Original Notice.

     Preproposal statement of inquiry was filed as WSR 07-16-060 and 07-21-147.

     Title of Rule and Other Identifying Information: Chapter 480-93 WAC, Gas companies -- Safety. The Washington utilities and transportation commission (UTC) has identified several rules in chapter 480-93 WAC that need to be updated to establish consistency with statutory changes made to Titles 80 and 81 RCW resulting from the passage of SSB 5225 during the 2007 legislative session. This rule making will provide amendments to update definitions and in addition update the penalty rule WAC 480-93-223 to be consistent with federal law, delete a requirement in WAC 480-93-200, modify the quarterly fee installment dates in WAC 480-93-240(3) and update the reference date in the adoption by reference rule WAC 480-93-999 (1)(a).

     Hearing Location(s): Commission's Hearing Room 206, Second Floor, Richard Hemstad Building, 1300 South Evergreen Park Drive S.W., Olympia, WA 98504-7250, on May 15, 2008, at 1:30 p.m.

     Date of Intended Adoption: May 15, 2008.

     Submit Written Comments to: Washington Utilities and Transportation Commission, P.O. Box 47250, Olympia, WA 98504-7250, e-mail records@utc.wa.gov, fax (360) 586-1150, by April 25, 2008. Please include Docket PG-070975 in your communication.

     Assistance for Persons with Disabilities: Contact Mary DeYoung by Tuesday, May 13, 2008, TTY (360) 586-8203 or (360) 664-1133.

     Purpose of the Proposal and Its Anticipated Effects, Including Any Changes in Existing Rules: The proposed amendments are intended to update current rules to reflect changes in Titles 80 and 81 RCW resulting from the passage of SSB 5225 during the 2007 legislative session. The changes provide updated definitions in WAC 480-93-005 for "gas pipeline company" and the addition of two new definitions "emergency notification line" and a definition for "line pipe or pipe." The change in definition for "gas pipeline company" is applicable to most of the rules in chapter 480-93 WAC. In addition, WAC 480-93-007 Application of rules, adds to the title "responsibility for contractors" and a new subsection (3) defining a company's responsibility for its contractors. Deletion of the existing WAC 480-93-200 (1)(g) eliminates the requirement to report an incident based solely on news media coverage. WAC 480-93-223 increases the penalty amounts to be consistent with federal law, WAC 480-93-240(3) changes the quarterly fee installment dates, and WAC 480-93-999 (1)(a) updates the version date for the adoption by reference of federal rules. In addition rule language has been modified from the passive to active voice.

     Reasons Supporting Proposal: With the passage of SSB 5225, chapter 480-93 WAC must reflect the statutory changes to be consistent with state law. In addition, UTC staff and stakeholders have discovered areas of the rules that call for minor correction, updates, deletion, and revision. This proposal would address those areas.

     Statutory Authority for Adoption: RCW 80.01.040(4) and 81.88.065.

     Statute Being Implemented: Not applicable.

     Rule is not necessitated by federal law, federal or state court decision.

     Name of Proponent: Washington utilities and transportation commission, governmental.

     Name of Agency Personnel Responsible for Drafting: Sondra Walsh, Operations Manager, 1300 South Evergreen Park Drive S.W., Olympia, WA 98504, (360) 664-1286; and Implementation and Enforcement: Carole J. Washburn, Executive Secretary, 1300 South Evergreen Park Drive S.W., Olympia, WA 98504, (360) 664-1174.

     No small business economic impact statement has been prepared under chapter 19.85 RCW. The proposed corrections and changes to rules will not result in or impose an increase in costs. Because there will not be any increase in costs resulting from the proposed rule changes, a small business economic impact statement is not required under RCW 19.95.030(1).

     A cost-benefit analysis is not required under RCW 34.05.328. The UTC is not an agency to which RCW 34.05.328 applies. The proposed rules are not significant legislative rules of the sort reference[d] in RCW 34.05.328(5).

March 19, 2008

Carole J. Washburn

Executive Secretary

OTS-1366.3

AMENDATORY SECTION(Amending Docket PG-061027, General Order R-544, filed 8/23/07, effective 9/23/07)

WAC 480-93-005   Definitions.   (1) "Bar hole" means a hole made in the soil or paving for the specific purpose of testing the subsurface atmosphere with a combustible gas indicator.

     (2) "Building" means any structure that is normally or occasionally entered by humans for business, residential, or other purposes and where gas could accumulate.

     (3) "Business district" means an area where the public regularly congregates or where the majority of the buildings on either side of the street are regularly utilized, for financial, commercial, industrial, religious, educational, health, or recreational purposes.

     (4) "CFR" means the Code of Federal Regulations.

     (5) "Combustible gas indicator" (CGI) means a device capable of detecting and measuring gas concentrations in air.

     (6) "Commission" means the Washington utilities and transportation commission.

     (7) "Enclosed space" means any subsurface structure of sufficient size that could accommodate a person and within which gas could accumulate, e.g., vaults, catch basins, and manholes.

     (8) "Emergency notification line" means 1-888-321-9146.

     (9) "Follow-up inspection" means an inspection performed after a repair has been completed in order to determine the effectiveness of the repair.

     (((9))) (10) "Gas" means natural gas, flammable gas, or gas that is toxic or corrosive.

     (((10))) (11) "Gas associated substructures" means those devices or facilities utilized by ((an operator)) a gas pipeline company which are not intended for storing, transporting, or distributing gas, such as valve boxes, vaults, test boxes, and vented casing pipe.

     (((11))) (12) "Gas pipeline" means all parts of a pipeline facility through which gas moves in transportation, including, but not limited to, line pipe, valves, and other appurtenances connected to line pipe, compressor units, metering stations, regulator stations, delivery stations, holders and fabricated assemblies. "Gas pipeline" does not include any pipeline facilities, other than a master meter system, owned by a consumer or consumers of the gas, located exclusively on the consumer or consumers' property, and none of the gas leaves that property through a pipeline.

     (13) "Gas pipeline company" means((, as defined in RCW 80.04.010, every corporation, company, association, joint stock association, partnership and person, their lessees, trustees or receiver appointed by any court whatsoever, and every city or town, owning, controlling, operating or managing any gas plant within this state)) a person or entity constructing, owning or operating a gas pipeline for transporting gas. "Gas pipeline company" includes a person or entity owning or operating a master meter system. "Gas pipeline company" does not include excavation contractors or other contractors that contract with a pipeline company.

     (((12))) (14) "High occupancy structure or area" means a building or an outside area (such as a playground, recreation area, outdoor theater, or other place of public assembly) that is occupied by twenty or more persons on at least five days a week for ten weeks in any twelve-month period. (The days and weeks need not be consecutive.)

     (((13))) (15) "Indication" means a response indicated by a gas detection instrument that has not been verified as a reading.

     (((14))) (16) "LEL" means the lower explosive limit of the gas being transported.

     (((15))) (17) "Line pipe" or "pipe" means a tube, usually cylindrical, through which a hazardous liquid or gas is transported from one point to another.

     (18) "MAOP" means maximum allowable operating pressure.

     (((16))) (19) "Master meters system" ((is defined as set forth in 49 CFR § 191.3)) means a pipeline system for distributing gas within, but not limited to, a definable area, such as a mobile home park, housing project, or apartment complex, where the operator purchases metered gas from an outside source for resale through a gas distribution pipeline system. The gas distribution pipeline system supplies the ultimate consumer who either purchases the gas directly through a meter or by any other means, such as by rents.

     (((17) "Operator":

     (a) For purposes of chapter 480-93 WAC, the term "operator" means:

     (i) Every gas distribution company that has tariffs on file with the commission;

     (ii) Every city or town that owns, controls, operates, or manages any gas plant in this state; and

     (iii) Every other person or corporation transporting gas by pipeline, or having for one or more of its principal purposes the construction, maintenance, or operation of pipelines for transporting gas in this state; even though such person or corporation does not deliver, sell, or furnish any such gas to any person or corporation within this state. The terms "person" and "corporation" are defined in RCW 80.04.010. "Transporting gas by pipeline" means transmission or distribution of gas through a pipe.

     (b) A single entity may qualify as an operator under one or more of the provisions of this subsection.

     (c) The term "operator" includes operators of master meter systems, as defined in this section.

     (18))) (20) "Prompt action" means to dispatch qualified personnel without undue delay.

     (((19))) (21) "Psig" means pounds per square inch gauge.

     (((20) "Public service company" is defined in RCW 80.04.010.

     (21))) (22) "Reading" means a repeatable representation on a combustible gas indicator or equivalent instrument expressed in percent LEL or gas-air ratio.

     (((22))) (23) "Record(s)" means any electronic or paper document, map, data base, report or drawing created by or kept by ((an operator)) a gas pipeline company.

     (((23))) (24) "Sniff test" means a qualitative test utilizing both threshold and readily detectable methods for determining proper concentrations of odorant.

     (((24))) (25) "Transmission line" means a gas pipeline as defined in 49 CFR § 192.3 on the date specified in WAC 480-93-999.

     (((25))) (26) "Weak link" means a device or method used when pulling polyethylene pipe to ensure that damage will not occur to the pipeline by exceeding the maximum tensile stresses allowed.

     (((26))) (27) Other terms that correspond to those used in 49 CFR Parts 191, 192 and 199 (Minimum Federal Safety Standards for Gas Pipelines) must be construed as used therein on the date specified in WAC 480-93-999.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-005, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210(1), and 80.01.040(1). 05-23-174 (Docket No. PG-050933, General Order No. R-524), § 480-93-005, filed 11/23/05, effective 12/24/05. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-005, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.310. 01-20-061 (Docket No. A-010827, General Order No. R-491), § 480-93-005, filed 9/28/01, effective 10/29/01. Statutory Authority: RCW 80.01.040 and 80.28.210. 95-13-082 (Order R-427, Docket No. UG-950061), § 480-93-005, filed 6/20/95, effective 7/21/95. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-005, filed 8/5/92, effective 9/5/92; Order R-100, § 480-93-005, filed 5/18/77. Formerly WAC 480-93-001.]

     (2) ((This chapter does not apply to customer-owned facilities, where the customer is the end user, and the customer-owned facilities are on the customer's side of the distribution meter. Customer-owned transmission lines are subject to the rules in this chapter.

     (3))) This chapter, with the exception of WAC 480-93-240, does not apply to ((those operators of gas facilities)) gas pipeline systems exclusively under federal jurisdiction for compliance with pipeline safety regulations.

     (3) While the commission's gas pipeline safety statutes and rules impose obligations on each gas pipeline company, a gas pipeline company may contract with a person to do tasks that are subject to these rules, such as excavation, construction, and maintenance. If the gas pipeline company's contractor (or any of its subcontractors) engages in conduct that violates commission rules applicable to the gas pipeline company, the gas pipeline company is subject to penalties and all other applicable remedies, as if the gas pipeline company itself engaged in that conduct.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-007, filed 5/2/05, effective 6/2/05.]

     (2) The commission retains the authority to impose additional or different requirements on any ((operator)) gas pipeline company in appropriate circumstances, consistent with the requirements of law.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-008, filed 5/2/05, effective 6/2/05.]

     (2) Accordingly, for the purpose of this chapter, the commission defines a covered task that will be subject to the requirements of 49 CFR §§ 192.803 through 192.809 as an activity, identified by the ((operator)) gas pipeline company, that:

     (a) Is performed on a gas pipeline ((facility));

     (b) Is an operations, maintenance, or new construction task;

     (c) Is performed as a requirement of Part 192 CFR; and

     (d) Affects the operation or integrity of the gas pipeline.

     (3) In all other respects, the requirements of 49 CFR §§ 192.801 through 192.809 apply to this chapter.

     (4) The equipment and facilities used by a gas pipeline company for training and qualification of employees must be similar to the equipment and facilities on which the employee will perform the covered task.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-013, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-013, filed 5/2/05, effective 6/2/05.]

     (2) ((Operators)) Each gas pipeline company must use an odorant testing instrument when conducting sniff tests. Sniff tests must be performed at least once monthly. Master meter ((operators who)) systems that comply with 49 CFR § 192.625(f) are exempt from this requirement.

     (3) ((Operators)) Each gas pipeline company must take prompt action to investigate and remediate odorant concentrations that do not meet the minimum requirements of subsection (1) of this section.

     (4) ((Operators)) Each gas pipeline company must follow the odorant testing instrument manufacturer's recommendations for maintaining, testing for accuracy, calibrating and operating ((odorant testing)) such instruments. When the manufacturer does not provide a recommendation, ((operators)) each gas pipeline company must conduct accuracy checks and calibrate such instruments at least once annually, if the instrument is outside specified tolerances((, at least once annually)).

     (5) ((Operators)) Each gas pipeline company must keep all records of odorant usage, sniff tests performed, and odorant testing instrument calibration for five years.

     (6) Exception. This rule does not apply to gas pipelines ((that transport gas)) where the odorant would make the gas unfit for its intended purpose.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-015, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-015, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.310. 01-20-061 (Docket No. A-010827, General Order No. R-491), § 480-93-015, filed 9/28/01, effective 10/29/01. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-015, filed 8/5/92, effective 9/5/92.]

     (2) ((With the exception of)) Except in an emergency ((situations)), a gas pipeline company must submit to the commission for review, at least forty-five days prior to construction, any construction plans that do not conform with a gas pipeline company's existing and accepted construction procedures, designs, and specifications on file with the commission((, must be submitted to the commission for review at least forty-five days prior to the initiation of construction activity)).

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-017, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210(1), and 80.01.040(1). 05-23-174 (Docket No. PG-050933, General Order No. R-524), § 480-93-017, filed 11/23/05, effective 12/24/05. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-017, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-017, filed 8/5/92, effective 9/5/92.]

     (2) ((Operators)) Each gas pipeline company must give the commission access to records for review during an inspection and must provide the commission copies of ((requested)) records upon request.

     (3) ((Operators)) Each gas pipeline company must maintain a list of forms and data bases, including examples where applicable, that specify what records the ((operator)) company maintains. ((Operators)) Each gas pipeline company must make this list available to the commission upon request.

     (4) ((Operators)) Each gas pipeline company must record and maintain records of the actual value of any required reads, tests, surveys or inspections performed. The records must include the name of the person who performed the work and the date the work was performed. The records must also contain information sufficient to determine the location and facilities involved. Examples of the values to be recorded include, but are not limited to, pipe to soil potential reads, rectifier reads, pressure test levels, and combustible gas indicator reads. A gas pipeline company may not record a range of values ((may not be recorded)) unless the measuring device being used provides only a range of values.

     (5) ((Operators)) Each gas pipeline company must update its records within six months of ((completion of)) when it completes any construction activity and make ((them)) such records available to appropriate company operations personnel.

     (6) If ((an operator)) a gas pipeline company believes a record provided to the commission is confidential as that term is defined in WAC 480-07-160(2), the ((operator will)) gas pipeline company must follow the procedures in WAC 480-07-160 for designating and treating that record as confidential.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-018, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-018, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-018, filed 8/5/92, effective 9/5/92.]

     (a) Operating any gas pipeline ((facility)) at greater than five hundred psig ((that)) if the gas pipeline is within five hundred feet of any of the following places:

     (i) A building that is in existence or under construction prior to the date authorization for construction is filed with the commission, ((and that)) if the building is not owned and used by the petitioning ((operator)) gas pipeline company in its gas operations; or

     (ii) A high occupancy structure or area that is in existence or under construction prior to the date authorization for construction is filed with the commission; or

     (iii) A public highway, as defined in RCW 81.80.010(3).

     (b) Operating any gas pipeline ((facility)) at greater than two hundred fifty psig, up to and including five hundred psig, ((that)) if the gas pipeline is ((operated)) within one hundred feet of either of the following places:

     (i) A building that is in existence or under construction prior to the date authorization for construction is filed with the commission, ((and that)) if the building is not owned and used by the petitioning ((operator)) gas pipeline company in its gas operations; or

     (ii) A high occupancy structure or area that is in existence or under construction prior to the date authorization for construction is filed with the commission.

     (2) For proposed new construction of pipelines having the characteristics listed in subsection (1)(a) or (b) of this section, ((operators)) each gas pipeline company must ((provide documentation proving)) demonstrate to the commission that it is not practical for the gas pipeline company to select an alternate route that will avoid such locations and ((further provide documents that demonstrate)) that the ((operator)) gas pipeline company has considered the possibility of the future development of the area and has designed ((their)) its gas pipeline ((facilities)) accordingly.

     (3) During the review process, ((operators)) each gas pipeline company must provide maps and records to the commission showing the exact location of the gas pipeline and the shortest direct distance to the places described in subsection (1)(a) and (b) of this section. Upon request of the commission, the ((operator)) gas pipeline company must provide the maintenance, construction, and operational history of the pipeline system and an aerial photograph showing the exact location of the gas pipeline in reference to places listed in subsection (1)(a) and (b) of this section.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-020, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-020, filed 8/5/92, effective 9/5/92; Order R-28, § 480-93-020, filed 7/15/71; Order R-5, § 480-93-020, filed 6/6/69, effective 10/9/69.]

     (2) Each gas pipeline company must locate gas compressor stations that are designed to operate at pressures in excess of two hundred fifty psig, and that have an installed capacity of less than one thousand horsepower ((must be located)) at least two hundred fifty feet away from any existing buildings that are not under the gas pipeline company's control ((of the operator)).

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-040, filed 5/2/05, effective 6/2/05; Order R-28, § 480-93-040, filed 7/15/71; Order R-5, § 480-93-040, filed 6/6/69, effective 10/9/69.]

     (a) Oxyacetylene welders may qualify under 49 CFR § 192 Appendix C, but may only weld the following size pipe:

     (i) Nominal two-inch or smaller branch connections to nominal six-inch or smaller main or service pipe.

     (ii) Nominal two-inch or smaller below ground butt welds.

     (iii) Nominal four-inch or smaller above ground manifold and meter piping operating at 10 psig or less.

     (((iv))) (b) Appendix C welders must be requalified at least twice annually, but not to exceed seven and one-half months between qualification tests.

     (((b))) (c) When testing welders or qualifying procedures, ((operators)) each gas pipeline company must use the ((necessary)) testing equipment necessary to measure the amperage, voltage, and speed of travel. All essential variables, as defined by the applicable procedure, must be recorded and documented as performed during the welder and procedure testing.

     (((c))) (d) For the purposes of (((b))) (c) of this subsection, "essential variable" is defined as any variable in the welding procedure, which, according to the procedure being used, would require the requalification of the procedure if changed from or performed outside a specified range. "Speed of travel" is defined as the actual per pass welding time in minutes divided by the length of the weld in inches.

     (((d))) (e) Qualified written welding procedures must be located on-site where welding is being performed.

     (2) Personnel qualified to join plastic pipe must be requalified at least once annually, but not to exceed fifteen months between qualifications.

     (a) Qualified written plastic joining procedures must be located on-site where plastic joining is being performed.

     (b) Plastic joiners must be requalified under an applicable procedure, if during any twelve-month period that person has not made any joints under that procedure.

     (c) In order to ensure compliance with (b) of this subsection and Title 49 CFR Part 192.285(c), each ((operator)) gas pipeline company must either have a method of tracking production joints or requalify each person qualified to join plastic pipe at a frequency not to exceed twelve months. ((This)) The method used to track production joints must be outlined in the ((operator's)) gas pipeline company's procedures manual. ((Production joints need to be tracked only to the extent that shows compliance with this requirement. Operators may elect not to track production joints, in which case personnel qualified to join plastic pipe must be requalified at a frequency not to exceed twelve months.))

     (3) Welders and plastic joiners must carry appropriate identification and qualification cards or certificates showing the name of the welder or joiner, their qualifications, the date of qualification and the ((operator)) gas pipeline company whose procedures were followed for the qualification. Welder and plastic joiner qualification cards are subject to commission inspection at all times when qualified personnel are working on facilities subject to commission jurisdiction.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-080, filed 5/2/05, effective 6/2/05; Order R-28, § 480-93-080, filed 7/15/71; Order R-5, § 480-93-080, filed 6/6/69, effective 10/9/69.]

     (a) Each pressure regulating station.

     (b) Principal feeds into business districts.

     (c) Geographical size of the area to be isolated.

     (d) Number of potential customers affected.

     (e) ((Pipeline)) Line pipe size and operating pressures.

     (f) Class locations.

     (g) Potential threats including, but not limited to, earthquakes, floods, and landslides.

     (h) Emergency response time.

     (i) High occupancy structures or areas.

     (j) ((Pipeline)) Line pipe material: For example steel, polyethylene, or cast iron.

     (2) Each ((operator)) gas pipeline company must have a written service valve installation and maintenance program detailing the valve selection process, inspection, maintenance, and operating procedures. The written program must detail which new services will be required to have valves installed and maintained under this section. Service valve installation requirements do not apply to existing services (they are not retroactive). Existing service valves that historically have not been maintained but are deemed necessary for maintenance by the written valve maintenance program must be maintained in accordance with subsection (3) of this section (service valve maintenance requirements are retroactive). The written program shall explain how each of the following criteria and/or locations are considered in selecting which services will have valves installed and/or maintained under this ((section)) subsection:

     (a) Services to churches, schools, hospitals.

     (b) Service line length and size.

     (c) Service line pressure.

     (d) Services to buildings occupied by persons who are confined, are of impaired mobility, or would be difficult to evacuate.

     (e) Services to commercial or industrial buildings or structures.

     (f) Services to high occupancy structures or areas.

     (3) All service valves selected for inspection in the program required in subsection (2) of this section must be operated and maintained at least once annually, but not to exceed fifteen months between operation and maintenance.

     (4) Each ((operator)) gas pipeline company must select which valves to inspect based on the unique operating conditions of the ((operator's)) company's pipeline system(s).

     (5) Each ((operator)) gas pipeline company must install and maintain valves for the purpose of minimizing the hazards resulting from a gas pipeline emergency and to aid in the timely control of an uncontrolled release of gas. In determining the minimum number and spacing of valves, the ((operator's)) gas pipeline company's primary objective shall be the protection of life and property. The ((operator)) gas pipeline company must consider this objective in conjunction with the criteria listed in subsections (1) and (2) of this section. ((Operators)) Each gas pipeline company must also incorporate ((their)) its valve programs established in subsections (1) and (2) of this section into their emergency plan and other plans and procedures designed to protect life and property in the event of an emergency.

     (6) ((Operators)) Each gas pipeline company must fully implement the requirements of this section within one year of the adoption date of this rule.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-100, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-100, filed 5/2/05, effective 6/2/05; Order R-28, § 480-93-100, filed 7/15/71; Order R-5, § 480-93-100, filed 6/6/69, effective 10/9/69.]

     (2) Each ((operator)) gas pipeline company must complete remedial action within ninety days to correct any cathodic protection deficiencies known and indicated by any test, survey, or inspection. An additional thirty days may be allowed for remedial action if due to circumstances beyond the ((operator's)) gas pipeline company's control ((it is not possible to)) the company cannot complete remedial action within ninety days. Each ((operator)) gas pipeline company must be able to provide documentation to the commission indicating that remedial action was started in a timely manner and that all efforts were made to complete remedial action within ninety days. (Examples of circumstances allowing ((operators)) each gas pipeline company to exceed the ninety-day time frame include right of way permitting issues, availability of repair materials, or unusually long investigation or repair requirements.)

     (3) Cathodic protection equipment and instrumentation must be maintained, tested for accuracy, calibrated, and operated in accordance with the manufacturer's recommendations. When there are no manufacturer's recommendations, then instruments must be tested for accuracy at an appropriate schedule determined by the ((operator)) gas pipeline company.

     (4) Each ((operator's)) gas pipeline company's procedures manual must have written procedures explaining how cathodic protection related surveys, reads, and tests will be conducted. Examples of such procedures include, but are not limited to, how to determine IR drop (as defined in 49 CFR § 192 Appendix D), how to conduct electrical surveys, how to test casings for electrical isolation, how to test casings for shorted conditions, and how to measure and interpret 49 CFR § 192 Appendix D criteria.

     (5) ((Operators)) Each gas pipeline company must conduct inspections or tests for electrical isolation between metallic pipeline casings and metallic pipelines at least once annually, but not to exceed fifteen months between inspections or tests. The test or inspection must also determine whether the pipeline has adequate levels of cathodic protection at the casing to pipeline interface. These requirements do not apply to unprotected copper inserted in ferrous pipe.

     (a) For each casing installed prior to September 5, 1992, that does not have test leads, the ((operator)) gas pipeline company must be able to demonstrate that other test or inspection methods are acceptable and that test lead wires are not necessary to monitor for electrical isolation and adequate cathodic protection levels.

     (b) Whenever electrical isolation tests or inspections indicate that a possible shorted condition exists between a casing and a pipeline, the ((operator)) gas pipeline company must conduct a follow-up test within ninety days to determine whether an actual short exists. The ((operator's)) gas pipeline company's procedures manual must have a level or threshold that would indicate a potential shorted condition and must also detail the method of determining whether the casing is actually shorted to the pipeline.

     (c) The ((operator)) gas pipeline company must clear the shorted condition where practical.

     (d) Whenever a short exists between a ((pipeline)) line pipe and casing, the ((operator)) gas pipeline company must perform a leak survey within ninety days of discovery and at least twice annually thereafter, but not to exceed seven and one-half months between leak surveys until the shorted condition is eliminated.

     (6) ((Operators)) Each gas pipeline company must record the condition of all underground metallic facilities each time the facilities are exposed.

     (7) ((Operators)) Each gas pipeline company must have a written program to monitor for indications of internal corrosion. The program must also have remedial action requirements for areas where internal corrosion is detected.

     (8) On all cathodically protected pipelines, the ((operator)) gas pipeline company must take a cathodic protection test reading each time an employee or representative of the ((operator)) gas pipeline company exposes the facility and the protective coating is removed.

     (9) Each ((operator)) gas pipeline company must have a written atmospheric corrosion control monitoring program. The program must have time frames for completing remedial action.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-110, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.310. 01-20-061 (Docket No. A-010827, General Order No. R-491), § 480-93-110, filed 9/28/01, effective 10/29/01. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-110, filed 8/5/92, effective 9/5/92; Order R-28, § 480-93-110, filed 7/15/71; Order R-5, § 480-93-110, filed 6/6/69, effective 10/9/69.]

     (2) For casings installed after September 5, 1992, ((operators)) each gas pipeline company must attach separate test lead wires to each casing without vents, and to the steel gas pipeline to verify that no electric short exists between the two, and that an adequate level of cathodic protection is applied to the steel ((pipeline)) line pipe.

     (3) Whenever ((an operator)) a gas pipeline company installs a main or transmission line in a casing or conduit of any type material, the ((operator)) gas pipeline company must seal the casing ends to prevent or slow the migration of gas in the event of a leak.

     (4) Whenever ((an operator)) a gas pipeline company installs a service line in a casing or conduit, the ((operator)) gas pipeline company must seal the casing at the end nearest the building wall to prevent or slow the migration of gas towards the building in the event of a leak.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-115, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-115, filed 8/5/92, effective 9/5/92.]

     (a) Where practical, over pipelines operating above two hundred fifty psig;

     (b) Over mains and transmission lines crossing navigable waterways (custom signage may be required to ensure visibility);

     (c) Over mains and transmission lines at river, creek, drainage ditch, or irrigation canal crossings where hydraulic scouring, dredging, or other activity could pose a risk to the pipeline (custom signage may be required to ensure visibility);

     (d) Over gas pipelines at railroad crossings;

     (e) At above ground gas pipelines ((and pipeline facilities.)) except service risers ((and)), meter set assemblies, and ((operator)) gas pipeline company owned piping downstream of the meter set assembly ((are exempt from this requirement)). The minimum lettering size requirements located in 49 CFR § 192.707 (d)(1) do not apply to services;

     (f) Over mains located in Class 1 and 2 locations;

     (g) Over transmission lines in Class 1 and 2 locations, and where practical, over transmission lines in Class 3 and 4 locations; and

     (h) Over mains and transmission lines at interstate, U.S. and state route crossings where practical.

     (2) ((Where markers are required at)) If practical, the gas pipeline company must place markers on both sides of any crossing((s)) listed in subsection (1) of this section((, they must be placed on both sides where practical)).

     (3) Where markers are required on buried gas pipelines, ((operators must, if practical, place them)) they must be placed approximately five hundred yards apart and at points of horizontal deflection ((of the pipeline)) if practical.

     (4) Where gas pipelines are attached to bridges or otherwise span an area, ((operators)) each gas pipeline company must place pipeline markers at both ends of the suspended pipeline. ((Operators)) Each gas pipeline company must conduct surveys of pipeline markers required by this subsection at least annually, not to exceed fifteen months.

     (5) ((Operators)) Each gas pipeline company must replace markers that are reported damaged or missing within forty-five days.

     (6) Surveys of pipeline markers not associated with subsection (4) of this section must be conducted at least every five calendar years but not to exceed sixty-three months, to ensure that markers are visible and legible.

     (a) ((The operator)) Each gas pipeline company must keep on file the last two surveys, or all surveys for the past five years, whichever number of surveys is greater.

     (b) Survey records must include a description of the system and area surveyed.

     (7) ((Operators)) Each gas pipeline company must have records such as maps((,)) or drawings ((or other)) sufficient ((records indicating)) to indicate class locations and other areas where pipeline markers are required.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-124, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-124, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.310. 01-20-061 (Docket No. A-010827, General Order No. R-491), § 480-93-124, filed 9/28/01, effective 10/29/01. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-124, filed 8/5/92, effective 9/5/92.]

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-130, filed 5/2/05, effective 6/2/05; Order R-28, § 480-93-130, filed 7/15/71; Order R-5, § 480-93-130, filed 6/6/69, effective 10/9/69.]

     (2) ((Operators)) Each gas pipeline company must inspect and test service regulators and associated safety devices during the initial turn-on, and when a customer experiences a pressure problem. Testing must include determining the gas regulator's outlet set pressure at a specified flow rate. ((Operators)) Each gas pipeline company must use pressure gauges downstream of the regulator during testing. Safety devices such as fracture discs are not required to be tested.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-140, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-140, filed 8/5/92, effective 9/5/92; Order R-28, § 480-93-140, filed 7/15/71; Order R-5, § 480-93-140, filed 6/6/69, effective 10/9/69.]

     (a) A list of all affected gas pipeline facilities, including pipes, fittings, valves, and other affected equipment, with the manufacturer's specified maximum operating pressure limits, their specified minimum yield strength (SMYS) at the intended MAOP, and any other applicable specifications or limitations;

     (b) Original design and construction standards;

     (c) Original pressure test records;

     (d) Previous operating pressures identifying the dates and lengths of time at that pressure;

     (e) Records of all leaks, regardless of cause, and the dates and methods of repair;

     (f) Where the pipeline is being uprated to a MAOP that produces a hoop stress of twenty percent or more of the SMYS, records of the original welding standards and welders;

     (g) Maintenance records of all affected regulator stations and system relief valves for the past three years or three most recent inspections, whichever is longer;

     (h) Where applicable, relief valve capacities at the proposed MAOP compared to regulator flow capacities, with calculations;

     (i) Cathodic protection readings of the affected gas pipeline and facilities, including rectifier readings, for the past three years or three most recent inspections, whichever is longer; and

     (j) Any additional information that the commission may deem necessary to evaluate the pressure increase.

     (2) Uprates must be based on a previous or current pressure test that will substantiate the intended MAOP.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-155, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.310. 01-20-061 (Docket No. A-010827, General Order No. R-491), § 480-93-155, filed 9/28/01, effective 10/29/01. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-155, filed 8/5/92, effective 9/5/92.]

     (2) The report must describe the proposed route and the specifications for the pipeline and must include, but is not limited to, the following items:

     (a) Description and purpose of the proposed pipeline;

     (b) Route map showing the type of construction to be used throughout the length of the line, and delineation of class location as defined in 49 CFR Part 192.5, and incorporated boundaries along the route. Aerial photographs must be submitted upon request;

     (c) Location and specification of principal valves, regulators, and other auxiliary equipment to be installed as a part of the pipeline system to be constructed((. The operator must submit aerial photographs upon request));

     (d) MAOP for the gas pipeline being constructed;

     (e) Location and construction details of all river crossings or other unusual construction requirements encountered en route, e.g., places where pipe will be exposed or it is impractical to provide required cover, bridge crossings, lines to be laid parallel to railroads or state highways, including encroachments, and any other areas requiring special or unusual design and construction considerations;

     (f) Proposed corrosion control program to be followed including specifications for coating and wrapping, and the method to ensure the integrity of the coating using holiday detection equipment;

     (g) Welding specifications; and

     (h) Bending procedures to be followed if needed.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-160, filed 5/2/05, effective 6/2/05; Order R-28, § 480-93-160, filed 7/15/71; Order R-5, § 480-93-160, filed 6/6/69, effective 10/9/69.]

     (a) The pressure tests of any such gas pipeline built in Class 3 or Class 4 locations, as defined in 49 CFR § 192.5, or within one hundred yards of a building, must be at least eight hours in duration.

     (b) When the test medium is to be a gas or compressible fluid, each ((operator)) gas pipeline company must notify the appropriate public officials so that adequate public protection can be provided for during the test.

     (c) In an emergency situation where it is necessary to maintain continuity of service, the requirements of subsection (1) of this section and subsection (1)(a) of this section may be waived by notifying the commission by ((telephone)) calling the emergency notification line (see WAC 480-93-005(8)) prior to performing the test.

     (2) The minimum test pressure for any steel service line or main, regardless of the intended operating pressure, must be determined by multiplying the intended MAOP by a factor determined in accordance with the table located in 49 CFR § 192.619 (a)(2)(ii).

     (3) ((Operators)) Each gas pipeline company must perform pressure tests for all new or replacement gas pipeline installations.

     (4) All service lines that are broken, pulled, or damaged, resulting in the interruption of gas supply to the customer, must be pressure tested from the point of damage to the service termination valve (generally the meter set) prior to being placed back into service.

     (5) ((Operators)) Each gas pipeline company may only use pretested pipe when it is not feasible to conduct a pressure test.

     (6) ((Operators)) Each gas pipeline company must perform soap tests at the tie-in joints at not less than the current operating pressure of the gas pipeline.

     (7) ((Operators)) Each gas pipeline company must keep records of all pressure tests performed for the life of the pipeline and must document the following information:

     (a) ((Operator's)) Gas pipeline company's name;

     (b) Employee's name;

     (c) Test medium used;

     (d) Test pressure;

     (e) Test duration;

     (f) Line pipe size and length;

     (g) Dates and times; and

     (h) Test results.

     (8) Where feasible, ((operators)) each gas pipeline company must install and backfill plastic pipe prior to pressure testing to expose any potential damage that could have occurred during the installation and backfill process.

     (9) ((Where)) When a gas pipeline company performs multiple pressure tests ((are performed)) on a single installation, ((operators)) the gas pipeline company must maintain a record of each test. An example of a single installation with multiple tests would be any continuous on-going job or installation such as a new plat or long main installation where more than one pressure test was conducted during construction.

     (10) Pressure testing equipment must be maintained, tested for accuracy, or calibrated, in accordance with the manufacturer's recommendations. When there are no manufacturer's recommendations, then pressure testing equipment must be tested for accuracy at an appropriate schedule determined by the ((operator)) gas pipeline company. Test equipment must be tagged with the calibration or accuracy check expiration date. The requirements of this section also apply to equipment such as pressure charts, gauges, dead weights or other devices used to test, monitor or check system pressures or set-points.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-170, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-170, filed 5/2/05, effective 6/2/05; Order R-28, § 480-93-170, filed 7/15/71; Order R-5, § 480-93-170, filed 6/6/69, effective 10/9/69.]

     (2) Except ((those pipelines detailed)) for the pipe referenced in subsection (1) of this section, a gas pipeline company may move or lower metallic line pipe with an MAOP of sixty psig or less, which has a nominal diameter of two inches or less, if the gas pipeline company can certify that no undue stresses will be placed on the pipeline and that it can be moved or lowered in a safe manner. The gas pipeline company must consider factors such as the type of materials, proximity to fittings, joints, and welds, and any other factors that could place undue stress on the gas pipeline or create an unsafe condition.

     (3) Before moving or lowering a gas pipeline other than the line pipe described in subsection (((3))) (2) of this section, each ((operator)) gas pipeline company must prepare a study ((prior to moving or lowering any metallic pipeline)) to determine whether ((the proposed action)) moving or lowering will cause an unsafe condition. ((This study)) The gas pipeline company's engineering department must ((be reviewed and approved by the operator's engineering department and retained in the operator's files)) review, approve, and retain the study for the life of the pipeline. ((This requirement does not apply to cast iron pipelines, which may not be lowered, or to copper pipelines.)) The study must ((include, but is not limited to, the following criteria)) analyze the following factors:

     (a) The required deflection of the pipe;

     (b) The diameter, wall thickness, and grade of pipe;

     (c) The characteristics of the pipeline;

     (d) The terrain and class location;

     (e) The present condition of the pipeline;

     (f) The anticipated stresses of the pipeline including the safe allowable stress limits; and

     (g) The toughness of the steel.

     (((2) Pipelines with mechanical or threaded joints must not be moved or lowered.

     (3) Pipelines operating at sixty psig or less which have a nominal diameter of two inches or less may be moved or lowered without the required study, if the operator can certify that no undue stresses will be placed on the pipeline and that it can be moved or lowered in a safe manner. The operator must consider factors such as the type of materials, proximity to fittings, joints, and welds, and any other factors that could place undue stress on the pipeline or create an unsafe condition.))

     (4) The gas pipeline company must conduct a leak survey ((must be conducted)) within thirty days from the date the company moves or lowers any gas pipeline ((has been moved or lowered)) under the provisions of subsection (((3))) (2) of this section.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-175, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-175, filed 8/5/92, effective 9/5/92.]

     (2) The gas pipeline company must follow the manufacturer's recommendation for maximum cumulative ultraviolet light exposure limit for plastic pipe ((is two years, or the manufacturer's recommended limit)). ((The acceptable time limit must be detailed in the operator's)) If there is no such recommendation, the gas pipeline company must not expose plastic pipe to ultraviolet light for more than two years. Each gas pipeline company must include the applicable ultraviolet exposure time limit in its procedures manual.

     (3) Each gas pipeline company must install a weak link on each plastic pipe that is pulled through the ground by mechanical means ((must have a weak link installed that will)), to ensure the pipe will not be damaged by excessive tensile forces.

     (4) When ((installing)) a gas pipeline company installs plastic pipelines parallel to other underground utilities, ((operators)) it must ensure there is a minimum of twelve inches of separation from the other utilities. Where a minimum twelve inches of separation is not possible, ((operators)) a gas pipeline company must take adequate precautions, such as inserting the plastic pipeline in conduit, to minimize any potential hazards resulting from the close proximity to the other utilities.

     (5) When ((installing)) a gas pipeline company installs plastic pipelines perpendicular to other underground utilities, ((operators)) it must ensure there is a minimum of six inches of separation from the other utilities. Where a minimum six inches of separation is not possible, ((an operator)) a gas pipeline company must take adequate precautions, such as inserting the plastic pipeline in conduit, to minimize any potential hazards resulting from the close proximity to the other utilities.

     (6) Except for approved steel encased plastic pipe, and except where allowed by (b) of this subsection, ((the maximum time limit that)) a gas pipeline company may temporarily install plastic pipe ((may be temporarily installed)) above ground ((is)) for no longer than thirty days.

     (a) During such temporary installations, ((operators)) the gas pipeline company must monitor and protect above ground plastic pipe from potential damage.

     (b) ((Operators)) A gas pipeline company may install above ground plastic pipe for periods longer than thirty days if ((they have)) it has a written monitoring program and ((notify)) if it notifies the commission by telephone using the emergency notification line (see WAC 480-93-005(8)) prior to exceeding the thirty-day time limit.

     (7) Plastic pipe must be bedded in a suitable material as recommended by the pipe manufacturer. Unless otherwise permitted by the manufacturer, plastic pipe must be bedded in an essentially rock-free material.

     (8) Plastic pipe may not be squeezed more than one time in the same location.

     (9) Plastic pipe must not be squeezed within twelve inches or three pipe diameters, whichever is greater, from any joint or fitting.

[Statutory Authority: RCW 80.04.160, 80.28.210(1), and 80.01.040(1). 05-23-174 (Docket No. PG-050933, General Order No. R-524), § 480-93-178, filed 11/23/05, effective 12/24/05. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-178, filed 5/2/05, effective 6/2/05.]

     (2) The manual must be filed with the commission forty-five days prior to the operation of any gas pipeline. ((Operators)) Each gas pipeline company must file revisions to the manual with the commission annually. The commission may, after notice and opportunity for hearing, require that a manual be revised or amended. Applicable portions of the manual related to a procedure being performed on the pipeline must be retained on-site where the activity is being performed.

     (3) The manual must be written in detail sufficient for a person with adequate training to perform the tasks described. For example, a manual should contain specific, detailed, step-by-step instructions on how to maintain a regulator or rectifier, conduct a leak survey or conduct a pressure test.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-180, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-180, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.310. 01-20-061 (Docket No. A-010827, General Order No. R-491), § 480-93-180, filed 9/28/01, effective 10/29/01. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-180, filed 8/5/92, effective 9/5/92; Order R-28, § 480-93-180, filed 7/15/71; Order R-5, § 480-93-180, filed 6/6/69, effective 10/9/69.]

     (2) In the event of an explosion, fire, death, or injury, the ((operator)) gas pipeline company must not remove any suspected gas facility until the commission or the lead investigative authority has designated the release of the gas facility. Once the situation is made safe, the ((operator)) gas pipeline company must keep the facility intact until directed by the lead investigative authority.

     (3) When leak indications are found to originate from a foreign source or facility such as gasoline vapors, sewer, marsh gas, or from customer-owned piping, the ((operator)) gas pipeline company must take appropriate action to protect life and property. Leaks that represent an on-going, potentially hazardous situation must be reported promptly to the owner or ((operator)) gas pipeline company of the source facility and, where appropriate, to the police department, fire department, or other appropriate governmental agency. If the property owner or an adult person occupying the premises is not available, the ((operator)) gas pipeline company must, within twenty-four hours of the leak investigation, send by first-class mail, addressed to the person occupying the premises, a letter explaining the results of the investigation. The ((operator)) gas pipeline company must keep a record of each letter sent for five years.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-185, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-185, filed 8/5/92, effective 9/5/92; Order R-102, § 480-93-185, filed 5/18/77.]

     (2) Each ((operator)) gas pipeline company must establish a procedure for evaluating the concentration and extent of gas leakage. When evaluating any leak, the ((operator)) gas pipeline company must determine and document the perimeter of the leak area. If the perimeter of the leak extends to a building wall, the ((operator)) gas pipeline company must extend the investigation inside the building. Where the reading is in an unvented, enclosed space, the ((operator)) gas pipeline company must consider the rate of dissipation when the space is ventilated and the rate of accumulation when the space is resealed.

     (3) The ((operator)) gas pipeline company must check the perimeter of the leak area with a combustible gas indicator. The ((operator)) gas pipeline company must perform a follow-up inspection on all leak repairs with residual gas remaining in the ground as soon as practical, but not later than thirty days following the repair.

     (4) Grade 1 and 2 leaks can only be downgraded once to a Grade 3 leak without a physical repair. After a leak has been downgraded once, the maximum repair time for that leak is twenty-one months.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-186, filed 5/2/05, effective 6/2/05; Order R-103, § 480-93-186, filed 5/18/77.]

     (a) Prompt action in response to a Grade 1 leak may require one or more of the following:

     (i) Implementation of the ((operator's)) gas pipeline company's emergency plan pursuant 49 CFR § 192.615;

     (ii) Evacuating the premises;

     (iii) Blocking off an area;

     (iv) Rerouting traffic;

     (v) Eliminating sources of ignition;

     (vi) Venting the area;

     (vii) Stopping the flow of gas by closing valves or other means; or

     (viii) Notifying police and fire departments.

     (b) Examples. Grade 1 leaks requiring prompt action include, but are not limited to:

     (i) Any leak, which in the judgment of ((operating)) gas pipeline company personnel at the scene, is regarded as an immediate hazard;

     (ii) Escaping gas that has ignited unintentionally;

     (iii) Any indication of gas that has migrated into or under a building or tunnel;

     (iv) Any reading at the outside wall of a building or where the gas could potentially migrate to the outside wall of a building;

     (v) Any reading of eighty percent LEL or greater in an enclosed space;

     (vi) Any reading of eighty percent LEL, or greater in small substructures not associated with gas facilities where the gas could potentially migrate to the outside wall of a building; or

     (vii) Any leak that can be seen, heard, or felt and which is in a location that may endanger the general public or property.

     (2) A "Grade 2 leak" is a leak that is recognized as being not hazardous at the time of detection but justifies scheduled repair based on the potential for creating a future hazard.

     (a) ((Operators)) Each gas pipeline company must repair or clear Grade 2 leaks within fifteen months from the date the leak is reported. If a Grade 2 leak occurs in a segment of pipeline that is under consideration for replacement, an additional six months may be added to the fifteen months maximum time for repair provided above. In determining the repair priority, ((operators)) each gas pipeline company should consider the following criteria:

     (i) Amount and migration of gas;

     (ii) Proximity of gas to buildings and subsurface structures;

     (iii) Extent of pavement; and

     (iv) Soil type and conditions, such as frost cap, moisture and natural venting.

     (b) ((Operators)) Each gas pipeline company must reevaluate Grade 2 leaks at least once every six months until cleared. The frequency of reevaluation should be determined by the location and magnitude of the leakage condition.

     (c) Grade 2 leaks vary greatly in degree of potential hazard. Some Grade 2 leaks, when evaluated by the criteria, will require prompt scheduled repair within the next five working days. Other Grade 2 leaks may require repair within thirty days. The ((operator)) gas pipeline company must bring these situations to the attention of the individual responsible for scheduling leakage repair at the end of the working day. Many Grade 2 leaks, because of their location and magnitude, can be scheduled for repair on a normal routine basis with periodic reevaluation as necessary.

     (d) When evaluating Grade 2 leaks, ((operators)) each gas pipeline company should consider leaks requiring action ahead of ground freezing or other adverse changes in venting conditions, and any leak that could potentially migrate to the outside wall of a building, under frozen or other adverse soil conditions.

     (e) Examples. Grade 2 leaks requiring action within six months include, but are not limited to:

     (i) Any reading of forty percent LEL or greater under a sidewalk in a wall-to-wall paved area that does not qualify as a Grade 1 leak and where gas could potentially migrate to the outside wall of a building;

     (ii) Any reading of one hundred percent LEL or greater under a street in a wall-to-wall paved area that does not qualify as a Grade 1 leak and where gas could potentially migrate to the outside wall of a building;

     (iii) Any reading less than eighty percent LEL in small substructures not associated with gas facilities and where gas could potentially migrate creating a probable future hazard;

     (iv) Any reading between twenty percent LEL and eighty percent LEL in an enclosed space;

     (v) Any reading on a pipeline operating at thirty percent of the specified minimum yield strength or greater in Class 3 or 4 locations that does not qualify as a Grade 1 leak; or

     (vi) Any leak that in the judgment of ((operating)) gas pipeline company personnel at the scene is of sufficient magnitude to justify scheduled repair.

     (3) A "Grade 3 leak" is a leak that is not hazardous at the time of detection and can reasonably be expected to remain not hazardous.

     (a) ((Operators)) Each gas pipeline company should reevaluate Grade 3 leaks during the next scheduled survey, or within fifteen months of the reporting date, whichever occurs first, until the leak is regraded or no longer results in a reading.

     (b) Examples. Grade 3 leaks requiring reevaluation at periodic intervals include, but are not limited to:

     (i) Any reading of less than eighty percent LEL in small gas associated substructures, such as small meter boxes or gas valve boxes; or

     (ii) Any reading under a street in areas without wall-to-wall paving where it is unlikely the gas could migrate to the outside wall of a building.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-18601, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-18601, filed 8/5/92, effective 9/5/92; Order R-103, Table 1 (codified as WAC 480-93-18601), filed 5/18/77.]

     (1) Date and time the leak was detected, investigated, reported, and repaired, and the name of the ((employee(s))) person conducting the investigation;

     (2) Location of the leak (sufficiently described to allow ready location by other qualified personnel);

     (3) Leak grade;

     (4) Pipeline classification (e.g., distribution, transmission, service);

     (5) If reported by an outside party, the name and address of the reporting party;

     (6) Component that leaked (e.g., pipe, tee, flange, valve);

     (7) Size and material that leaked (e.g., steel, plastic, cast iron);

     (8) Pipe condition;

     (9) Type of repair;

     (10) Leak cause;

     (11) Date pipe installed (if known);

     (12) Magnitude and location of CGI readings left; and

     (13) Unique identification numbers (such as serial numbers) of leak detection equipment.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-187, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-187, filed 8/5/92, effective 9/5/92; Order R-104, § 480-93-187, filed 5/18/77.]

     (a) Over all mains, services, and transmission lines including the testing of the atmosphere near other utility (gas, electric, telephone, sewer, or water) boxes or manholes, and other underground structures;

     (b) Through cracks in paving and sidewalks;

     (c) On all above ground piping (may be checked with either a gas detection instrument or with a soap solution);

     (d) Where a gas service line exists, ((a)) the gas pipeline company must conduct a leak survey ((must be conducted)) at the building wall at the point of entrance, using a bar hole if necessary; and

     (e) Within all buildings where gas leakage has been detected at the outside wall, at locations where escaping gas could potentially migrate into and accumulate inside the building.

     (2) Each gas pipeline company must maintain, test for accuracy, calibrate and operate gas detection instruments ((must be maintained, tested for accuracy, calibrated, and operated)) in accordance with the manufacturer's recommendations. If there are no written manufacturer's recommendations or schedules, then the gas pipeline company must test such instruments ((must be tested)) for accuracy at least monthly, but not to exceed forty-five days between testing, and ((include testing)) at least twelve times per year. The gas pipeline company must recalibrate or remove from service any such instrument that ((fails its)) does not meet applicable tolerances ((must be calibrated or removed from service)). Records of accuracy checks, calibration and other maintenance performed must be maintained for five years.

     (3) Each gas pipeline company must conduct gas leak surveys ((must be conducted)) according to the following minimum frequencies:

     (a) Business districts - at least once annually, but not to exceed fifteen months between surveys. All mains in the right of way adjoining a business district must be included in the survey;

     (b) High occupancy structures or areas - at least once annually, but not to exceed fifteen months between surveys;

     (c) Gas pipelines operating at or above two hundred fifty psig - at least once annually, but not to exceed fifteen months between surveys;

     (d) Where the gas system has cast iron, wrought iron, copper, or noncathodically protected steel - at least twice annually, but not to exceed seven and one-half months between surveys; and

     (e) Unodorized gas pipelines - at least monthly.

     (4) Each gas pipeline company must conduct special leak surveys ((must be conducted)) under the following circumstances:

     (a) Prior to paving or resurfacing, following street alterations or repairs where gas ((facilities)) pipelines are under the area to be paved, and where damage could have occurred to gas ((facilities)) pipelines;

     (b) In areas where substructure construction occurs adjacent to underground gas ((facilities)) pipelines, and damage could have occurred to the gas ((facilities, operators)) pipeline, each gas pipeline company must perform a gas leak survey following the completion of construction, but prior to paving;

     (c) Unstable soil areas where active gas ((lines)) pipelines could be affected;

     (d) In areas and at times of unusual activity, such as earthquake, floods, and explosions; and

     (e) After third-party excavation damage to services, ((operators)) each gas pipeline company must perform a gas leak survey from the point of damage to the service tie-in.

     (5) Each gas pipeline company must keep leak survey records ((must be kept)) for a minimum of five years. At a minimum, survey records must contain the following information:

     (a) Description of the system and area surveyed (including maps and leak survey logs);

     (b) Survey results;

     (c) Survey method;

     (d) Name of the ((employee)) person who performed the survey;

     (e) Survey dates; and

     (f) Instrument tracking or identification number.

     (6) Each ((operator)) gas pipeline company must perform self audits of the effectiveness of its leak detection and recordkeeping programs. ((Operators)) Each gas pipeline company must maintain records of the self audits for five years. Self audits must be performed as frequently as necessary, but not to exceed three years between audits. At a minimum, self audits should ensure that:

     (a) Leak survey schedules meet the minimum federal and state safety requirements for gas pipelines;

     (b) Consistent evaluations of leaks are being made throughout the system;

     (c) Repairs are made within the time frame allowed;

     (d) Repairs are effective; and

     (e) Records are accurate and complete.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-188, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-188, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-188, filed 8/5/92, effective 9/5/92; Order R-105, § 480-93-188, filed 5/18/77.]

     (a) ((Results in)) A fatality or personal injury requiring hospitalization;

     (b) ((Results in)) Property damage ((-to the property of the operator and others of a combined total exceeding)) valued at more than fifty thousand dollars;

     (c) ((Results in)) The evacuation of a building, or a high occupancy structure or area;

     (d) ((Results in)) The unintentional ignition of gas;

     (e) ((Results in)) The unscheduled interruption of service furnished by any ((operator)) gas pipeline company to twenty-five or more distribution customers;

     (f) ((Results in)) A pipeline or system pressure exceeding the MAOP plus ten percent or the maximum pressure allowed by proximity considerations outlined in WAC 480-93-020; or

     (g) ((Results in the news media reporting the occurrence; or

     (h) Is)) A significant occurrence, in the judgment of the ((operator)) gas pipeline company, even though it does not meet the criteria of (a) through (g) of this subsection.

     (2) ((Operators)) Each gas pipeline company must give notice to the commission by telephone using the emergency notification line (see WAC 480-93-005(8)) within twenty-four hours of ((occurrence of every)) each incident or hazardous condition arising out of its operations that results in:

     (a) The uncontrolled release of gas for more than two hours;

     (b) The taking of a high pressure supply or transmission pipeline or a major distribution supply gas pipeline out of service;

     (c) A gas pipeline ((or system)) operating at low pressure dropping below the safe operating conditions of attached appliances and gas equipment; or

     (d) A gas pipeline ((or system)) pressure exceeding the MAOP.

     (3) Routine or planned maintenance and operational activities of the ((operator)) gas pipeline company that result in operator-controlled plant and equipment shut downs, reduction in system pressures, flaring or venting of gas, and normal leak repairs are not reportable items under this section.

     (4) ((Operators)) Each gas pipeline company must provide to the commission a written report within thirty days of the initial telephonic report required under subsections (1) and (2) of this section. At a minimum, the written reports must include the following:

     (a) Name(s) and address(es) of any person or persons injured or killed, or whose property was damaged;

     (b) The extent of such injuries and damage;

     (c) A description of the incident or hazardous condition including the date, time, and place, and reason why the incident occurred. If more than one reportable condition arises from a single incident, each must be included in the report;

     (d) A description of the gas ((facilities)) pipeline involved in the incident or hazardous condition, the system operating pressure at that time, and the MAOP of the facilities involved;

     (e) The date and time the ((operator)) gas pipeline company was first notified of the incident;

     (f) The date and time the ((operators')) gas pipeline company's first responders arrived on-site;

     (g) The date and time the gas ((facility)) pipeline was made safe;

     (h) The date, time, and type of any temporary or permanent repair that was made;

     (i) The cost of the incident to the ((operator)) gas pipeline company;

     (j) Line type;

     (k) City and county of incident; and

     (l) Any other information deemed necessary by the commission.

     (5) ((Operators)) Each gas pipeline company must submit a supplemental report if required information becomes available after the thirty-day report is submitted.

     (6) ((Operators)) Each gas pipeline company must provide to the commission a copy of each failure analysis report completed or received by the ((operator)) gas pipeline company, concerning any incident or hazardous condition due to construction defects or material failure within five days of completion or receipt of such report.

     (7) ((Operators)) Each gas pipeline company must file with the commission the following annual reports no later than March 15 for the preceding calendar year:

     (a) A copy of every Pipeline and Hazardous Materials Safety Administration (PHMSA) F-7100.1-1 and F-7100.2-1 annual report required by U.S. Department of Transportation, Office of Pipeline Safety.

     (b) A report titled, "Damage Prevention Statistics." The Damage Prevention Statistics report must include in detail the following information:

     (i) Number of gas-related one-call locate requests completed in the field;

     (ii) Number of third-party damages incurred; and

     (iii) Cause of damage, where cause of damage is classified as one of the following:

     (A) Inaccurate locate;

     (B) Failure to use reasonable care;

     (C) Excavated prior to a locate being conducted; or

     (D) Excavator failed to call for a locate.

     (c) A report detailing all construction defects and material failures resulting in leakage. ((Operators)) Each gas pipeline company must categorize the different types of construction defects and material failures anticipated for their system. The report must include the following:

     (i) Types and numbers of construction defects; and

     (ii) Types and numbers of material failures.

     (8) ((Operators)) Each gas pipeline company must file with the commission, and with appropriate officials of all municipalities where ((operators)) gas pipeline companies have facilities, the names, addresses, and telephone numbers of the responsible officials of the ((operator)) gas pipeline company who may be contacted in the event of an emergency. In the event of any changes in ((operator)) such personnel, the ((operator)) gas pipeline company must immediately notify ((immediately)) the commission and municipalities.

     (9) ((Operators)) Each gas pipeline company must send to the commission, by e-mail, daily reports of construction and repair activities. Reports may be faxed only if the ((operator)) gas pipeline company does not have e-mail capability. Reports must be received no later than 10:00 a.m. each day of the scheduled work, and must include both ((operator)) gas pipeline company and contractor construction and repair activities. Report information must be broken down by individual crews and the scheduled work must be listed by address, as much as practical. To the extent possible the reports will only contain construction and repair activity scheduled for that day, but they may include a reasonable allowance for scheduling conflicts or disruptions.

     (10) When ((an operator)) a gas pipeline company is required to file a copy of a DOT Drug and Alcohol Testing Management Information System (MIS) Data Collection Form with the U.S. Department of Transportation, Office of Pipeline Safety, the ((operator)) gas pipeline company must simultaneously submit a copy of the form to the commission.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-200, filed 8/23/07, effective 9/23/07. Statutory Authority: RCW 80.04.160, 80.28.210(1), and 80.01.040(1). 05-23-174 (Docket No. PG-050933, General Order No. R-524), § 480-93-200, filed 11/23/05, effective 12/24/05. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-200, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-200, filed 8/5/92, effective 9/5/92; Order R-28, § 480-93-200, filed 7/15/71; Order R-5, § 480-93-200, filed 6/6/69, effective 10/9/69.]

     (5) Any corporation other than a public service company that is subject to RCW 80.28.210 and that violates any provision of chapter 480-93 WAC, has failed to construct and/or maintain its facilities in a safe and efficient manner in violation of RCW 80.28.210, and is subject to a civil penalty under RCW 80.04.387.)) Any gas pipeline company that violates any pipeline safety provision of any commission order or any rule in this chapter including those rules adopted by reference, or chapter 81.88 RCW is subject to a civil penalty not to exceed one hundred thousand dollars for each violation for each day that the violation persists. The maximum civil penalty under this subsection for a related series of violations is one million dollars.

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-223, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040 and 80.28.210. 95-19-057 (Order R-433, Docket No. UG-950625), § 480-93-223, filed 9/15/95, effective 10/16/95.]

[Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-230, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040. 92-16-100 (Order R-375, Docket No. UG-911261), § 480-93-230, filed 8/5/92, effective 9/5/92; Order R-28, § 480-93-230, filed 7/15/71; Order R-5, § 480-93-230, filed 6/6/69, effective 10/9/69.]

     (2) Each company will pay an annual pipeline safety fee as established in the methodology set forth in subsection (3) of this section (((2) below)).

     (((2))) (3) The fee will be set by general order of the commission entered before ((July)) September 1 of each year and will be collected in four equal installments payable on the first day of each ((calendar)) quarter as listed below:

     1st quarter fee installment due September 1;

     2nd quarter fee installment due December 1;

     3rd quarter fee installment due March 1;

     4th quarter fee installment due June 1.

     (a) The total of pipeline safety fees will be calculated to recover no more than the costs of the legislatively authorized workload represented by current appropriations for the commission's pipeline safety program, less the amount received in total base grants through the Federal Department of Transportation and less any amount received from penalties collected under RCW 19.122.050. Federal grants, other than the federal base grant, received by the commission for additional activities not included or anticipated in the legislatively directed workload will not be credited against company pipeline safety fees, nor will the work supported by ((such)) grants be considered a cost for purposes of calculating such fees. To the extent that the actual base grant proceeds are different than the amount credited, the difference will be applied in the following year.

     (b) Total pipeline safety fees as determined in (a) of this subsection will be calculated in two parts:

     (i) The commission's annual overhead charge to the pipeline safety program will be allocated among companies according to each gas pipeline company's share of the total of all pipeline miles within Washington as reported by ((the)) companies in their annual reports to the commission.

     (ii) After deducting the commission's annual overhead charge, the remainder of the total pipeline safety fee commission's annual pipeline safety program allotment will be allocated among companies in proportion to each company's share of the program staff hours that are directly attributable to particular companies. The commission will determine each company's share by dividing the total hours directly attributable to the company during the two preceding calendar years (as reflected in the program's timekeeping system) by the total of directly attributable hours for all companies over the same period.

     (iii) For fee setting purposes, any program hours related to a ((staff)) commission investigation of an incident attributed to third-party damage ((resulting)) that results in penalties collected under RCW 19.122.055 will not be directly attributed to the ((operator)) owner of the damaged gas pipeline ((for fee-setting purposes)).

     (c) The commission general order setting fees pursuant to this rule will detail the specific calculation of each company's pipeline safety fee including the allocations set forth in (b) of this subsection.

     (((3))) (4) By ((June)) August 1 of each year the commission staff will mail an invoice to each company ((an invoice)).

     (((4))) (5) All funds received by the commission for the pipeline safety program will be deposited to the pipeline safety account. For ((those companies)) each gas pipeline company subject to RCW 80.24.010, ((the)) their portion of the company's total regulatory fee applicable to pipeline safety will be transferred from the public service revolving fund to the pipeline safety account.

     (((5))) (6) Any company wishing to contest the amount of the fee imposed under this section must pay the fee when due and, within 6 months ((of)) after the due date of the fee, file a petition in writing with the commission requesting a refund. The petition must state the name of the petitioner; the date and the amount paid, including a copy of any receipt, if available; the amount of the fee that is contested; ((and any)) all reasons why the commission may not impose the fee in that amount; and a calculation and explanation of the fee amount the petitioner contends is appropriate, if any. The commission may grant the petition administratively or may set the petition for adjudication or for brief adjudication.

[Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, 80.24.060, and 81.24.090. 05-17-017 (Docket No. P-041344, General Order No. R-523), § 480-93-240, filed 8/4/05, effective 7/1/06. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160 and 2001 c 238 § 2. 02-03-016 (Docket No. UG-010522, General Order No. R-497), § 480-93-240, filed 1/4/02,effective 2/4/02.]

     (1) Subscribe to the appropriate one-number locator service;

     (2) Provide, upon receipt of locate notice, reasonably accurate information as to its locatable underground facilities by surface-marking the location of the facilities;

     (3) Respond with locate markings within two business days after receipt of the notice or within a time mutually agreed upon between the operator and the excavator requesting the utility locate information.

[Statutory Authority: RCW 80.01.040, 81.01.010, and 81.88.060. 07-18-010 (Docket PG-061027, General Order R-544), § 480-93-250, filed 8/23/07, effective 9/23/07.]

     (1) Parts 191, 192, 193, and 199 of Title 49 Code of Federal Regulations, ((cited as 49 CFR, Parts 191, 192, 193, and 199)) including all appendices and amendments thereto as published by the United States Government Printing Office.

     (a) The commission adopts the version of the above regulations that were in effect on October 1, ((2005)) 2007, except the following sections are not adopted by reference: 191.1, 192.1(a), 193.2001(a), 199.1. ((However)) In addition, please note that in WAC 480-93-013, the commission includes "new construction" in the definition of "covered task," as defined in 49 CFR § 192.801(b)(2).

     (b) This publication is referenced in WAC 480-93-005, 480-93-080, 480-93-100, 480-93-110, 480-93-124, 480-93-155, 480-93-170, 480-93-180, and 480-93-18601.

     (c) The Code of Federal Regulations is published by the federal government. Copies of Title 49 Code of Federal Regulations are available from most Government Printing Offices, including the Seattle office of the Government Printing Office, as well as from various third-party vendors and various libraries, including the branch of the state library located at the commission. It is also available for inspection at the commission.

     (2) Section IX of the ASME Boiler and Pressure Vessel Code.

     (a) The commission adopts the 2001 edition of Section IX of the ASME Boiler and Pressure Vessel Code.

     (b) This publication is referenced in WAC 480-93-080.

     (c) Copies of Section IX of the ASME Boiler and Pressure Vessel Code (2001 edition) are available from The American Society of Mechanical Engineers, Park Avenue, New York, New York, and various libraries, including the branch of the state library located at the commission. It is also available for inspection at the commission.

     (3) The American Petroleum Institute (API) standard 1104 (19th edition).

     (a) The commission adopts the 19th edition of this standard.

     (b) This standard is referenced in WAC 480-93-080.

     (c) Copies of API standard 1104 (19th edition) are available from the Office of API Publishing Services in Washington DC, and various libraries, including the branch of the state library located at the commission. It is also available for inspection at the commission.

[Statutory Authority: RCW 80.01.040, 80.04.160, 80.28.210, 81.04.160, 81.88.020, and 34.05.353. 06-14-052 (Docket A-060464, General Order No. R-535), § 480-93-999, filed 6/28/06, effective 7/29/06. Statutory Authority: RCW 80.04.160, 80.28.210, and 80.01.040. 05-10-055 (Docket No. UG-011073, General Order No. R-520), § 480-93-999, filed 5/2/05, effective 6/2/05. Statutory Authority: RCW 80.01.040, 80.04.160, 81.04.160, and 34.05.310. 01-20-061 (Docket No. A-010827, General Order No. R-491), § 480-93-999, filed 9/28/01, effective 10/29/01.]

© Washington State Code Reviser's Office