(a) Each transmission line valve must be inspected and partially operated at intervals not exceeding 15-months, but at least once each calendar year.
(b) Each operator must take prompt remedial action to correct any valve that might be required during any emergency that is found inoperable, unless the operator designates an alternative valve.
(c) For each remote-control valve (RCV) installed in accordance with sections 255.179 or 255.634 of this Part, an operator must conduct a point- to-point verification between SCADA system displays and the installed valves, sensors, and communications equipment, in accordance with subdivisions 255.631(c) and (e) of this Part.
(d) For each alternative equivalent technology installed on an onshore pipeline pursuant to subdivisions 255.179(e) or (f) or section 255.634 of this Part, that is manually or locally operated (i.e., not a rupture-mitigation valve (RMV), as that term is defined in section 255.3 of this Part):
(1) Operators must achieve a valve closure time of 30 minutes or less, pursuant to subdivision 255.636(b) of this Part, through an initial drill and through periodic validation as required in paragraph (d)(2) of this section. An operator must review and document the results of each phase of the drill response to validate the total response time, including confirming the rupture, and valve shut-off time as being less than or equal to 30 minutes after rupture identification.
(2) Within each pipeline system and within each operating or maintenance field work unit, operators must randomly select a valve serving as an alternative equivalent technology in lieu of an RMV for an annual 30-minute-total response time validation drill that simulates worst-case conditions for that location to ensure compliance with section 255.636 of this Part. Operators are not required to close the valve fully during the drill; a minimum 25 percent valve closure is sufficient to demonstrate compliance with drill requirements unless the operator has operational information that requires an additional closure percentage for maintaining reliability. The response drill must occur at least once each calendar year, with intervals not to exceed 15 months. Operators must include in their written procedures the method they use to randomly select which alternative equivalent technology is tested in accordance with this paragraph.
(3) If the 30-minute-maximum response time cannot be achieved during the drill, the operator must revise response efforts to achieve compliance with section 255.636 of this Part as soon as practicable but no later than 12 months after the drill. Alternative valve shut-off measures must be in place in accordance with subdivision (e) of this section within 7 days of a failed drill.
(4) Based on the results of response-time drills, the operator must include lessons learned in:
(i) training and qualifications programs;
(ii) design, construction, testing, maintenance, operating, and emergency procedures manuals; and
(iii) any other areas identified by the operator as needing improvement.
(5) The requirements of this subdivision (d) do not apply to manual valves that, pursuant to subdivision 255.636(g) of this Part, have been exempted from the requirements of subdivision 255.636(b) of this Part.
(e) Each operator must develop and implement remedial measures to correct any valve installed on an onshore pipeline pursuant to subdivisions 255.179(e) or (f) or section 255.634 of this Part that is indicated to be inoperable or unable to maintain effective shut-off as follows:
(1) repair or replace the valve as soon as practicable but no later than 12 months after finding that the valve is inoperable or unable to maintain effective shut-off. An operator must request an extension from the Department and PHMSA in accordance with section 255.18 of this Part if repair or replacement of a valve within 12 months would be economically, technically, or operationally infeasible; and
(2) designate an alternative valve acting as an RMV within seven (7) calendar days of the finding while repairs are being made and document an interim response plan to maintain safety. Such valves are not required to comply with the valve spacing requirements of this Part.
(f) An operator using an ASV as an RMV, in accordance with sections 255.3, 255.179, 255.634, and 255.636 of this Part, must document and confirm the ASV shut-in pressures, in accordance with subdivision 255.636(f) of this Part, at intervals not exceeding 15 months, but at least once each calendar year. ASV shut-in set pressures must be proven and reset individually at each ASV, as required, on a calendar year basis not to exceed 15 months.
(g) The location of all valves in transmission lines shall be designated on appropriate records, drawings or maps in relation to aboveground structures, so that the valves and associated access covers can be readily located when the ground is covered with snow and ice. Since there may be changes or alterations in aboveground structures over a period of time, the accuracy of the reference points established shall be verified at the time of the periodic inspection.
(h) At the time of the periodic inspection, valves shall be checked for external leakage.