Natural Gas Public Utilities with Distribution Systems
The Department requires each gas public utility operating within the State, and providing natural gas, to submit an annual Pipeline Modernization Report. Each gas public utility will be required to include three categories of information in the Pipeline Modernization Report: general information about the mains and service lines in the State, leak monitoring information, and blowdown event information.
Applicable Rules: N.J.A.C. 7:27E – Subchapter 3 REPORTING REQUIREMENTS FOR GAS PUBLIC UTILITIES
1st Reporting year begins on July 1, 2022.
1st Reporting year ends on December 31, 2022
Subsequent reporting is conducted on a calendar year basis (January 1 – December 31)
Reporting Fee = $8000 annually
What to report on
Submit a Pipeline Modernization Report by June 15, 2023, at NJDEPonline.com (available January 1, 2023). The gas public utility must annually report the following information:
1. The miles of mains and number of service lines in New Jersey, identified by material type, in the distribution system at the end of the reporting period.
2. Mains and service lines in New Jersey added, replaced, or refurbished in the reporting period, as follows:
i. Miles of mains grouped by the original mains material type and the replacement or refurbished material type;
ii. Number of service lines grouped by the original service line material type and the replacement or refurbished material type;
iii. Miles of mains added, grouped by material type; and
iv. Number of service lines added, grouped by material type.
3. Identification of each leak from pipeline components that have a leak grade classification ranked as grade 1, 2, or 3, as follows:
i. Leak identification number;
ii. Pipeline component that is leaking or has leaked;
iii. Grade classification of the leak;
iv. Date that the leak is reported;
v. Date that the leak is repaired;
vi. Location of the leak, including the street address or location description, municipality in which the component is located, county, zip code, latitude, and longitude.;
vii. If known, the method by which the leak was identified; and
viii. If known, the volume of methane emissions released, per unit of time.
4. If applicable, leak detection practices that exceed the minimum requirements of 49 CFR Part 192, Subpart M, as follows:
i. Frequency of leak detection surveys;
ii. Types of leak detection equipment or technology utilized;
iii. Leak prevention and reduction efforts; and
iv. Plans to utilize leak detection equipment or technology that exceeds Federal requirements.
5. A report of each blowdown event in excess of 50 standard cubic feet (scf), conducted by a gas public utility, as follows:
i. Blowdown identification number;
ii. The amount of natural gas released, measured in standard cubic feet, as calculated with one of the following methodologies:
(1) The volume of the pipeline segment between isolation valves and the pressure and the temperature of the gas within the pipeline in accordance with 40 CFR 98.233(i)2, incorporated by reference; or
(2) The measurement of emissions using a flow meter in accordance with 40 CFR 98.233(i)3, incorporated by reference;
iii. The percent volume of methane of the natural gas released;
iv. Date of the blowdown event;
v. Reason for blowdown event;
vi. Mitigation efforts to reduce emissions from the blowdown event; and
vii. Location of blowdown event, including street address or location description, municipality, county, zip code, latitude, and longitude.