D.C. Mun. Regs. tit. 15, r. 15-3705
The Natural Gas Utility shall establish a Gas Main risk ranking index to determine its Gas Main Segments (including associated Service Lines) most in need of improvement or replacement. Factors associated with the main ranking index for making improvement and replacement decisions include, poor leak history, poor cathodic protection or poor gas main conditions determined from visual observations, poor pressure in the area, interruption of service due to water infiltration, and segment affected by city or state public improvement projects. At least once each calendar year, the Natural Gas Utility shall rank and identify areas of Pipeline Networks of its natural gas operating system requiring improvements to eliminate segments most susceptible to leakage, excavation damage, failure, supply interruptions or failure to meet its minimum design pressure and volume deliverability requirements. The Natural Gas Utility shall retain in its leak database the leak data/leak history in the main segments and service lines it has replaced. The Natural Gas Utility shall establish a performance ranking by area, on a scale of one to ten with one being the poorest performing segment. The Natural Gas Utility shall file the results with the Commission and a copy with the OPC on a biennial basis.
Each calendar year, the Natural Gas Utility shall perform the necessary analysis for the issues identified in Section 3705.1 and provide plans for eliminating the ten worst performing segments due to low pressure or interruption problems. The Natural Gas Utility shall file the results with the Commission and a copy to OPC on an annual basis.
The Natural Gas Utility shall respond to all underground utility locate requests and locate their facilities in accordance with the damage prevention laws established within the District of Columbia and the U.S. Department of Transportation. The Natural Gas Utility shall maintain an accurate count of all locate requests, responses to locate requests, number of gas main and service lines inaccurately marked which resulted in damages (e.g., hits per 1,000 locates) or construction delays, number of locations which the Natural Gas Utility failed to mark as required by the damage prevention rules, number of calls not made for One Call ticket numbers by excavator(s), reports of incidents to underground utilities, damages caused by excavators or third party to gas underground facilities, third party responsible for the damage, and the root cause(s) of the damage. An annual report shall be filed with the Commission and a copy to OPC in the QSSPR no later than February 15 of the following year.
The Natural Gas Utility shall monitor high volume condensate drips on its low-pressure distribution network to minimize service continuity disruption. In no case shall a natural gas customer outage caused by condensate accumulation affect more than five percent (5%) of the low-pressure customers during two consecutive winter periods. The Natural Gas Utility shall prepare a remediation plan within one hundred twenty (120) days of exceeding the five percent (5%) standard of service interruption, for the approval of the Commission, and provide a target date for completion of the recommended repair to the low-pressure piping network. The Natural Gas Utility shall file the results with the Commission and a copy to OPC on an annual basis in the QSSPR.
The standard in Subsection 3705.4 may be changed or modified by the Commission, at a later date, based on a study of trends in service interruptions.
The Natural Gas Utility shall measure annually its Lost Time Accident Rate as reported in the Occupational Safety and Health Administration ("OSHA") 300 Log Summary of Occupational Injuries and Illnesses. The Natural Gas Utility shall file the results with the Commission and a copy to OPC on an annual basis in the QSSPR.
D.C. Mun. Regs. tit. 15, r. 15-3705