D.C. Mun. Regs. tit. 15, § 3705
3705.1 The natural gas utility shall establish a gas main 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, segment affected by city or state public improvement projects, etc. At least once each calendar year, the natural gas utility shall rank and identify areas of piping networks of its natural gas operating system requiring improvements to eliminate segments most susceptible to leakage, failure, supply interruptions or failure to meet its minimum design pressure and volume deliverability requirements. The utility shall establish a performance ranking by area, on a scale of one to ten, one being the poorest performing segment. The natural gas utility shall provide the results to OE and OPC on a biennial basis.
3705.2 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 OCMS and OPC on a biennial basis.
3705.3 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 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 or construction delays, number of locations which the utility failed to mark as required by the damage prevention rules, number of calls not made by excavation contractors for accurately marked utility lines as determined by calls or reports of incidents to underground utilities, damages caused by excavators or third party to gas facilities (both above ground and underground), third party responsible for the damage, and the root cause(s) of the damage. An annual report shall be filed with OCMS and OPC in the QSSPR.
3705.4 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 due to condensate accumulation be more than 5% of the low-pressure customer base during two consecutive winter periods. The natural gas utility shall prepare a remediation plan within 120 days of exceeding the 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 OCMS and OPC on an annual basis in the QSSPR.
3705.5 The standard in 3705.4 may be changed or modified, at a later date, based on a study of trends in service interruptions.
3705.6 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 may provide this information on a system-wide basis with a breakdown for each of the jurisdictions. The natural gas utility shall provide the results to OE and OPC on an annual basis in the QSSPR.
SOURCE: Notice of Final Rulemaking published at 56 DCR 7646 (September 25, 2009), incorporating text of Proposed Rulemaking published at 56 DCR 1827, 1844 (February 27, 2009).