05.]


PDF480-100-262

Securities report.

Each electric utility that has issued securities must file with the commission an annual securities transaction report. The report is due five months from the end of the utility's reporting period, whether a fiscal or calendar year. At a minimum, the report must contain:
(1) A schedule of the securities issued during the reporting period including a detailed description of the final agreements;
(2) A description of the use of proceeds stating the amounts used for each purpose allowed by RCW 80.08.030;
(3) The level of expenses for each of the securities transactions for the reporting period;
(4) A schedule of securities retired, refunded, repurchased, or otherwise removed from the utility's capitalization; and
(5) A schedule of securities scheduled to mature in the fiscal or calendar year following the reporting period.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 05-17-026 (Docket No. A-021178 and TO-030288, General Order No. R-522), § 480-100-262, filed 8/5/05, effective 9/5/05.]


PDF480-100-264

Affiliated interest and subsidiary transactions report.

(1) Each electric utility must file an annual report summarizing all transactions, except transactions provided at tariff rates, that occurred between the utility and its affiliated interests, and the utility and its subsidiaries. The report is due one hundred fifty days from the end of each reporting period, whether a fiscal or calendar year. The report must include a corporate organization chart of the utility and its affiliated interests and subsidiaries.
(2) When total transactions with an affiliated interest or a subsidiary are less than one hundred thousand dollars for the reporting period, the utility must provide the name of the affiliated interest or subsidiary participating in the transactions and the total dollar amounts of the transactions. When total transactions with an affiliated interest or subsidiary equal or exceed one hundred thousand dollars for the reporting period, the utility must provide:
(a) A balance sheet and income statement for such affiliated interest;
(b) A description of the products or services provided to or from the utility and each such affiliated interest or subsidiary;
(c) A description of the pricing basis or costing method, and procedures for allocating costs for such products or services, and the amount and accounts charged during the year;
(d) A description of the terms of any loans between the utility and each such affiliated interest or subsidiary and a listing of the year-end loan amounts and maximum loan amounts outstanding during the year;
(e) A description of the terms and total amount of any obligation or liability assumed by the utility for each such affiliated interest or subsidiary;
(f) A description of the activities of each such affiliated interest or subsidiary with which the utility has transactions; and
(g) A list of all common officers and directors between the electric utility and each such affiliated interest or subsidiary, along with their titles in each organization.
(3) The report required in this section supersedes the reporting requirements contained in previous commission orders authorizing affiliated interest transactions pursuant to chapter 80.16 RCW.
(4) The utility is obligated to file verified copies of affiliated interest contracts and arrangements as stated in WAC 480-100-245 (Affiliated interest—Contracts and arrangements).
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-264, filed 2/28/05, effective 3/31/05.]


PDF480-100-268

Essential utilities services contracts report.

(1) When the annual transactions with a vendor exceed one and one-half percent of total company sales to ultimate customers as reported in the utility's most recent Federal Energy Regulatory Commission (FERC) Form No. 1 (or combined Forms No. 1 and No. 2 for combined utilities), each electric utility must report the total contracts with that vendor for essential utility services specifying the relevant terms of the contract or contracts, along with anticipated associated charges. Information about the FERC Form No. 1 regarding the version adopted and where to obtain it is set out in WAC 480-100-999 (Adoption by reference).
(2) The report of essential service vendors is due one hundred twenty days from the end of each reporting period, whether a fiscal or calendar year.
(3) For each vendor the report must include:
(a) The parties to the contract;
(b) The type of contract;
(c) The essential obligations of each party to the contract;
(d) The length of the contract;
(e) The budgeted annual dollar value of the contract during the reporting period; and
(f) The actual payments for services rendered under the contract during the reporting period.
(4) Essential utility services are those services necessary to provide electric service such as:
(a) Operation or maintenance of electric system infrastructure;
(b) Operation or maintenance of computer systems;
(c) Purchase of electricity for classes of customer service regulated by the commission; and
(d) Construction of electric system infrastructure.
(5) The requirements under this section may be satisfied in whole or in part by cross-reference to the applicable portions of other documents that the utility has on file with the commission.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-268, filed 2/28/05, effective 3/31/05.]


PDF480-100-275

Actual results for Washington operations report.

Within sixty days of the end of each quarter, each electric utility must file a report of actual results for Washington operations. The results of operations report must contain each of the three monthly balances and the latest twelve months' ending balance for all accounts of the uniform system of accounts. The report must include the average customer count and total unit sales per customer class for each reported period.
[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 34.05.353. WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-275, filed 2/28/05, effective 3/31/05.]


PDF480-100-282

Application for approval of lease of utility facilities.

Under the provisions of RCW 80.04.520, the applicant must certify that the requested approval of lease of utility facilities is necessary to exempt any owner of the facilities from being a public utility company under the Public Utility Holding Company Act of 1935.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 05-17-026 (Docket No. A-021178 and TO-030288, General Order No. R-522), § 480-100-282, filed 8/5/05, effective 9/5/05.]


PDF480-100-287

Form of lease application.

A filing for approval of lease of utility facilities must be submitted in the following form:
Before The Washington Utilities And Transportation Commission
In the Matter of the Application of (insert name) for an Order
Approving the Lease of Utility Facilities.
 
No . . . .
 
(Number to be inserted by Commission)
. . . . . . . .
 
 
Application is hereby made to the Washington Utilities and Transportation Commission for an order authorizing the lease of utility facilities. The following general information and exhibits are furnished in support:
GENERAL INFORMATION
1. Name of applicant.
2. Address of principal office of applicant.
3. Name and address of attorney or agent.
4. State or states under which applicant is organized and form of organization.
5. A general description of the property owned by applicant and the field of its operations.
EXHIBIT "A"
A statement by applicant certifying that the requested approval is necessary or appropriate to exempt any owner of the facilities from being a public utility company under the federal Public Utility Holding Company Act of 1935.
EXHIBIT "B"
Detailed unconsolidated balance sheet as of three months before the date the application is filed, and a pro forma balance sheet as of the same date showing the effect of the proposed lease. Indicate separately the amount of intangibles and the amount reflected in plant acquisition adjustment account if such items are included in the fixed capital or utility plant accounts of the balance sheet.
EXHIBIT "B-1"
(A) Detailed income and profit-and-loss statement for the twelve months ended as of the date of the balance sheet submitted as Exhibit "B."
(B) Reconcilement of the retained earnings account for the period covered by the income and profit-and-loss statement. Retained earnings should be segregated from other surplus accounts.
EXHIBIT "C"
1. A description of the property to be leased.
2. The historical or original cost of the property to be leased and the related accrued depreciation. (Estimated in both cases if actual amounts are not known.)
3. The amount of contributions in aid of construction.
4. Terms of the lease.
EXHIBIT "D"
Economic and financial justification for entering into the proposed lease including a lease versus purchase analysis.
EXHIBIT "E"
Show such other facts that may be pertinent to the application.
The undersigned applicant requests that the Washington Utilities and Transportation Commission enter an order granting this application.
Dated this            day of
            , 20    .
 
By                   
(Applicant/Title)
[Statutory Authority: RCW 80.01.040, 80.04.160, and 81.04.160. WSR 05-17-026 (Docket No. A-021178 and TO-030288, General Order No. R-522), § 480-100-287, filed 8/5/05, effective 9/5/05.]


PDF480-100-308

Meter location.

(1) Subject to the utilities' requirements, customers must provide a place to install the metering equipment that is:
(a) Readily accessible to utility employees without risks of bodily harm; and
(b) Free from vibration, corrosive atmosphere, and abnormal temperatures.
(2) Upon request by a customer or a customer's representative, electric utilities must provide a written description of acceptable meter installation parameters applicable to the customer's electrical service needs.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-308, filed 5/3/01, effective 6/3/01.]


PDF480-100-313

Meter charges.

(1) An electric utility will make no charge for furnishing and installing the meter or meters required to determine the customer's usage for billing of electric service in accordance with the utility's filed tariff. The utility may charge for additional meters requested by the customer or required by the utility's tariff for service beyond determining the customer's bill.
(2) No meter may be required on unmetered load.
[Stautory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-313, filed 5/3/01, effective 6/3/01.]


PDF480-100-318

Meter readings, multipliers, and test constants.

(1) Electric utilities must use electric meters or other such devices to accurately record or indicate the quantity of electricity sold to customers. Such measuring devices will allow utilities to calculate a customer's consumption in units of kilowatt hours or other units as filed in the company's tariffs.
(2) Electric utilities that decide to either measure a customer's consumption with a device that employs a multiplier or calculate consumption from recording devices must provide customers, upon request, information sufficient to enable the customer to compute the quantity consumed.
(3) Indirect reading meters and those that operate from instrument transformers must have the multiplier plainly marked on the dial of the instrument or be otherwise suitably marked.
(4) The watt-hour constant for the meter itself must be placed on all watt-hour meters (as specified in ANSI C12.1). Information about the ANSI C12.1 regarding the version adopted and where to obtain it is set out in WAC 480-100-999 Adoption by reference.
(5) Measuring devices that have the capability to do so must measure all energy sold to customers at a minimum of sixty-minute intervals for residential customers and fifteen-minute intervals for nonresidential customers.
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapter 80.28 RCW. WSR 20-16-077 (Docket U-180525, General Order R-600), § 480-100-318, filed 7/29/20, effective 8/29/20. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-318, filed 5/3/01, effective 6/3/01.]


PDF480-100-328

Meter identification.

Electric utilities must identify each meter by a unique series of serial numbers, letters, or combination of both, placed in a conspicuous position on the meter.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-328, filed 5/3/01, effective 6/3/01.]


PDF480-100-333

Initial accuracy of electric meters.

All meters must be in good order and adjusted to register as nearly correct as practicable prior to being put into service or returned to service following testing or other work. All meters in service must be sealed by the use of a sealing device acceptable to the commission.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-333, filed 5/3/01, effective 6/3/01.]


PDF480-100-338

Accuracy requirements for electric meters.

(1) Watt-hour meter accuracy.
(a) The requirements for watt-hour meters used for measuring electrical quantities supplied include, but are not limited to:
(i) All meters must be of proper design for the circuit on which they are used, be in good mechanical and/or electronic condition, have adequate insulation, correct internal connections, and correct register;
(ii) Mechanical meters must not creep at "no load" more than one full revolution of the disk in five minutes:
(A) When the load wires are disconnected and potential is impressed; or
(B) In a shop test where the load wires are disconnected and the permissible voltage variation is impressed;
(b) All meters must be capable of registering no more than plus or minus 2.0 percent error when subject to a current ranging between five and ten percent of the meter's nameplate test current (ta) value, at the meter's rated voltage, and at unity power factor;
(c) All meters must be capable of registering no more than plus or minus 2.0 percent error when subject to a current ranging between seventy-five and one hundred fifty percent of the meter's nameplate test current (ta) value, at the meter's rated voltage, and at unity power factor;
(d) All meters must be capable of registering no more than plus or minus 3.0 percent error when subject to approximately one hundred percent of the meter's nameplate test current (ta) value, at the meter's nameplate rated voltage, and at a fifty percent lagging power factor;
(e) All polyphase meters must have the elements in balance within 2.0 percent when subject to a current approximately one hundred percent of the nameplate test current value, at the meter's rated voltage, at both unity and fifty percent lagging power factor.
(2) Demand meter accuracy.
(a) The requirements for demand meters, demand registers, or demand attachments used to measure a customer's service include, but are not limited to:
(i) The device must be in good mechanical and electrical condition;
(ii) The device must have the proper multiplier, indicating scale, resetting apparatus, and contact device if used;
(iii) The device must not register at no load;
(b) The device must achieve the following accuracies:
(i) Curve-drawing meters that record quantity-time curves, and integrated-demand meters must be accurate to within plus or minus 2.0 percent of full scale throughout their working range;
(ii) Timing elements measuring specific demand intervals must be accurate to within plus or minus 2.0 percent and the timing element that provides the time of day record of when the demand occurs must be accurate to within plus or minus four minutes in twenty-four hours;
(iii) Lagged-demand meters must be accurate to within plus or minus 4.0 percent of final indication;
(c) Mechanical and lagged demand meters must be tested at load points above fifty percent of full scale as specified in ANSI C12.1. Information about the ANSI C12.1 regarding the version adopted and where to obtain it is set out in WAC 480-100-999, Adoption by reference.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-338, filed 5/3/01, effective 6/3/01.]


PDF480-100-343

Statement of meter test procedures.

(1) Electric utilities must include in their tariffs a statement describing their practices under these rules covering:
(a) A description of methods used and frequency of tests for determining electric meter accuracy. The description must include, but is not limited to:
(i) Test group detail and selection procedures;
(ii) Performance standard details for meters that exceed the maximum allowable tolerance for slow as well as fast meters;
(iii) The corrective action and time period in which such action will be implemented; and
(iv) Reference to an industry standard such as ANSI C12.1 or ANSI/[isrt]ASQC-Z1.9 that will establish acceptable criteria for numerical analysis. Information about the ANSI C12.1 regarding the version adopted and where to obtain it is set out in WAC 480-100-999, Adoption by reference.
(b) A description of meter testing equipment, including methods employed to ascertain and maintain accuracy of all testing equipment.
(c) If an electric utility does not maintain meter testing equipment, the electric utility must state that it will use a qualified testing laboratory for this purpose. The utility must notify the commission by separate correspondence of the name of the testing laboratory making meter tests if it does not maintain meter testing equipment.
(d) The testing and adjustment program used for meters prior to installation and periodically after installation, if applicable.
(2) If an electric utility changes any portion of its meter test procedures after they have been approved by the commission, the utility must submit a revised tariff.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-343, filed 5/3/01, effective 6/3/01.]
Reviser's note: The brackets and enclosed material in the text of the above section occurred in the copy filed by the agency.


PDF480-100-353

Meter history records.

(1) Electric utilities must keep records showing the history of each meter purchased and installed. Such records must be maintained for the life of the meter plus three months. The forms of such records are subject to commission approval and must contain the following information at a minimum:
(a) The approximate date of purchase;
(b) The manufacturer's name and meter number or the utility's own unique meter identification number;
(c) The place(s) of installation; and
(d) The readings at the time of each installation and each removal.
(2) The records must include the date of all tests made on the meter, together with data recorded and computations made to determine the meter's accuracy. If a test is a complaint test, the records must include the complainant's name and the meter's calculated accuracy before and after the test.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-353, filed 5/3/01, effective 6/3/01.]


PDF480-100-358

Instrument transformers.

(1) Instrument transformers used in conjunction with metering equipment to measure customers' service must:
(a) Be in proper mechanical condition and have electrical insulation satisfactory for the service in which they are used; and
(b) Have characteristics such that the combined inaccuracies of all transformers supplying one or more meters in a given installation will not exceed the following:
100% Power Factor
50% Power Factor
10%
Current
100%
Current
10%
Current
100%
Current
1.5% error
0.75% error
3.0% error
2.0% error
(2) Meters used in conjunction with instrument transformers must be adjusted so that the overall accuracy of the meter installation (including both meter and instrument transformers) will meet the requirements specified in WAC 480-100-338, Accuracy requirements for electric meters. Instrument transformers may be tested with the meter with which they are associated, or separately. Except as provided in these rules, if transformers are tested separately, meters must also be tested to assure that the overall installation meets the prescribed accuracy requirements.
(3) Adjustment of the meter to correct instrument accuracy errors is not necessary when instrument transformers with the following accuracy characteristics are used:
(a) Instrument current transformers. The combined effect of ratio error and phase angle on the accuracy of the meter at any load power factor from sixty percent lagging to unity does not exceed six-tenths of one percent at ten percent rated current, or three-tenths of one percent at approximately one hundred percent rated current;
(b) Instrument potential transformers. The combined effect of ratio error and phase angle on the accuracy of the meter from ninety percent rated voltage to one hundred ten percent rated voltage, at any load power factor from sixty percent lagging to unity, does not exceed three-tenths of one percent.
(4) Electric utilities must keep instrument transformer test results on record and available for use when transformers are installed.
(5) Phase shifting transformers must have secondary voltages that are within plus or minus one percent of the voltage impressed on primary terminals, when tested under balanced line voltage conditions.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-358, filed 5/3/01, effective 6/3/01.]


PDF480-100-363

Portable indicating instruments.

(1) Electric utilities must maintain in reasonable working order all portable indicating electrical instruments used to determine quality of electrical service, such as volt meters, ammeters, and watt meters, and all fixed-location meter testing equipment in use and, if in question, must check it against suitable reference standards. If suitable reference standards are not available within the utility, the utility must check its portable instruments at a standardizing laboratory meeting specifications recommended by the meter manufacturer.
(2) Electric utilities must adjust portable analog indicating instruments that are found appreciably in error at zero. If a portable analog indicating instrument is in error by more than one percent at commonly used scale deflections, the electric utility must adjust it, unless the instrument is accompanied by a calibration card.
(3) Electrical utilities must maintain in good working order, as specified by the manufacturer of such instruments, all portable indicating electrical instruments used for purposes other than determining the quality of electrical service, such as instruments primarily for the safety of workers.
(4) Electric utilities must keep history and calibration records for each portable indicating electrical instrument used to determine quality of electrical service as defined in subsection (1) of this section, as long as the instrument is in service.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-363, filed 5/3/01, effective 6/3/01.]


PDF480-100-368

Standard frequency.

Any electric utility supplying alternating current must design and maintain its distribution system for a standard operating frequency of sixty cycles per second under normal operating conditions.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-368, filed 5/3/01, effective 6/3/01.]


PDF480-100-373

Standard voltage and permissible variation.

(1) Voltage means the voltage existing with loads operating under stable conditions. Each electric utility must adopt standard voltages for its different classes of standard voltage service and file these standards with the commission in the form of tariffs.
(2) Electric utilities must maintain the voltage on their distribution system reasonably constant and any allowed variation must be a gradual change in voltage as a result of normal changes in load.
The voltage on each primary distribution feeder must be maintained as follows:
(a) Voltage variations may not be more than five percent above or below the standard voltage adopted; and
(b) The total voltage variation from minimum to maximum value may not exceed eight percent of the standard voltage.
A utility may allow greater voltage variation than that specified in this rule in case of emergency service or when service is supplied directly from a transmission line. A utility may also permit greater voltage variations in an area where the revenues received do not justify close voltage regulation. In such cases, electric utilities must provide the best voltage regulation that is economically and technically practicable under the circumstances.
(3) Voltage variations in excess of those specified, caused by the action of the elements, by infrequent and unavoidable fluctuations of short duration due to system operation, or by the operation of power apparatus on the customer's premises which necessarily requires large starting currents and only affects the user of such apparatus, will not be considered a violation of this rule.
(4) Customers must control and operate the equipment on their premises in such a way that its starting and operating characteristics will not cause an instantaneous voltage drop of more than four percent of the standard voltage as measured at the point of interconnection with the electric utility. Likewise, customers must control and operate their equipment in such a way that it does not cause damage or interfere with the normal operation of the electric utility's facilities or of the facilities or equipment of another customer, such as causing excessive flicker in other customers' lights. Utilities are not required to monitor customers' equipment and its interactions with third party or utility equipment on an ongoing basis.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-373, filed 5/3/01, effective 6/3/01.]


PDF480-100-378

Accuracy of test standards.

(1) Electrical utilities must provide the commission with a written statement of their practices under these rules covering:
(a) A description of test standards and meter testing equipment, if maintained by the electrical utility;
(b) A description of methods employed to ascertain and maintain the accuracy of the test standards and meter testing equipment, including the frequency of such tests, if the electrical utility chooses to maintain its own such standards and equipment rather than use the services of a certified testing laboratory.
(2) If an electrical utility chooses to maintain its own test standards and meter testing instruments, it must retain records showing the date when each test standard and each meter testing instrument was tested, calibrated, or adjusted. Test standards must not be used in the field as working instruments.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-378, filed 5/3/01, effective 6/3/01.]


PDF480-100-383

Reports of accidents.

Each electric utility must notify the commission orally or by electronic mail no later than the second business day following discovery of any accident that results in death or serious injury to any person occurring in its plant or through electrical contact with its facilities. Electric utilities must submit a follow-up written report to the commission within fifteen business days of initial notification that includes, at a minimum:
(1) The name and address of the person or persons injured;
(2) The time and place of the accident;
(3) Whether the accident resulted in a fatality;
(4) A brief description of how the accident occurred; and
(5) A brief description of any necessary medical treatment that was provided.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-383, filed 5/3/01, effective 6/3/01.]


PDF480-100-388

Electric service reliability definitions.

"Electric service reliability" means the continuity of electric service experienced by retail customers.
"Reliability statistic" means a number, which may include multiple components (for example, service interruptions, customers, and hours), that measures electric service reliability.
"Baseline reliability statistic" means a number calculated by the utility measuring aspects of electric service reliability in a specified year that may be used as a comparison for measuring electric service reliability in subsequent years.
"Sustained interruption" means an interruption to electric service that has a length of duration specified by the electric utility, but in any case not less than one minute.
"Power quality" means characteristics of electricity, primarily voltage and frequency, that must meet certain specifications for safe, adequate and efficient operations.
"Full-system" means all equipment and lines necessary to serve retail customers whether for the purpose of generation, transmission, distribution or individual service.
"Major event" means an event, such as a storm, that causes serious reliability problems, and that meets criteria established by the utility for such an event.
[Statutory Authority: RCW 80.01.040. WSR 01-08-009 (Docket No. UE-991168, General Order No. R-478), § 480-100-388, filed 3/22/01, effective 4/22/01.]


PDF480-100-393

Electric service reliability monitoring and reporting plan.

(1) Who must file. Electric utilities subject to commission jurisdiction must file a plan for monitoring and reporting electric service reliability information to the commission.
(2) When to file. The plan for monitoring and reporting electric service reliability information must be filed with the commission six months after the effective date of this rule, though utilities are encouraged to file the plan sooner. Any modification to the plan must be filed with the commission before the modification is implemented.
(3) What to file. The utility must file a plan for monitoring and reporting electric service reliability information to the commission. The plan, and any modification to it, must be accepted by the commission. The plan must include the following items:
(a) What reliability statistics and information the utility will report to the commission. The utility must select and define statistics that track full-system reliability, and information, which may include statistics, that tracks localized reliability and identifies areas of greatest reliability concern.
(b) When the utility will establish baseline reliability statistics to report to the commission. Prior to establishing baseline reliability statistics, the utility must report the best information available. The utility must establish baseline reliability statistics within three years of the effective date of this rule.
(c) When the utility will file its annual electric service reliability report to the commission.
[Statutory Authority: RCW 80.01.040. WSR 01-08-009 (Docket No. UE-991168, General Order No. R-478), § 480-100-393, filed 3/22/01, effective 4/22/01.]


PDF480-100-398

Electric service reliability reports.

The electric utility must file an electric service reliability report with the commission at least once a year. The report must meet the following conditions:
(1) The report must be consistent with the electric service reliability monitoring and reporting plan filed under WAC 480-100-393. As set forth in the plan, in an identified year, baseline reliability statistics must be established and reported. In subsequent years, new reliability statistics must be compared to the baseline reliability statistics and to reliability statistics from all intervening years. The utility must maintain historical reliability information necessary to show trends for a minimum of seven years.
(2) The report must address any changes that the utility may make in the collection of data and calculation of reliability information after initial baselines are set. The utility must explain why the changes occurred and explain how the change is expected to affect comparisons of the newer and older information. Additionally, to the extent practical, the utility must quantify the effect of such changes on the comparability of new reliability statistics to baseline reliability statistics.
(3) The report must identify the utility's geographic areas of greatest reliability concern, explain their causes, and explain how the utility plans to address them.
(4) The report must identify the total number of customer complaints about reliability and power quality made to the utility during the year, and must distinguish between complaints about sustained interruptions and power quality. The report must also identify complaints that were made about major events.
[Statutory Authority: RCW 80.01.040. WSR 01-08-009 (Docket No. UE-991168, General Order No. R-478), § 480-100-398, filed 3/22/01, effective 4/22/01.]


PDF480-100-405

Electrical company generation resource compliance with the greenhouse gas emissions performance standard.

(1) No electrical company may enter into a long-term financial commitment after June 30, 2008, for the supply of baseload generation unless such generation complies with the greenhouse gas emissions performance standard. Electrical companies bear the burden to prove compliance with the greenhouse gas emissions performance standard under the requirements of WAC 480-100-415 or as part of a general rate case. For electrical companies that fail to carry their burden of proof, the commission may disallow recovery of some or all costs in rates, impose penalties, or take such other action as is consistent with law. Electrical companies seeking to prove compliance with the greenhouse gas emissions standard as part of a general rate case must submit all of the information specified in WAC 480-100-415. This chapter does not apply to any long-term financial commitment with the Bonneville power administration.
(2) The following definitions apply for purposes of this section, WAC 480-100-415, 480-100-425, and 480-100-435:
(a) "Baseload electric generation" means electric generation from a power plant that is designed and intended to provide electricity at an annualized plant capacity factor of at least sixty percent.
(b) "Electricity from unspecified sources" means electricity that is to be delivered in Washington pursuant to a long-term financial commitment entered into by an electrical company and whose sources or origins of generation and expected average annual deliveries cannot be ascertained with reasonable certainty.
(c) "Greenhouse gas emissions performance standard" means the standard established in RCW 80.80.040, WAC 173-407-120 and 173-407-130, and the verification and measurement procedures contained in WAC 173-407-140, 173-407-230, and 173-407-300.
(d) "Long-term financial commitment" means either a new ownership interest in baseload electric generation or an upgrade to a baseload electric generation facility; or a new or renewed contract for baseload electric generation with a term of five or more years for provision of retail power or wholesale power to end-use customers in this state.
(e) "New ownership interest" means a change in the ownership structure of a baseload power plant or a cogeneration facility or the electrical generation portion of a cogeneration facility affecting at least:
(i) Five percent of the market value of the power plant or cogeneration facility; or
(ii) Five percent of the electrical output of the power plant or cogeneration facility.
The above thresholds apply to each unit within a multiunit generation facility. A direct or indirect change in ownership of an electrical company does not constitute a new ownership interest in baseload electric generation.
(f) "Plant capacity factor" means the ratio of the electricity produced during a given time period, measured in kilowatt hours, to the electricity the unit could have produced if it had been operated at its rated capacity during that period, expressed in kilowatt hours.
(g) "Power plant" means a facility for the generation of electricity that is permitted as a single plant by a jurisdiction inside or outside the state.
(h) "State" means the state of Washington.
(i) "Upgrade" means any modification made for the primary purpose of increasing the electric generation capacity of a baseload electric generation facility or unit. Upgrade does not include:
(i) Routine or necessary maintenance;
(ii) Installation of emission control equipment;
(iii) Installation, replacement, or modification of equipment that improves the heat rate of the facility; or
(iv) Installation, replacement, or modification of equipment for the primary purpose of maintaining reliable generation output capability that does not increase the heat input or fuel usage as specified in existing generation air quality permits as of July 22, 2007, but may result in incidental increases in generation capacity.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 80.08.060(8). WSR 10-23-032 (Docket UE-100865, General Order R-561), § 480-100-405, filed 11/9/10, effective 12/10/10. Statutory Authority: RCW 80.01.040, 80.04.160 and 80.80.060. WSR 08-23-047 (Docket UE-080111, General Order R-553), § 480-100-405, filed 11/14/08, effective 12/15/08.]


PDF480-100-415

Electrical company applications for commission determination outside of a general rate case of electric generation resource compliance with greenhouse gas emissions performance standard.

(1) Any electrical company may apply for a determination by the commission outside of a general rate case of whether an electric generation resource it proposes to acquire as a long-term financial commitment complies with the greenhouse gas emissions performance standard, including whether the resource is baseload electric generation.
(2) If an electrical company submits an application under this subsection regarding a long-term financial commitment with multiple power plants, each power plant will be considered individually in determining:
(a) Annualized plant capacity factor;
(b) Net emissions;
(c) Compliance with RCW 80.80.040(1) except as provided in RCW 80.80.040 (3) through (5).
(3) Any request under this subsection must include the following information:
(a) If the proposed electric generation resource is a specific power plant located in the state:
(i) The plant technology, design, fuel and fuel consumption;
(ii) Any site certificate or other permits necessary for operation of the power plant, including, any determination made by the department of ecology, local air authority or the energy facility site evaluation council regarding compliance with the greenhouse gas emissions performance standard;
(iii) Such other information as is available to or in the possession of the electrical company concerning exhaust emissions including total annual pounds of greenhouse gas from each power plant.
(b) If the proposed electric generation resource is a specific power plant located outside the state:
(i) The plant technology, design, fuel and fuel consumption;
(ii) Any site certificate or other permits necessary for operation of the power plant;
(iii) Such other information as is available to or in the possession of the electrical company concerning exhaust emissions characteristics of the plant including total annual pounds of greenhouse gas from each power plant;
(iv) Documentation of emissions verifications and measurement procedures which show consistency with the state's emissions performance standard.
(c) If the proposed electric generation resource is a power purchase contract including contracts for delivery of electricity from unspecified sources:
(i) The proposed contract;
(ii) The technology, location, design, fuel and fuel consumption of any power plant, or plants, identified in the contract as the source of the contracted power deliveries, including such information as is knowable regarding the proportionate share each power source, or type of plant, will contribute to deliveries on an annual basis over the life of the contract;
(iii) Such other information as is available to or in the possession of the electrical company concerning the exhaust emissions characteristics of the plant(s) supporting contracted power deliveries including total annual pounds of greenhouse gas from each power plant.
(iv) A calculation of the percent of electricity delivered under the power purchase contract from unspecified resources.
(v) The contract term of the power purchase agreement.
(4) The commission may consider an application filed under this section pursuant to chapter 34.05 RCW (Part IV) following the procedures established in chapter 480-07 WAC, but the commission will not decide in any application under this section, issues involving the actual costs to construct and operate the selected resource, cost recovery, or other issues reserved by the commission for decision in a general rate case or other proceeding authorized by the commission for recovery of the resource or contract costs.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 80.08.060(8). WSR 10-23-032 (Docket UE-100865, General Order R-561), § 480-100-415, filed 11/9/10, effective 12/10/10. Statutory Authority: RCW 80.01.040, 80.04.160 and 80.80.060. WSR 08-23-047 (Docket UE-080111, General Order R-553), § 480-100-415, filed 11/14/08, effective 12/15/08.]


PDF480-100-425

Electrical company applications for exemption from the greenhouse gas emissions performance standard.

(1) An electrical company may apply to the commission for a case-by-case exemption from the greenhouse gas emissions performance standard to address:
(a) Unanticipated electric system reliability needs; or
(b) Extraordinary cost impacts on utility ratepayers; or
(c) Catastrophic events or threat of significant financial harm that may arise from unforeseen circumstances.
(2) An electrical company's application under subsection (1)(a) of this section must include:
(a) A description of the electric system reliability needs including an explanation of why these needs were not anticipated, and why they cannot be addressed with other baseload electric generation that complies with the greenhouse gas performance standard.
(b) The estimated duration of the exemption necessary to address the reliability need.
(c) A description of any long-term financial commitment the company proposes to enter into to address the reliability need including all of the information specified in WAC 480-100-415.
(3) An application under subsection (1)(b) of this section must include:
(a) Identification of the long-term financial commitment that will result in extraordinary costs to ratepayers.
(b) Criteria used by the applicant to judge cost as extraordinary.
(c) A description of the extraordinary cost including:
(i) Total system, jurisdictional and per-customer cost impact.
(ii) Company proposed alternatives, if any, to address the extraordinary costs.
(iii) The estimated duration of the exemption necessary to address the extraordinary cost impact.
(4) An electrical company's application under subsection (1)(c) of this section must include:
(a) A description of the catastrophic event or threat of significant financial harm and an explanation of why the circumstances from which the event or harm arose were not foreseen including:
(i) An explanation of why the circumstances cannot be addressed with baseload generation that complies with the greenhouse gas performance standard;
(ii) What the anticipated negative financial impact would be to the company if such exemption were denied;
(b) The estimated duration of the exemption necessary to address the catastrophic event or threat of significant financial harm.
(c) A description of any long-term financial commitment the company proposes to enter into to address the catastrophic event or threat of significant financial harm including all of the information specified in WAC 480-100-415.
(5) An electrical company may propose recovery of costs associated with an application under this rule as part of a general rate case.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 80.08.060(8). WSR 10-23-032 (Docket UE-100865, General Order R-561), § 480-100-425, filed 11/9/10, effective 12/10/10. Statutory Authority: RCW 80.01.040, 80.04.160 and 80.80.060. WSR 08-23-047 (Docket UE-080111, General Order R-553), § 480-100-425, filed 11/14/08, effective 12/15/08.]


PDF480-100-435

Electrical company deferral of costs associated with long-term financial commitments—Notice and reporting.

(1) An electrical company may account for and defer for later consideration by the commission costs incurred in connection with a long-term financial commitment for:
(a) Baseload electric generation; or
(b) An eligible renewable resource as defined in RCW 19.285.030 that the electrical company owns or has entered a power purchase agreement for a term of five or more years.
(2) Deferred costs may include operating and maintenance costs, depreciation, taxes, and cost of invested capital.
(3) An electrical company deferring costs under subsection (1) of this section must:
(a) Notify the commission within ten business days of its intent to defer such costs; and
(b) File quarterly with the commission a report documenting the balances of costs deferred in a form specified by the commission.
(4) The deferral begins with the date on which the power plant begins commercial operation or the effective date of the power purchase agreement and continues for a period not to exceed twenty-four months; provided that if during such period the company files a general rate case or other proceeding for the recovery of such costs, deferral ends on the effective date of the final decision by the commission in such proceeding. Creation of such a deferral account does not by itself determine the actual costs of the long-term financial commitment, whether recovery of any or all of these costs is appropriate, or other issues to be decided by the commission in a general rate case or other proceeding authorized by the commission for recovery of these costs.
[Statutory Authority: RCW 80.01.040, 80.04.160, and 80.08.060(8). WSR 10-23-032 (Docket UE-100865, General Order R-561), § 480-100-435, filed 11/9/10, effective 12/10/10. Statutory Authority: RCW 80.01.040, 80.04.160 and 80.80.060. WSR 08-23-047 (Docket UE-080111, General Order R-553), § 480-100-435, filed 11/14/08, effective 12/15/08.]


PDF480-100-505

Smart grid technology report.

(1) Purpose. The purpose of this section is to establish requirements for each electric utility to submit periodic reports to the commission of the utility's evaluation of smart grid technologies that are available or likely soon to be available and any plans for implementing smart grid technologies affecting or applicable to ratepayers of Washington state.
(2) Definitions.
(a) "Smart grid function" means one or more of the following:
(i) The ability to develop, store, send and receive digital information concerning electricity use, costs, prices, time of use, nature of use, storage, or other information relevant to management of the electricity grid, utility operations, or customer energy use.
(ii) The ability to sense local disruptions or changes in power flows on the electricity grid and to communicate such information instantaneously and automatically for purposes of enabling automatic protective responses or to inform the utility to make manual changes to sustain reliability and security or improve efficiency of grid operations.
(iii) The ability of the utility to deliver signals, measurements or communications to allow an end-use load device to respond automatically or in a manner programmed by its owner or operator without human action.
(iv) The ability to use digital information to operate functions on the electricity grid that were previously electromechanical or manual.
(v) The ability to use digital controls to manage and modify electricity demand, enable congestion management, assist in voltage control, provide operating reserves, or provide frequency regulation.
(vi) The ability to use two-way communication to enable different customer contracts or programs, such as real time prices or demand response programs.
(vii) The ability to manage new end-use services to reduce operating or power costs, improve reliability, or improve energy efficiency, such as charging electric vehicles.
(viii) The ability to use real time measurement of power generated from customer-owned power facilities to reduce operating or power cost, improve energy efficiency, or improve reliability.
(ix) The ability to use digital information to improve the reliability or efficiency of generating equipment in an integrated manner to improve flexibility, functionality, interoperability, cyber-security, situational awareness, and operational efficiency of the transmission and distribution system.
(b) "Smart grid pilot" means a project designed to test the feasibility of smart grid technologies or customer acceptance of such.
(c) "Smart grid technologies" means any technology intended to improve the reliability or efficiency, or to reduce the operating costs, of electrical transmission and distribution systems by enabling one or more smart grid functions. Smart grid technologies include, without limitation, measurement devices, communication equipment, information processing equipment and software, and control devices.
(d) "Smart grid technology report" or "report" means a report describing the utility's evaluation of, and any implementation plans for, smart grid technologies.
(3) Reporting requirement.
(a) Each electric utility must file with the commission a smart grid technology report no later than September 1, 2010, and a subsequent report no later than September 1st of each even-numbered year thereafter through September 2016.
(b) Unless otherwise ordered by the commission, this reporting requirement shall expire after the filing of the report due September 1, 2016.
(4) Content. At a minimum, the smart grid technology report must include:
(a) A description of the smart grid technologies the utility has considered for integration into its system, and the utility's evaluation of such technologies. The description required by this subsection shall contain details that the utility has considered and evaluated: Examples of such details include:
(i) Goal or purpose of the smart grid technologies described in the report;
(ii) Total costs of the deployment and use of smart grid technologies including meter or other equipment costs, installation costs, and any incremental administration costs including the cost of changes to data storage, processing and billing systems;
(iii) Overall cost-effectiveness of smart grid technologies planned to be implemented and, to the extent it can be quantified, possible impacts on customer bills;
(iv) Operational savings associated with meter reading or other utility functions;
(v) Effects on system capability to meet or modify energy or peak loads;
(vi) Effects on service reliability including storm damage response and recovery, outage frequency and duration and voltage quality;
(vii) Effects on integration of new utility loads, such as recharging batteries in electrically powered vehicles;
(viii) Cyber and physical security of utility operational information;
(ix) Cyber and physical security of customer information and effects, if any, on existing consumer protection policies;
(x) Interoperability and upgradability of technology and compliance with applicable national standards;
(xi) Customer acceptance and behavioral response;
(xii) Tariff and rate design changes necessary to implement the technology;
(xiii) Nonquantifiable societal benefits, if any; and
(xiv) Economic considerations recognizing the above-listed factors.
(b) Identification of any smart grid technologies that may be cost-effective and available for the utility and its customers during the subsequent ten-year period.
(c) A description of the utility's plans and timeline for implementing any smart grid technologies during the two years following submission of the report.
(d) After the first report, all subsequent reports should include information on the utility's progress on any smart grid technologies scheduled for implementation as stated in its previously filed reports and any smart grid pilot project the utility has undertaken.
(5) The smart grid technology report may include:
(a) The utility's assessment of the risk of investment in smart grid technologies and any recommendations for regulatory treatment, supported by the utility's rationale for such treatment.
(b) Any other factors considered by the utility.
(6) To the extent that some of the information required or allowed to be included in the report also is included in other reports, such as the utility's most recent integrated resource plan, the utility may incorporate that information by specific reference.
(7) The commission may consider the information contained in a smart grid technology report when it evaluates, in rate and other appropriate proceedings, the performance of the utility and its investments in transmission, distribution and metering infrastructure.
[Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 10-08-001 (Docket U-090222, General Order R-559), § 480-100-505, filed 3/24/10, effective 4/24/10.]


PDF480-100-600

Purpose.

The purpose of these rules is to ensure that the utility meets the clean energy transformation standards outlined in WAC 480-100-610 in a timely manner and at the lowest reasonable cost.
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-600, filed 12/28/20, effective 12/31/20.]


PDF480-100-605

Definitions.

The definitions below apply to all of WAC 480-100-600 through 480-100-665.
"Allocation of electricity" means, for the purposes of setting electricity rates, the costs and benefits associated with the resources used to provide electricity to an electric utility's retail electricity consumers that are located in this state.
"Alternative lowest reasonable cost and reasonably available portfolio" means, for purposes of calculating the incremental cost of compliance in RCW 19.405.060(3), the portfolio of investments the utility would have made and the expenses the utility would have incurred if not for the requirement to comply with RCW 19.405.040 and 19.405.050. The alternative lowest reasonable cost and reasonably available portfolio must include the social cost of greenhouse gases in the resource acquisition decision in accordance with RCW 19.280.030 (3)(a).
"Biomass energy" includes: Organic by-products of pulping and the wood manufacturing process; animal manure; solid organic fuels from wood; forest or field residues; untreated wooden demolition or construction debris; food waste and food processing residuals; liquors derived from algae; dedicated energy crops; and yard waste.
Biomass energy does not include:
• Wood pieces that have been treated with chemical preservatives such as creosote, pentachlorophenol, or copper-chrome-arsenic;
• Wood from old growth forests; or
• Municipal solid waste.
"Carbon dioxide equivalent" or "CO2e" means a metric measure used to compare the emissions from various greenhouse gases based upon their global warming potential.
"CEAP" means the clean energy action plan.
"CEIP" means the clean energy implementation plan.
"Coal-fired resource" means a facility that uses coal-fired generating units, or that uses units fired in whole or in part by coal as feedstock, to generate electricity. Coal-fired resource does not include:
• An electric generating facility that is included as part of a limited duration wholesale power purchase, not to exceed one month, made by an electric utility for delivery to retail electric customers that are located in this state for which the source of the power is not known at the time of entry into the transaction to procure the electricity; or
• An electric generating facility that is subject to an obligation to meet the standards contained in RCW 80.80.040 (3)(c).
"Commission" means the Washington utilities and transportation commission.
"Conservation and efficiency resources" means any reduction in electric power consumption that results from increases in the efficiency of energy use, production, transmission, or distribution.
"Cost-effective" means that a project or resource is forecast: (a) To be reliable and available within the time it is needed; and (b) to meet or reduce the electric power demand of the intended consumers at an estimated incremental system cost no greater than that of the least-cost similarly reliable and available alternative project or resource, or any combination thereof.
"Customer benefit indicator" means an attribute, either quantitative or qualitative, of resources or related distribution investments associated with customer benefits described in RCW 19.405.040(8).
"Demand response" means changes in electric usage by demand-side resources from their normal consumption patterns in response to changes in the price of electricity, or to incentive payments designed to induce lower electricity use, at times of high wholesale market prices or when system reliability is jeopardized. Demand response may include measures to increase or decrease electricity production on the customer's side of the meter in response to incentive payments.
"Distributed energy resource" means a nonemitting electric generation or renewable resource or program that reduces electric demand, manages the level or timing of electricity consumption, or provides storage, electric energy, capacity, or ancillary services to an electric utility and that is located on the distribution system, any subsystem of the distribution system, or behind the customer meter, including conservation and energy efficiency.
"Energy assistance" means a program undertaken by a utility to reduce the household energy burden of its customers.
• Energy assistance includes, but is not limited to, weatherization, conservation and efficiency services, and monetary assistance, such as a grant program or discounts for lower income households, intended to lower a household's energy burden.
• Energy assistance may include direct customer ownership in distributed energy resources or other strategies if such strategies achieve a reduction in energy burden for the customer above other available conservation and demand-side measures.
"Energy assistance need" means the amount of assistance necessary to achieve an energy burden equal to six percent for utility customers.
"Energy burden" means the share of annual household income used to pay annual home energy bills.
"Equitable distribution" means a fair and just, but not necessarily equal, allocation of benefits and burdens from the utility's transition to clean energy. Equitable distribution is based on disparities in current conditions. Current conditions are informed by, among other things, the assessment described in RCW 19.280.030 (1)(k) from the most recent integrated resource plan.
"Fossil fuel" means natural gas, petroleum, coal, or any form of solid, liquid, or gaseous fuel derived from such a material.
"Greenhouse gas" includes carbon dioxide, methane, nitrous oxide, hydrofluorocarbons, perfluorocarbons, sulfur hexafluoride, and any other gas or gases designated by the department of ecology by rule under RCW 70A.45.010.
"Highly impacted community" means a community designated by the department of health based on the cumulative impact analysis required by RCW 19.405.140 or a community located in census tracts that are fully or partially on "Indian country," as defined in 18 U.S.C. Sec. 1151.
"Implementation period" means the four years after the filing of each clean energy implementation plan through 2045. The first implementation period will begin January 1, 2022, and will end December 31, 2025, and the second implementation period will begin on January 1, 2026, and will end on December 31, 2029.
"Integrated resource plan" or "IRP" means an analysis describing the mix of generating resources, conservation, methods, technologies, and resources to integrate renewable resources and, where applicable, address overgeneration events, and efficiency resources that will meet current and projected needs at the lowest reasonable cost to the utility and its ratepayers and that complies with the requirements specified in RCW 19.280.030(1).
"Lowest reasonable cost" means the lowest cost mix of generating resources and conservation and efficiency resources determined through a detailed and consistent analysis of a wide range of commercially available resources. At a minimum, this analysis must consider resource cost, market-volatility risks, demand-side resource uncertainties, resource dispatchability, resource effect on system operation, the risks imposed on the utility and its customers, public policies regarding resource preference adopted by Washington or the federal government, and the cost of risks associated with environmental effects, including emissions of carbon dioxide. The analysis of the lowest reasonable cost must describe the utility's combination of planned resources and related delivery system infrastructure and show consistency with chapters 19.280, 19.285, and 19.405 RCW.
"Natural gas" means naturally occurring mixtures of hydrocarbon gases and vapors consisting principally of methane, whether in gaseous or liquid form, including methane clathrate. Natural gas does not include renewable natural gas or the portion of renewable natural gas when blended into other fuels.
"Nonemitting electric generation" means electricity from a generating facility or a resource that provides electric energy, capacity, or ancillary services to an electric utility and that does not emit greenhouse gases as a by-product of energy generation. Nonemitting electric generation does not include renewable resources.
"Nonpower attributes" means all environmentally related characteristics, exclusive of energy, capacity reliability, and other electrical power service attributes, that are associated with the generation of electricity including, but not limited to, the facility's fuel type, geographic location, vintage, qualification as a renewable resource, and avoided emissions of pollutants to the air, soil, or water, and avoided emissions of carbon dioxide and other greenhouse gases. Nonpower attributes does not include any aspects, claims, characteristics, and benefits associated with the on-site capture and destruction of methane or other greenhouse gases at a facility through a digester system, landfill gas collection system, or other mechanism, which may be separately marketable as greenhouse gas emission reduction credits, offsets, or similar tradable commodities. However, these separate avoided emissions may not result in or otherwise have the effect of attributing greenhouse gas emissions to the electricity.
"Renewable energy credit" or "REC" means a tradable certificate of proof of one megawatt-hour of a renewable resource. The certificate includes all of the nonpower attributes associated with that one megawatt-hour of electricity and the certificate is verified by a renewable energy credit tracking system selected by the department of commerce.
"Renewable resource" means water; wind; solar energy; geothermal energy; renewable natural gas; renewable hydrogen; wave, ocean, or tidal power; biodiesel fuel that is not derived from crops raised on land cleared from old growth or first growth forests; or biomass energy.
"Resource" includes, but is not limited to, generation, conservation, distributed generation, demand response, efficiency, and storage.
"Resource need" means any current or projected deficit to reliably meet electricity demands created by changes in demand, changes to system resources, or their operation to comply with state or federal requirements. Such demands or requirements may include, but are not limited to, capacity and associated energy, capacity needed to meet peak demand in any season, fossil-fuel generation retirements, equitable distribution of benefits or reduction of burdens, cost-effective conservation and efficiency resources, demand response, and renewable and nonemitting resources.
"Retail electric load" means the amount of megawatt-hours of electricity delivered in a given calendar year by an electric utility to its Washington retail electric customers. "Retail electric load" does not include:
(a) Megawatt-hours delivered from qualifying facilities under the federal Public Utility Regulatory Policies Act of 1978, P.L. 95-617, in operation prior to May 7, 2019, provided that no entity other than the electric utility can make a claim on delivery of the megawatt-hours from those resources; or
(b) Megawatt-hours delivered to an electric utility's system from a renewable resource through a voluntary renewable energy purchase by a retail electric customer of the utility in which the renewable energy credits associated with the megawatt-hours delivered are retired on behalf of the retail electric customer.
"Social cost of greenhouse gas emissions" or "SCGHG" is the inflation-adjusted costs of greenhouse gas emissions resulting from the generation of electricity, as required by RCW 80.28.405, the updated calculation of which is published on the commission's website.
"Unbundled renewable energy credit" or "unbundled REC" means a renewable energy credit that is sold, delivered, or purchased separately from the underlying electricity. All thermal renewable energy credits are considered unbundled renewable energy credits.
"Unspecified electricity" means an electricity source for which the fuel attribute is unknown or has been separated from the energy delivered to retail electric customers.
"Vulnerable populations" means communities that experience a disproportionate cumulative risk from environmental burdens due to: (a) Adverse socioeconomic factors, including unemployment, high housing and transportation costs relative to income, access to food and health care, and linguistic isolation; and (b) sensitivity factors, such as low birth weight and higher rates of hospitalization.
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-605, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-605, filed 12/28/20, effective 12/31/20.]


PDF480-100-610

Clean energy transformation standards.

(1) On or before December 31, 2025, each utility must eliminate coal-fired resources from its allocation of electricity to Washington retail electric customers;
(2) By January 1, 2030, each utility must ensure all retail sales of electricity to Washington electric customers are greenhouse gas neutral;
(3) By January 1, 2045, each utility must ensure that nonemitting electric generation and electricity from renewable resources supply 100 percent of all retail sales of electricity to Washington electric customers;
(4) In making progress toward and meeting subsections (2) and (3) of this section, each utility must:
(a) Pursue all cost-effective, reliable, and feasible conservation and efficiency resources and demand response;
(b) Maintain and protect the safety, reliable operation, and balancing of the electric system; and
(c) Ensure that all customers are benefiting from the transition to clean energy through:
(i) The equitable distribution of energy and nonenergy benefits and reduction of burdens to vulnerable populations and highly impacted communities;
(ii) Long-term and short-term public health and environmental benefits and reduction of costs and risks; and
(iii) Energy security and resiliency.
(5) Each utility must demonstrate that it has made progress toward and has met the standards in this section at the lowest reasonable cost.
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-610, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-610, filed 12/28/20, effective 12/31/20.]


PDF480-100-620

Content of an integrated resource plan.

(1) Purpose. Consistent with chapters 80.28, 19.280, and 19.405 RCW, each electric utility has the responsibility to identify and meet its resource needs with the lowest reasonable cost mix of conservation and efficiency, generation, distributed energy resources, and delivery system investments to ensure the utility provides energy to its customers that is clean, affordable, reliable, and equitably distributed. At a minimum, integrated resource plans must include the components listed in this rule. Unless otherwise stated, the assessments, evaluations, and forecasts should be over an appropriate planning horizon.
(2) Load forecast. The IRP must include a range of forecasts of projected customer demand that reflect the effect of economic forces on the consumption of electricity and address changes in the number, type, and efficiency of end uses of electricity.
(3) Distributed energy resources.
(a) The IRP must include assessments of a variety of distributed energy resources. These assessments must incorporate nonenergy costs and benefits not fully valued elsewhere within any integrated resource plan model. Utilities must assess the effect of distributed energy resources on the utility's load and operations under RCW 19.280.030 (1)(h). The commission strongly encourages utilities to engage in a distributed energy resource planning process as described in RCW 19.280.100. If the utility elects to use a distributed energy resource planning process, the IRP should include a summary of the results.
(b) The required distributed energy resource assessments must include the following:
(i) Energy efficiency and conservation potential assessment – The IRP must assess currently employed and potential policies and programs needed to obtain all cost-effective conservation, efficiency, and load management improvements, including the ten-year conservation potential used in calculating a biennial conservation target under chapter 480-109 WAC;
(ii) Demand response potential assessment – The IRP must assess currently employed and new policies and programs needed to obtain all cost-effective demand response;
(iii) Energy assistance potential assessment – The IRP must include distributed energy programs and mechanisms identified pursuant to RCW 19.405.120, which pertains to energy assistance and progress toward meeting energy assistance need; and
(iv) Other distributed energy resource potential assessments – The IRP must assess other distributed energy resources that may be installed by the utility or the utility's customers including, but not limited to, energy storage, electric vehicles, and photovoltaics. Any such assessment must include the effect of distributed energy resources on the utility's load and operations.
(4) Supply-side resources. The IRP must include an assessment of a wide range of commercially available generating and nonconventional resources, including ancillary service technologies.
(5) Renewable resource integration. An assessment of methods, commercially available technologies, or facilities for integrating renewable resources including, but not limited to, battery storage and pumped storage, and addressing overgeneration events, if applicable to the utility's resource portfolio. The assessment may address ancillary services.
(6) Regional generation and transmission. The IRP must include an assessment of the availability of regional generation and transmission capacity on which the utility may rely to provide and deliver electricity to its customers.
(a) The assessment must include the utility's existing transmission capabilities, and future resource needs during the planning horizon, including identification of facilities necessary to meet future transmission needs.
(b) The assessment must also identify the general location and extent of transfer capability limitations on its transmission network that may affect the future siting of resources.
(7) Resource evaluation. The IRP must include a comparative evaluation of all identified resources and potential changes to existing resources for achieving the clean energy transformation standards in WAC 480-100-610 at the lowest reasonable cost.
(8) Resource adequacy. The IRP must include an assessment and determination of resource adequacy metrics. It must also identify an appropriate resource adequacy requirement and measurement metrics consistent with RCW 19.405.030 through 19.405.050.
(9) Economic, health, and environmental burdens and benefits. The IRP must include an assessment of energy and nonenergy benefits and reductions of burdens to vulnerable populations and highly impacted communities; long-term and short-term public health and environmental benefits, costs, and risks; and energy security risk. The assessment should be informed by the cumulative impact analysis conducted by the department of health.
(10) Scenarios and sensitivities. The IRP must include a range of possible future scenarios and input sensitivities for the purpose of testing the robustness of the utility's resource portfolio under various parameters. The IRP must also provide a narrative description of scenarios and sensitivities the utility used, including those informed by the advisory group process.
(a) At least one scenario must describe the alternative lowest reasonable cost and reasonably available portfolio that the utility would have implemented if not for the requirement to comply with RCW 19.405.040 and 19.405.050, as described in WAC 480-100-660(1). This scenario's conditions and inputs should be the same as the preferred portfolio except for those conditions and inputs that must change to account for the impact of RCW 19.405.040 and 19.405.050.
(b) At least one scenario must be a future climate change scenario. This scenario should incorporate the best science available to analyze impacts including, but not limited to, changes in snowpack, streamflow, rainfall, heating and cooling degree days, and load changes resulting from climate change.
(c) At least one sensitivity must be a maximum customer benefit scenario. This sensitivity should model the maximum amount of customer benefits described in RCW 19.405.040(8) prior to balancing against other goals.
(11) Portfolio analysis and preferred portfolio. The utility must integrate the demand forecasts and resource evaluations into a long-range integrated resource plan solution describing the mix of resources that meet current and projected resource needs. Each utility must provide a narrative explanation of the decisions it has made, including how the utility's long-range integrated resource plan expects to:
(a) Achieve the clean energy transformation standards in WAC 480-100-610 (1) through (3) at the lowest reasonable cost;
(b) Serve utility load, based on hourly data, with the output of the utility's owned resources, market purchases, and power purchase agreements, net of any off-system sales of such resource;
(c) Include all cost-effective, reliable, and feasible conservation and efficiency resources, using the methodology established in RCW 19.285.040, and demand response;
(d) Consider acquisition of existing renewable resources;
(e) In the acquisition of new resources constructed after May 7, 2019, rely on renewable resources and energy storage, insofar as doing so is at the lowest reasonable cost;
(f) Maintain and protect the safety, reliable operation, and balancing of the utility's electric system, including mitigating over-generation events and achieving the identified resource adequacy requirement;
(g) Achieve the requirements in WAC 480-100-610 (4)(c); the description should include, but is not limited to:
(i) The long-term strategy and interim steps the utility will take to equitably distribute benefits and reduce burdens for highly impacted communities and vulnerable populations; and
(ii) The estimated degree to which benefits will be equitably distributed and burdens reduced over the planning horizon.
(h) Assess the environmental health impacts to highly impacted communities;
(i) Analyze and consider combinations of distributed energy resource costs, benefits, and operational characteristics including ancillary services, to meet system needs; and
(j) Incorporate the social cost of greenhouse gas emissions as a cost adder as specified in RCW 19.280.030(3).
(12) Clean energy action plan (CEAP). The utility must develop a ten-year clean energy action plan for implementing RCW 19.405.030 through 19.405.050. The CEAP must:
(a) Be at the lowest reasonable cost;
(b) Identify and be informed by the utility's ten-year cost-effective conservation potential assessment as determined under RCW 19.285.040;
(c) Identify how the utility will meet the requirements in WAC 480-100-610 (4)(c) including, but not limited to:
(i) Describing the specific actions the utility will take to equitably distribute benefits and reduce burdens for highly impacted communities and vulnerable populations;
(ii) Estimating the degree to which such benefits will be equitably distributed and burdens reduced over the CEAP's ten-year horizon; and
(iii) Describing how the specific actions are consistent with the long-term strategy described in WAC 480-100-620 (11)(g).
(d) Establish a resource adequacy requirement;
(e) Identify the potential cost-effective demand response and load management programs that may be acquired;
(f) Identify renewable resources, nonemitting electric generation, and distributed energy resources that may be acquired and evaluate how each identified resource may reasonably be expected to contribute to meeting the utility's resource adequacy requirement;
(g) Identify any need to develop new, or to expand or upgrade existing, bulk transmission and distribution facilities;
(h) Identify the nature and possible extent to which the utility may need to rely on an alternative compliance option identified under RCW 19.405.040 (1)(b), if appropriate; and
(i) Incorporate the social cost of greenhouse gas emissions as a cost adder as specified in RCW 19.280.030(3).
(13) Avoided cost and nonenergy impacts. The IRP must include an analysis and summary of the avoided cost estimate for energy, capacity, transmission, distribution, and greenhouse gas emissions costs. The utility must list nonenergy costs and benefits addressed in the IRP and should specify if they accrue to the utility, customers, participants, vulnerable populations, highly impacted communities, or the general public. The utility may provide this content as an appendix.
(14) Data disclosure. The utility must include the data input files made available to the commission in native format per RCW 19.280.030 (10)(a) and (b) and in an easily accessible format as an appendix to the IRP. For filing confidential information, the utility may designate information within the data input files as confidential, provided that the information and designation meet the requirements of WAC 480-07-160.
(15) Information relating to purchases of electricity from qualifying facilities. Each utility must provide information and analysis that it will use to inform its annual filings required under chapter 480-106 WAC. The detailed analysis must include, but is not limited to, the following components:
(a) A description of the methodology used to calculate estimates of the avoided cost of energy, capacity, transmission, distribution and emissions averaged across the utility; and
(b) Resource assumptions and market forecasts used in the utility's schedule of estimated avoided cost required in WAC 480-106-040 including, but not limited to, cost assumptions, production estimates, peak capacity contribution estimates and annual capacity factor estimates.
(16) Report of substantive changes. The IRP must include a summary of substantive changes to modeling methodologies or inputs that result in changes to the utility's resource need, as compared to the utility's previous IRP.
(17) Summary of public comments. The utility must provide a summary of public comments received during the development of its IRP and the utility's responses, including whether issues raised in the comments were addressed and incorporated into the final IRP as well as documentation of the reasons for rejecting any public input. The utility may include the summary as an appendix to the final IRP. Comments with similar content or input may be consolidated with a single utility response.
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-620, filed 12/28/20, effective 12/31/20.]


PDF480-100-625

Integrated resource plan development and timing.

(1) Timing. Unless otherwise ordered by the commission, each electric utility must file an integrated resource plan (IRP) with the commission by January 1, 2021, and every four years thereafter.
(2) IRP work plan. No later than 15 months prior to the due date of its IRP, the utility must file a work plan that includes advisory group input and outlines the content of the IRP and expectations for the subsequent two-year progress report. The utility must include the following in its work plan:
(a) The methods for assessing potential resources;
(b) A proposed schedule of meetings for the utility's resource planning advisory group and equity advisory group, as established in WAC 480-100-655 (1)(b), for the IRP;
(c) A list of significant topics, consistent with WAC 480-100-620, that will be discussed at each advisory group meeting for the IRP;
(d) The date the draft IRP will be filed with the commission;
(e) The date the final IRP will be filed;
(f) A link to the utility's website, updated in a timely manner, to which the utility posts and makes publicly available information related to the IRP, including information outlined in subsection (5) of this section;
(g) If the utility anticipates significant changes in the workplan, it must file an updated workplan.
(3) Draft IRP. No later than four months prior to the due date of the final IRP, the utility must file its draft IRP with the commission. At minimum, the draft IRP must include the preferred portfolio, CEAP, and supporting analysis, and to the extent practicable all scenarios, sensitivities, appendices, and attachments.
(a) The commission will hear public comment on the draft IRP at an open meeting scheduled after the utility files its draft IRP. The commission will accept public comments electronically and in any other available formats, as outlined in the commission's notice for the open public meeting and opportunity to comment.
(b) The utility must file with the commission completed presentation materials concerning the draft IRP at least five business days prior to the open meeting.
(4) Two-year progress report. At least every two years after the utility files its IRP, beginning January 1, 2023, the utility must file a two-year progress report.
(a) In this report, the utility must update its:
(i) Load forecast;
(ii) Demand-side resource assessment, including a new conservation potential assessment;
(iii) Resource costs; and
(iv) The portfolio analysis and preferred portfolio.
(b) The progress report must include other updates that are necessary due to changing state or federal requirements, or significant changes to economic or market forces.
(c) The progress report must also update for any elements found in the utility's current clean energy implementation plan, as described in WAC 480-100-640.
(5) Publicly available information. The utility must make the following information publicly available on its website:
(a) Meeting summaries and materials for advisory group meetings, including materials for future meetings;
(b) A current schedule of advisory group meetings and significant topics to be covered, actively updated by the company and changes highlighted;
(c) Information on how members of the public may participate in advisory group meetings; and
(d) Advisory group comments about the IRP and its development received to date, including responses communicating how the subject of the input was considered or used. Comments with similar content or input may be consolidated with a single utility response.
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-625, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-625, filed 12/28/20, effective 12/31/20.]


PDF480-100-630

Integrated resource planning advisory groups.

(1) The utility must demonstrate and document how it considered input from advisory group members in the development of its IRP and two-year progress report. Examples of how the utility may incorporate advisory group input include using modeling scenarios, sensitivities, and assumptions advisory group members proposed and using data and information supplied by advisory group members as inputs to plan development. As part of this process and consistent with WAC 480-100-625(5), the utility must communicate to advisory group members about whether and how the utility used their input in its analysis and decision making, including explanations for why the utility did not use an advisory group member's input.
(2) The utility must make available completed presentation materials for each advisory group meeting at least three business days prior to the meeting. The utility may update materials as needed.
(3) The utility must make all its data inputs and files used to develop its IRP available to the commission in native file format, per RCW 19.280.030 (10)(a) and (b), and in an easily accessible format. The utility may make confidential information available by providing it to the commission pursuant to WAC 480-07-160. The utility should minimize its designation of information in the IRP as confidential. Nonconfidential contents of the IRP, two-year progress report, and supporting documentation as well as nonconfidential data inputs and files must be available for advisory group member review in an easily accessible format upon request. Nothing in this subsection limits the protection of records containing commercial information under RCW 80.04.095.
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-630, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-630, filed 12/28/20, effective 12/31/20.]


PDF480-100-640

Content of a clean energy implementation plan (CEIP).

(1) Filing requirements – General. Unless otherwise ordered by the commission, each electric utility must file with the commission a CEIP by October 1, 2021, and every four years thereafter. The CEIP describes the utility's plan for making progress toward meeting the clean energy transformation standards and is informed by the utility's clean energy action plan. The information and documents described in each subsection below must be included in each CEIP.
(2) Interim targets.
(a) Each utility must propose a series of interim targets that:
(i) Demonstrate how the utility will make reasonable progress toward meeting the standards identified in WAC 480-100-610 (2) and (3); and
(ii) Are consistent with WAC 480-100-610(4).
(b) Each utility must propose interim targets in the form of the percent of forecasted retail sales of electricity supplied by nonemitting and renewable resources prior to 2030 and from 2030 through 2045.
(c) The utility must include the utility's percentage of retail sales of electricity supplied by nonemitting and renewable resources in 2020 in the first CEIP it files.
(d) Each interim target must be informed by the utility's historic performance under median water conditions.
(3) Specific targets.
(a) Each utility must propose specific targets for energy efficiency, demand response, and renewable energy.
(i) The energy efficiency target must encompass all other energy efficiency and conservation targets and goals the commission requires the utility to meet. The specific energy efficiency target must be described in the utility's biennial conservation plan required in chapter 480-109 WAC. The utility must provide forecasted distribution of energy and nonenergy costs and benefits.
(ii) The utility must provide proposed program details, program budgets, measurement and verification protocols, target calculations, and forecasted distribution of energy and nonenergy costs and benefits for the utility's demand response target.
(iii) The utility must propose the renewable energy target as the percent of retail sales of electricity supplied by renewable resources and must provide details of renewable energy projects or programs, program budgets as applicable, and forecasted distribution of energy and nonenergy costs and benefits.
(b) The utility must provide a description of the technologies, data collection, processes, procedures, and assumptions the utility used to develop the targets in this subsection. The utility must make data input files that are used to determine relevant targets available in native format and in an easily accessible format as an appendix.
(4) Customer benefit data. Each CEIP must:
(a) Identify highly impacted communities using the cumulative impact analysis pursuant to RCW 19.405.140 combined with census tracts at least partially in Indian country;
(b) Identify vulnerable populations based on adverse socioeconomic factors and sensitivity factors developed through the advisory group process and public participation plan described in WAC 480-100-655, describing and explaining any changes from the utility's most recently approved CEIP; and
(c) Include proposed or updated customer benefit indicators and associated weighting factors related to WAC 480-100-610 (4)(c) including, at a minimum, one or more customer benefit indicators associated with energy benefits, nonenergy benefits, reduction of burdens, public health, environment, reduction in cost, reduction in risk, energy security, and resiliency. Customer benefit indicators and weighting factors must be developed consistent with the advisory group process and public participation plan described in WAC 480-100-655. The utility should describe and explain any changes in customer benefit indicators or weighting factors from its most recently approved CEIP.
(5) Specific actions. Each CEIP must include the specific actions the utility will take over the implementation period. The specific actions must meet and be consistent with the clean energy transformation standards and be based on the utility's clean energy action plan and interim and specific targets. Each CEIP must present the specific actions in a tabular format that provides the following information for each specific action:
(a) The general location, if applicable, proposed timing, and estimated cost of each specific action or remaining resource need, including whether the resource will be located in highly impacted communities, will be governed by, serve, or otherwise benefit highly impacted communities or vulnerable populations in part or in whole;
(b) Metrics related to resource adequacy including contributions to capacity or energy needs; and
(c) Customer benefit indicator values, or a designation as nonapplicable, for every customer benefit indicator described in subsection (4)(c) of this section.
(6) Narrative description of specific actions. The CEIP must describe how the specific actions:
(a) Demonstrate progress toward meeting the standards identified in WAC 480-100-610 (2) and (3).
(b) Demonstrate consistency with the standards identified in WAC 480-100-610(4) including, but not limited to:
(i) An assessment of current benefits and burdens on customers, by location and population, and the projected impact of specific actions on the distribution of customer benefits and burdens during the implementation period.
(ii) A description of how the specific actions in the CEIP mitigate risks to highly impacted communities and vulnerable populations and are consistent with the longer-term strategies and actions described in the utilities most recent IRP and CEAP as required by WAC 480-100-620 (11)(g) and (12)(c).
(c) Are consistent with the proposed interim and specific targets.
(d) Are consistent with the utility's integrated resource plan.
(e) Are consistent with the utility's resource adequacy requirements, including a narrative description of how the resources identified in the most recent resource adequacy assessment conducted or adopted by the utility demonstrates that the utility will meet its resource adequacy standard.
(f) Demonstrate how the utility is planning to meet the clean energy transformation standards at the lowest reasonable cost including, but not limited to:
(i) A description of the utility's approach to identifying the lowest reasonable cost portfolio of specific actions that meet the requirements of (a) through (e) of this subsection, including a description of its methodology for weighing considerations in WAC 480-100-610(4);
(ii) A description of the utility's methodology for selecting the investments and expenses it plans to make over the next four years that are directly related to the utility's compliance with the clean energy transformation standards, consistent with RCW 19.405.050 (3)(a), and a demonstration that its planned investments represent a portfolio approach to investment plan optimization; and
(iii) Supporting documentation justifying each specific action identified in the CEIP.
(7) Projected incremental cost. Each CEIP must include a projected incremental cost as outlined in WAC 480-100-660(4).
(8) Public participation. Each CEIP must detail the extent of advisory group and other public participation in the development of the CEIP as described in WAC 480-100-655 including, but not limited to, a summary of advisory group member comments described in WAC 480-100-655 (1)(i).
(9) Alternative compliance. The utility must describe any plans it has to rely on alternative compliance mechanisms as described in RCW 19.405.040 (1)(b).
(10) Early action coal credit. If the utility proposes to take the early action compliance credit authorized in RCW 19.405.040(11), the utility must satisfy the requirements in that statutory provision and demonstrate that the proposed action constitutes early action by presenting the analysis in subsection (6) of this section both with and without the proposed early action. The utility must compare both the proposed early action and the alternative against the same proposed interim and specific targets.
(11) Biennial CEIP update. The utility must make a biennial CEIP update filing on or before November 1st of each odd-numbered year that the utility does not file a CEIP. The CEIP update may be limited to the biennial conservation plan requirements under chapter 480-109 WAC. The utility must file its biennial CEIP update in the same docket as its most recently filed CEIP and include an explanation of how the update will modify targets in its CEIP. In addition to its proposed biennial conservation plan, the utility may file in the update other proposed changes to the CEIP as a result of the integrated resource plan progress report.
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-640, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-640, filed 12/28/20, effective 12/31/20.]


PDF480-100-645

Process for review of CEIP and updates.

(1) Public comment. Interested persons may file written comments with the commission regarding a utility's CEIP and biennial CEIP update within sixty days of the utility's filing unless the commission states otherwise.
(2) Approval process. The utility's CEIP and biennial CEIP update filing will be set for an open public meeting. On the commission's own motion or at the request of any person who has a substantial interest in the subject matter of the filing, the commission will initiate an adjudication, or if appropriate a brief adjudicative proceeding, to consider the filing. The commission will enter an order approving, rejecting, or approving with conditions the utility's CEIP or CEIP update at the conclusion of its review. The commission may, in its order, recommend or require more stringent targets than those the utility proposes.
(a) The commission may adjust or expedite interim and specific target timelines when issuing a decision on a CEIP or biennial CEIP updates.
(b) Any party requesting the commission make existing targets more stringent or adjust existing timelines has the burden of demonstrating the utility can achieve the targets or timelines in a manner consistent with the requirements of RCW 19.405.060 (1)(c)(i) through (iv).
[Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-645, filed 12/28/20, effective 12/31/20.]


PDF480-100-650

Reporting and compliance.

(1) Clean energy compliance report. Unless otherwise ordered by the commission, each electric utility must file a clean energy compliance report with the commission by July 1, 2026, and at least every four years thereafter. The report must:
(a) Demonstrate whether and how the utility met its interim targets.
(b) Demonstrate whether and how the utility met its specific targets.
(c) Demonstrate whether and how the specific actions the utility took made progress toward meeting the clean energy transformation standards at the lowest reasonable cost.
(d) Demonstrate whether and how the utility met its statutory obligations under RCW 19.405.040(1) and 19.405.050(1) through the acquisition of the electricity and associated RECs or nonpower attributes. This requires the utility to demonstrate that the electricity the utility reports for compliance is:
(i) From a generating facility located within the utility's service area or balancing authority area; or
(ii) Acquired by the utility at one of the following points of delivery:
(A) The transmission or distribution system of an electric utility;
(B) The transmission system of the Bonneville Power Administration;
(C) The transmission system of any entity that is a participant in a centralized organized market located in the Western Interconnection in which the electric utility is a participant; or
(D) Another point of delivery designated by the electric utility for the purpose of subsequent delivery to the electric utility.
(e) Demonstrate whether and how the specific actions the utility took are consistent with the requirements in WAC 480-100-610 (4)(c) including, but not limited to:
(i) Providing updated customer benefit indicator values;
(ii) An analysis that the distribution of benefits and reductions of burdens have accrued or will reasonably accrue to intended customers, including highly impacted communities and vulnerable populations.
(f) Provide a description of the utility's equity advisory group process, customer engagement and outcomes, and how the utility's efforts are consistent with the requirements in WAC 480-100-655 for the development or update of customer benefit indicators related to WAC 480-100-610 (4)(c).
(g) Include the actual incremental cost of compliance as required in WAC 480-100-660(5).
(h) Include all of the information found in the annual progress report as described in subsection (4) of this section for the fourth year of the CEIP.
(i) Include a summary of the data in the annual progress reports described in subsection (4) of this section.
(j) Document the use of any alternative compliance options as described in RCW 19.405.040 (1)(b), or any request for a temporary exemption per RCW 19.405.090(3).
(k) Include a description of the public participation opportunities the utility provided and the feedback the utility received during the implementation period, including whether and how public participation influenced the utility's decisions and actions.
(l) Include the data input files made available to the commission in native format and in an easily accessible format as an appendix.
(2) Clean energy compliance report review process.
(a) Interested persons may file written comments with the commission regarding the utility's clean energy compliance report within 60 days of the utility's filing unless the commission states otherwise.
(b) The commission may review clean energy compliance reports through the commission's open public meeting process, as described in chapter 480-07 WAC.
(c) After completing its review of the utility's clean energy compliance report, the commission will determine whether the utility met its specific and interim targets, and whether the utility made sufficient progress toward meeting the clean energy transformation standards.
(3) Annual clean energy progress reports. On or before July 1st of each year beginning in 2023, other than in a year in which the utility files a clean energy compliance report, the utility must file with the commission, in the same docket as its most recently filed CEIP, an informational annual clean energy progress report regarding its progress in meeting its targets during the preceding year. The annual clean energy progress report must include, but is not limited to:
(a) Beginning July 1, 2027, and each year thereafter, an attestation for the previous calendar year that the utility did not use any coal-fired resource as defined in this chapter to serve Washington retail electric customer load.
(b) Conservation achievement in megawatts, first-year megawatt-hour savings, and projected cumulative lifetime megawatt-hour savings.
(c) Demand response program achievement and demand response capability in megawatts and megawatt hours.
(d) Renewable resource capacity in megawatts, and renewable energy usage in megawatt hours and as a percentage of electricity supplied by renewable resources.
(e) All renewable energy credits and the program or obligation for which they were used (e.g., voluntary renewable programs, renewable portfolio standard, clean energy transformation standards).
(f) Verification and documentation of the retirement of renewable energy credits for all electricity from renewable resources used to comply with the requirements of RCW 19.405.040, 19.405.050, a specific target, or an interim target, except for electricity purchased from Bonneville Power Administration, which may be used to comply with these requirements without a renewable energy credit until January 1, 2029, as long as the nonpower attributes of the renewable energy are tracked through contract language.
(g) Nonemitting resource capacity in megawatts, and nonemitting energy usage in megawatt hours and as a percentage of total electricity supplied by nonemitting energy.
(h) The utility's greenhouse gas content calculation pursuant to RCW 19.405.070.
(i) An electronic link to the utility's most recently filed fuel mix disclosure report as required by RCW 19.29A.140.
(j) Total greenhouse gas emissions in metric tons of CO2e.
(k) Demonstration of ownership of nonpower attributes for nonemitting generation using attestations of ownership and transfer by properly authorized representatives of the generating facility, all intermediate owners of the nonemitting electric generation, and an appropriate company executive of the utility; the utility may not transfer ownership of the nonpower attributes after claiming them in any compliance report.
(l) Other information the company agreed to or was ordered to report in the most recently approved CEIP or biennial CEIP update.
(4) Data and contract reporting. Each utility must file its annual clean energy progress report based on an analysis that identifies and considers the source and characteristics of the electricity a utility claims to meet compliance obligations under WAC 480-100-610, including electricity that is produced, purchased, sold, or exchanged.
(a) Unless otherwise ordered by the commission, the analysis and supporting data provided in the filing must include data in an hourly format for:
(i) Total Washington retail sales.
(ii) Retail sales for customers participating in a voluntary renewable energy purchase program in alignment with RCW 19.405.020 (36)(b).
(iii) Total electricity production for all renewable and nonemitting generation owned, contracted, or controlled by the utility.
(iv) Generation from qualifying facilities as described in RCW 19.405.020 (36)(a).
(v) All electricity sold or transferred for all bundled sales of electricity from renewable and nonemitting sources. For the purposes of this subsection, bundled electricity is electricity that is sold with all its nonpower attributes in the same transaction.
(vi) All electricity sales in which the electricity was sold by that utility in a wholesale market sale without its associated nonpower attributes.
(b) Unless otherwise ordered by the commission, the utility must include in its filing the following:
(i) Total monthly megawatt-hours of sales, purchases, and exchanges by counter party of electricity sales in which the electricity was sold by that utility in a wholesale market sale without its associated nonpower attributes. Any contract in which the utility sells electricity in a wholesale market sale without its associated nonpower attributes must include terms stating the seller is not transferring any of the nonpower attributes and the buyer may not represent in any form that the electricity has any nonpower attributes associated with it and that the buyer must include such provision in any sale of the electricity in any subsequent sale it makes.
(ii) Total monthly megawatt-hours of sales, purchases, and exchanges of bundled electricity from renewable or nonemitting generation. For the purposes of this subsection, bundled electricity is electricity that is sold with all of its nonpower attributes in the same transaction.
(iii) All purchase contracts longer than one month that source the electricity delivered from coal fueled generation.
(iv) Beginning January 1, 2026, all existing or new purchase contracts longer than one month with documentation that none of the electricity delivered is sourced from coal fueled generation.
(v) Any data provided to the Western power pool's resource adequacy program or its successor.
(c) A utility may use an unbundled REC as an alternative compliance option, as provided in RCW 19.405.040 (1)(b), only if the utility demonstrates that there is no double counting of any nonpower attribute associated with that REC. This subsection sets only the minimum requirements necessary to demonstrate that no double counting has occurred. The commission may require the utility to produce other evidence or take specific actions as the commission determines necessary to ensure that there is no double counting of nonpower attributes.
(i) Except as provided in (c)(iii) of this subsection, a utility may use an unbundled REC for alternative compliance only if the utility demonstrates:
(A) The associated electricity was sold, delivered, or transferred without fuel sources or nonpower attributes and under a contract or transaction term expressly stating the fuel source or nonpower attributes are not included; and
(B) The associated electricity was not delivered, reported, or claimed as a zero-emission specified source or assigned the emissions rate of the renewable generating facility under a greenhouse gas (GHG) program.
(ii) A utility's demonstration under this section may be met by documentation that the entity providing the unbundled REC:
(A) Provides contract, confirmation, or other transaction terms that comply with the requirements of (c)(i)(A) and (B) of this subsection;
(B) Was a party to or otherwise has knowledge of the transaction in which the associated electricity was sold or transferred and attests to (c)(i)(A) and (B) of this subsection; or
(C) Obtained the unbundled REC from an entity that attests that it and all previous owners of the REC transferred the REC using transaction terms complying with the requirements of (c)(ii)(A) or (B) of this subsection.
(iii) To claim and retire an unbundled REC for alternative compliance where the Washington-eligible RECs were created by renewable electricity marketed by the Bonneville Power Administration a utility must demonstrate the REC was not associated with electricity from a system sale from the Bonneville Power Administration directly into a state with a GHG program and to an entity regulated by the state greenhouse gas program. The RECs are calculated based on the same vintage year as the year in which the electricity was imported to the state with the greenhouse gas program.
(iv) For the purposes of (c) of this subsection, "greenhouse gas program" includes any governmental program outside of Washington that caps or limits greenhouse gas emissions or requires the purchase, surrender, or retirement of greenhouse gas allowances if the scope of the greenhouse gas program includes electricity imported from outside the governmental jurisdiction and does not require the retirement of RECs for such imported electricity.
(d) For the purposes of reporting and compliance, the storage of electricity has the following impacts:
(i) The eligibility of renewable or nonemitting electricity is not affected by the use of storage resources.
(ii) Except for storage resources located on the customer side of a retail meter, any electrical consumption or loss resulting from the charging, holding, and discharging of storage resources is not considered retail electric load as defined in RCW 19.405.020(36).
(iii) Any electrical consumption or loss resulting from the charging, holding, and discharging of storage resources located on the customer side of a retail meter is considered retail electric load for the purpose of compliance with chapter 19.405 RCW.
(5) Commission staff information requests. Nothing in this rule affects the utility's obligation to provide any additional information or data requested by commission staff.
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-650, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-650, filed 12/28/20, effective 12/31/20.]


PDF480-100-655

Public participation in a clean energy implementation plan (CEIP).

(1) Advisory groups. The utility must demonstrate and document how it considered input from advisory group members in the development of its CEIP and biennial CEIP update. Examples of how the utility may incorporate advisory group input include: Using modeling scenarios, sensitivities, and assumptions advisory group members proposed and using data and information supplied by advisory group members as inputs to plan development. As part of this process and consistent with (i) of this subsection, the utility must communicate to advisory group members about whether and how the utility used their input in its analysis and decision-making, including explanations for why the utility did not use an advisory group member's input.
(a) The utility must involve all advisory groups in the development of its CEIP and its biennial CEIP update, including the equity advisory group identified in (b) of this subsection.
(b) The utility must maintain and regularly engage an external equity advisory group to advise the utility on equity issues including, but not limited to, vulnerable population designation, equity customer benefit indicator development, data support and development, and recommended approaches for the utility's compliance with WAC 480-100-610 (4)(c)(i). The utility must encourage and include the participation of environmental justice and public health advocates, tribes, and representatives from highly impacted communities and vulnerable populations in addition to other relevant groups.
(c) The utility must convene advisory groups, with reasonable advance notice, at regular meetings open to the public during the planning process. A utility must notify advisory groups of company and commission public meetings scheduled to address its CEIP and biennial CEIP update.
(d) Engaging with advisory groups for the purposes of developing the CEIP does not relieve the utility of the obligation to continue to convene and engage these groups for their individual topical duties. This section does not supersede existing rules related to those groups.
(e) Nothing in this section limits the utility from convening and engaging public advisory groups on other topics.
(f) Participation in an advisory group does not restrict groups and individuals from commenting on CEIP filings before the commission.
(g) The utility must make available completed presentation materials for each advisory group meeting at least three business days prior to the meeting. The utility may update materials as needed.
(h) The utility must make all its data inputs and files used to develop its CEIP available to the commission in native file format and in an easily accessible format. The utility may make confidential information available by providing it to the commission pursuant to WAC 480-07-160. The utility should minimize its designation of information in the CEIP as confidential. Nonconfidential contents of the CEIP, biennial update, and supporting documentation as well as nonconfidential data inputs and files must be available for advisory group review in an easily accessible format upon request. Nothing in this subsection limits the protection of records containing commercial information under RCW 80.04.095.
(i) As part of the filing of its CEIP and biennial update with the commission, the utility must provide a summary of advisory group comments received during the development of its CEIP and biennial update and the utility's responses, including whether issues raised in the comments were addressed and incorporated into the final CEIP as well as documentation of the reasons for rejecting public input. The utility must include the summary as an appendix to the final CEIP. Comments with similar content or input may be consolidated with a single utility response.
(2) Participation plan and education. The utility must involve advisory groups in developing the timing and extent of meaningful and inclusive public participation throughout the development and duration of the CEIP, including outreach and education serving vulnerable populations and highly impacted communities. On or before May 1st of each odd-numbered year, the utility must file with the commission a plan that outlines its schedule, methods, and goals for public participation and education both during the development of its CEIP and throughout the implementation of the plan. The utility must include the following in its participation plan:
(a) Timing, methods, and language considerations for seeking and considering input from:
(i) Vulnerable populations and highly impacted communities for the creation of or updates to customer benefit indicators and weighting factors for the utility's compliance with WAC 480-100-610 (4)(c)(i); and
(ii) All customers, including vulnerable populations and highly impacted communities, for the creation of, or updates to, customer benefit indicators and weighting factors for the utility's compliance with WAC 480-100-610 (4)(c)(ii) and (iii).
(b) Identification of barriers to public participation including, but not limited to, language, cultural, economic, or other factors, and strategies for reducing barriers to public participation.
(c) Plans to provide information and data in broadly understood terms through meaningful participant education.
(d) A proposed schedule of public meetings or engagement, including advisory group meetings.
(e) A proposed list of significant topics that will be discussed.
(f) The date the utility will file the final CEIP with the commission.
(g) A link to a website accessible to the public and managed by the utility, to which the utility posts and makes publicly available the following information:
(i) Meeting summaries and materials for all relevant meetings, including materials for future meetings;
(ii) A current schedule of advisory group meetings and significant topics to be covered;
(iii) Information on how the public may participate in CEIP development; and
(iv) Final plans and biennial CEIP updates posted within 30 days of final commission action.
(3) Customer notices. Within 30 days of filing the utility's CEIP, the utility must inform customers of the filing and requirements under chapter 19.405 RCW, briefly summarize the utility's CEIP, and inform customers of how they may comment on the utility's filing. The notice must include:
(a) The date the notice is issued;
(b) The utility's name and address;
(c) A website link that navigates to the full CEIP;
(d) A statement that the commission has the authority to approve the CEIP, with or without conditions, or reject the CEIP;
(e) A description of how customers may contact the utility if they have specific questions or need additional information about the CEIP; and
(f) Public involvement language pursuant to WAC 480-100-194 (4)(j).
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-655, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-655, filed 12/28/20, effective 12/31/20.]


PDF480-100-660

Incremental cost of compliance.

(1) Incremental cost methodology. To determine the incremental cost of the actions a utility takes to comply with RCW 19.405.040 and 19.405.050, the utility must compare its lowest reasonable cost portfolio to the alternative lowest reasonable cost and reasonably available portfolio. The utility should use a portfolio optimization model, such as the one used in its most recent IRP, as the basis for calculating the alternative lowest reasonable cost and reasonably available portfolio to show the difference in portfolio choices and investment needs between the two portfolios, and demonstrate which investments and expenses are directly attributable costs to meet the requirements of RCW 19.405.040 and 19.405.050.
(a) The utility may include in its documentation of both portfolios those investments and expenses that are not reflected in the portfolio optimization if the utility demonstrates that the investment or expense could not reasonably have been reflected in the portfolio optimization model.
(b) If the portfolios provided are the result of a model, the utility must provide a fully linked and electronically functional copy of that model as part of its workpapers.
(c) The utility may propose an alternative incremental cost methodology if it can demonstrate that it meets the requirements of a methodology as described in RCW 19.405.060 (3) and (5), and that it will comply with RCW 19.405.040 and 19.405.050 at the lowest reasonable cost.
(2) Incremental cost calculation. The utility must calculate the average annual threshold amount for determining eligibility for reliance on RCW 19.405.060(3) as a means of compliance. The average annual threshold amount is equal to a two percent increase over the utility's weather-adjusted sales revenue to customers from each previous year, divided by the number of years in the period. For a period consisting of four years, the mathematical formula for the annual threshold amount is:
Annual Threshold Amount
=
(WASR0 × 2% × 4) + (WASR1 × 2% × 3) + (WASR2 × 2% × 2) + (WASR3 × 2%)
4
(3) Directly attributable costs. An investment or expense is directly attributable only if all the following conditions are satisfied:
(a) The utility made the investment or incurred the expense during the implementation period.
(b) The investment or expense is part of the lowest reasonable cost portfolio that results in compliance with RCW 19.405.040 and 19.405.050.
(c) The investment or expense is additional to the costs that the utility would incur for the alternative lowest reasonable cost and reasonably available portfolio.
(d) The investment or expense is not required to meet any statutory, regulatory, or contractual requirement or any provision of chapter 19.405 RCW other than RCW 19.405.040 or 19.405.050.
(4) Projected incremental cost. The utility must file projected incremental cost estimates in each CEIP using the methodology described in subsection (1) of this section and using projected weather-adjusted sales revenue in the calculation in subsection (2) of this section to estimate the average annual threshold amount for the implementation period. The utility must support the projections with workpapers, models, and associated calculations, and must:
(a) Identify all investments and expenses that the utility plans to make during the period in order to comply with the requirements of RCW 19.405.040 and 19.405.050.
(b) Demonstrate that the investments and expenses identified in (a) of this subsection are directly attributable to actions necessary to comply with, or make progress towards, the requirements of RCW 19.405.040 and 19.405.050.
(c) Provide the expected cost of the utility's planned activities and the expected cost of the alternative lowest reasonable cost and reasonably available portfolio.
(5) Reported actual incremental costs. In each CEIP compliance report as described in WAC 480-100-650, the utility must file the actual incremental costs using the methodology described in subsection (1) of this section and the calculation in subsection (2) of this section. The utility must support its filing by providing the following information:
(a) The actual costs the utility incurred during the implementation period. Presentation of capital and expense accounts should be reported by Federal Energy Regulatory Commission (FERC) account by year.
(b) A demonstration that the reported incremental cost is directly attributable to specific actions the utility has taken that were necessary to comply with RCW 19.405.040 and 19.405.050, per subsection (2) of this section.
(c) Documentation of the cost of the alternative lowest reasonable cost and reasonably available portfolio; the utility must update verifiable and material inputs of this portfolio with the most recent information available.
(d) If the utility uses the incremental cost compliance option as described in this subsection, a demonstration that during the implementation period the average annual incremental cost of meeting the standards or the interim targets equals or exceeds a two percent annual increase of the investor-owned utility's weather-adjusted electric retail sales revenue to customers for electric operations above the previous year.
(e) An explanation for the variance between the projected incremental cost in subsection (3) of this section and the actual incremental costs reported in subsection (4) of this section.
(f) Workpapers and calculations supporting the incremental cost calculations.
(6) Determination of incremental cost of compliance option.
(a) For any implementation period in which the utility relies on RCW 19.405.060(3) as the basis for compliance with the standard under RCW 19.405.040(1) or 19.405.050(1), the utility must request a determination from the commission when filing its clean energy compliance report, per WAC 480-100-650.
(b) The utility must also provide evidence that, if the utility relied on alternative compliance options allowed under RCW 19.405.040 (1)(b) during the applicable period, the utility has maximized investments in renewable resources and nonemitting electric generation before relying on these alternative compliance options.
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-660, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-660, filed 12/28/20, effective 12/31/20.]


PDF480-100-665

Enforcement.

(1) General. The commission may take enforcement action in response to a utility's failure to comply with the provisions of chapter 19.405 RCW, this chapter of the commission's rules, or a commission order implementing those requirements.
(2) Procedure. The commission may take enforcement action in the following types of proceedings:
(a) Complaint. The commission may bring a complaint against the utility pursuant to RCW 80.04.380 and WAC 480-07-300, et seq.
(b) Penalty assessment. The commission may assess penalties as provided in RCW 80.04.405 and WAC 480-07-915.
(c) Other. The commission may take enforcement action in any proceeding in which the utility's compliance with the provisions of chapter 19.405 RCW, this chapter of the commission's rules, or a commission order implementing those requirements is at issue including, but not limited to, the utility's general rate case.
(3) Remedies. The commission may impose any one or a combination of the following remedies for a utility's failure to comply with the provisions of chapter 19.405 RCW, this chapter of the commission's rules, or a commission order implementing those requirements.
(a) RCW 19.405.090. For all violations subject to the compliance, enforcement, and penalty provisions of RCW 19.405.090, the commission may require the utility to pay an administrative penalty of $100 multiplied by the applicable megawatt-hour of electric generation used to meet load that is not electricity from a renewable resource or nonemitting electric generation.
(b) For violations of rule or order not subject to RCW 19.405.090, the commission may pursue the following remedies:
(i) RCW 80.04.380. The commission may assess penalties of up to $1,000 for each violation. Violation of the same requirement in statute, rule, or commission order are separate and distinct violations, and each day the utility is not in compliance with these requirements is a separate and distinct violation.
(ii) RCW 80.04.405. The commission may assess penalties of $100 for each violation. Violation of the same requirement in statute, rule, or commission order are separate and distinct violations, and each day the utility is not in compliance with these requirements is a separate and distinct violation.
(c) Specific performance. The commission may order a utility to take specific actions necessary to comply with chapter 19.405 RCW, this chapter of the commission's rules, and commission orders implementing those requirements.
(d) Customer notification. If the commission finds a utility in violation of chapter 19.405 RCW, this chapter of the commission's rules, or commission orders implementing those requirements, the commission may order the utility to notify its retail electric customers of the violation in a published form.
(4) Mitigation. A utility may request mitigation of, and the commission may mitigate, any administrative penalty as described in RCW 19.405.090(3) or penalty assessment as provided in WAC 480-07-915. Any mitigation the commission grants does not relieve the utility of its obligation to comply with applicable legal requirements or to take specific actions the commission orders.
[Statutory Authority: RCW 80.01.040, 80.04.160, 19.285.080, and 19.405.100. WSR 22-14-055 (Docket UE-210183, General Order R-604), § 480-100-665, filed 6/29/22, effective 7/1/22. Statutory Authority: RCW 80.01.040, 80.04.160, and chapters 80.28, 19.280, and 19.405 RCW. WSR 21-02-022 (Dockets UE-191023 and UE-190698, General Order 601), § 480-100-665, filed 12/28/20, effective 12/31/20.]


PDF480-100-999

Adoption by reference.

In this chapter, the commission adopts by reference all or portions of regulations and standards identified below. The publications, effective date, references within this chapter, and availability of the resources are as follows:
(1) Title 18 Code of Federal Regulations, cited as 18 C.F.R., including all appendices and amendments is published by the United States Government Publishing Office.
(a) The commission adopts the version in effect on April 1, 2023.
(b) The accounting and reporting for the types of transactions and events covered by the amendment should not be construed as indicative of their treatment by this commission for ratemaking purposes.
(c) This publication is referenced in WAC 480-100-203 (Accounting system requirements), WAC 480-100-244 (Transferring cash or assuming obligations), WAC 480-100-252 (Federal Energy Regulatory Commission (FERC) Form No. 1), and WAC 480-100-268 (Essential utilities services contracts report).
(d) Copies of Title 18 Code of Federal Regulations are available from the U.S. Government Publishing Office in Washington D.C., or online at https://www.gpo.gov/, and from various third-party vendors. It is also available for inspection at the commission library.
(2) The Regulations to Govern the Preservation of Records of Electric, Gas, and Water Utilities is published by the National Association of Regulatory Utility Commissioners (NARUC).
(a) The commission adopts the version in effect in 2007.
(b) This publication is referenced in WAC 480-100-228 (Retention and preservation of records and reports).
(c) The Regulations to Govern the Preservation of Records of Electric, Gas, and Water Utilities is a copyrighted document. Copies are available from NARUC in Washington, D.C. or at NARUC publications store online: https://maxxwww.naruc.org/forms/store/ProductFormPublic/regulations-to-govern-the-preservation-of-records. It is also available for inspection at the commission branch of the state library.
(3) The National Electrical Code is published by the National Fire Protection Association (NFPA).
(a) The commission adopts the edition effective in 2017, including errata 70-17-1 published September 29, 2016, errata 70-17-2 published December 16, 2016, 70-17-3 published January 11, 2017, 70-17-4 published March 13, 2017, errata 70-21-1 published October 10, 2019, errata 70-20-2 published December 23, 2019, and errata 70-20-3 published March 10, 2020.
(b) This publication is referenced in WAC 480-100-163 (Service entrance facilities).
(c) The National Electrical Code is a copyrighted document. Copies are available from the NFPA at 1 Batterymarch Park, Quincy, Massachusetts 02169, or at internet address https://www.nfpa.org/.
(4) The American National Standard for Electric Meters: Code for Electricity Metering, ANSI C12.1 is published by the American National Standards Institute.
(a) The commission adopts the version published in 2016.
(b) This publication is referenced in WAC 480-100-318 (Meter readings, multipliers, and test constants), WAC 480-100-338 (Accuracy requirements for electric meters), and WAC 480-100-343 (Statement of meter test procedures).
(c) The ANSI C12.1 is a copyrighted document. ANSI C12.1 – 2016 is available at American National Standards Institute website https://webstore.ansi.org/ (PDF) or at IHS Standards Store website https://global.ihs.com/ (PDF and print).
[Statutory Authority: RCW 80.10.040 [ 80.01.040], 80.04.160, 81.04.160, and 34.05.353. WSR 23-13-003, § 480-100-999, filed 6/7/23, effective 7/8/23; WSR 22-15-104, § 480-100-999, filed 7/19/22, effective 8/19/22; WSR 21-13-130, § 480-100-999, filed 6/22/21, effective 7/23/21; WSR 19-14-118, § 480-100-999, filed 7/3/19, effective 8/3/19; WSR 18-13-106, § 480-100-999, filed 6/19/18, effective 7/20/18. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.353. WSR 17-15-054 (Docket A-170015, General Order R-589), § 480-100-999, filed 7/13/17, effective 8/13/17; WSR 16-05-035 (Docket A-151884, General Order R-585), § 480-100-999, filed 2/9/16, effective 3/11/16; WSR 15-06-048 (Docket A-143302, General Order R-579), § 480-100-999, filed 3/2/15, effective 4/2/15; WSR 14-05-001 (Docket A-131761, General Order R-574), § 480-100-999, filed 2/5/14, effective 3/8/14; WSR 13-05-023 (Docket A-121496, General Order R-569), § 480-100-999, filed 2/11/13, effective 3/14/13; WSR 12-05-063 (Docket A-111722, General Order R-564), § 480-100-999, filed 2/15/12, effective 3/17/12; WSR 11-04-041 (Docket A-101466, General Order R-562), § 480-100-999, filed 1/25/11, effective 2/25/11; WSR 10-03-044 (Docket A-091124, General Order R-557), § 480-100-999, filed 1/14/10, effective 2/14/10; WSR 09-01-171 (Docket A-081419, General Order R-554), § 480-100-999, filed 12/23/08, effective 1/23/09; WSR 06-17-087 (Docket A-060475, General Order No. R-537), § 480-100-999, filed 8/14/06, effective 9/14/06; WSR 05-21-022 (Docket No. A-050271, General Order No. R-521), § 480-100-999, filed 10/10/05, effective 11/10/05; WSR 05-06-051 (Docket No. A-021178 and TO-030288, General Order No. R-518), § 480-100-999, filed 2/28/05, effective 3/31/05; WSR 04-01-152 (General Order No. R-511, Docket No. A-030852), § 480-100-999, filed 12/22/03, effective 1/22/04; WSR 02-18-033 (Docket No. A-020379, General Order No. R-501), § 480-100-999, filed 8/26/02, effective 9/26/02. Statutory Authority: RCW 80.01.040 and 80.04.160. WSR 01-11-004 (Docket No. UE-990473, General Order No. R-482), § 480-100-999, filed 5/3/01, effective 6/3/01.]
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