65-407-420 Me. Code R. § 6

Current through 2024-51, December 18, 2024

Section 407-420-6 - Operation Standards

A.Operator Qualification (OQ) Program Requirements

Operators must include in its OQ Program's written plan:

1. A provision that all of the operator's personnel and the employees of the operator's contractors who may be joining plastic pipe, by any method, or inspecting plastic pipe joints must be qualified (a) directly by an employee of the operator who is fully trained and qualified; or (b) if an operator utilizes an agency to qualify its personnel, all such qualifications must be by the same agency through which the operator has adopted their OQ Program written plan. Any individual(s) conducting inspections or qualification testing must be qualified to join plastic pipe by all methods and have a minimum of two years of experience making all joints they are inspecting or for which they are qualifying others;

2. A provision requiring documentation that all qualified personnel (employees and contractors) have received training, for all tasks for which each person is qualified, prior to being tested for qualification. Operators must retain this documentation for as long as the individual is performing the covered task, and for five years thereafter;

3. A provision requiring documentation indicating that personnel (employees and contractors), qualified for any task by written testing, were tested for those tasks by an independent proctor and that all tests were corrected by the test proctor or by a computerized or online test administrating organization or agency. Operators must retain this documentation for as long as the individual is performing the covered task, and for five years thereafter. If written testing is conducted through a computerized or on-line test administered by the Northeast Gas Association or similar organization or agency, then the operator must ensure that the test proctor has been qualified by the administrator of the test;

4. A provision requiring documentation indicating that personnel (employees and contractors), qualified for any task by hands-on testing, were tested individually for those tasks by an independent proctor and that all tests were corrected by the test proctor. Operators must retain this documentation for as long as the individual is performing the covered task, and for five years thereafter;

5. A provision requiring that. if task testing is computer based, the operator have procedures to ensure that the stated individual is the person actually taking the test(s) and that the stated individual did not receive assistance during the testing. Operators must create documentation regarding the above and retain this documentation for as long as the individual is performing the covered task, and for five years thereafter;

6. A provision that. for tasks other than joining plastic pipe, the operator must perform analysis to verify that the domains and elements of all tasks performed by contractor personnel, qualified by an OQ Program other than the operator's, equate to the tasks as described in the operator's OQ Program. Operators must retain documentation of this analysis for as long as the contractor personnel are performing covered tasks, and for five years thereafter;

7. A provision that if the domains and elements of a contractor's task do not equate to those contained in the operator's OQ Program or if contractor personnel are lacking qualification for necessary tasks, the affected personnel must be qualified by the operator or the same agency through which the operator has adopted its OQ Program written plan; and

8. A provision that prior to the start of each construction season, the operator must provide the Gas Safety Staff with the necessary usernames and/or passwords to access any on-line databases used for the tracking of qualifications of the operator's employees and contractors.

B.Quality Assurance/Quality Control (QA/QC) Program

1. Operators must, as part of their compliance with 49 C.F.R. § 192.605Procedural manual for operations, maintenance, and emergencies, include procedures for evaluating the work performed by operator personnel to determine the effectiveness and adequacy of the procedures used during normal operation and maintenance tasks and to modify the procedures when deficiencies are found. Such procedures must be set out in a written QA/QC program that promotes gas system and related employee and contractor safety through monitoring of field work activities performed during the construction, installation, operation and maintenance of gas facilities. The operator must also develop a construction inspection program for new construction and facility repair work done by its employees and by contractors as part of its QA/QC program.

2. A mandatory component of operators' QA/QC Programs must be on-going audits of tasks performed with a goal to ensure compliance with the operator's written policies, practices, procedures and specifications; and with applicable codes. Record keeping accuracy and completeness verification audits are also included in this component of the QA/QC Program.

3. The QA/QC audit program must include:

a. Field Verification Audits of which a representative number are conducted after field work is completed for specific tasks.

b. Performance Audits which consist of various tasks of which a representative sample are evaluated during the actual time that the work is being performed by the employee or contractor.

c. Construction Inspections that are frequent enough to encompass most of the new facility installation and repairs that are done on the operator's system.

d. Detailed forms incorporating activity checklists prepared to cover normally performed work activities for evaluation or inspection of specified field work and construction.

4. When necessary, operators must use QA/QC audit and construction inspection findings to implement changes in procedures, training, and work practices.

5. Audits must be conducted by management personnel (e.g., supervisors, engineers) and performed on different employees/crews to ensure that all personnel are reviewed and construction work is inspected regularly.

C.Scheduling Permanent Abandonment/Disconnection of Inactive Mains and Service Lines

1. Operators must add and monitor service lines where gas is no longer being billed to a customer and which are not cathodically protected steel or plastic gas service lines equipped with an excess flow valve, according to the operators' DIMP written plans until the lines are disconnected and abandoned.

2. Operators discovering inactive bare steel (unprotected) service lines or stubs in the course of leakage surveillance, construction, maintenance or inspection of facilities must abandon or replace those lines or stubs as follows: If leaking, abandon immediately at the main; if not leaking, abandon or replace as soon as practicable but not more than six months after discovery.

3. The operator must indicate in its mapping system any main or service line that is abandoned at the time it is abandoned.

4. The operator must maintain records of any main or service line that has been abandoned.

5. If a building with an active service line is to be demolished and is not slated to be replaced the operator must abandon the service line must at the main.

D.Leak Detection

1.Leakage Surveys and Patrols. Operators must conduct leakage surveys and patrols according to the following:

a. Operators must conduct a risk-based leakage survey program for all gas mains with, at a minimum, the requirements as set forth in 49 C.F.R. § 192.723. As part of their compliance with 49 C.F.R. § 192.605, operators must provide the detail on the survey cycles. Operators' DIMP written plans must provide the justification, based on data and metrics compiled and reviewed as part of the DIMP written plan, for the selection of each survey cycle identified in the operators' operations and maintenance procedures.

b. Operators must conduct a leakage survey of all cast iron main lines at least every 30 days between December 1 and April 30.

c. Operators must conduct a leak survey at buildings used for public assembly, including schools, post offices, churches, hospitals, nursing homes, theaters, and municipal buildings each year during the period March 1 to December 1. This requirement only applies to all public assembly buildings having a gas service line. Operators must utilize risk-based parameters to identify additional service lines in places of public congregation beyond those listed above, that require a survey each year from March 1 to December 1. Operators must use existing and readily accessible data to identify these risk-based parameters which may include service size, delivery pressure, number of meters, meter size, or building occupancy

d. If, when investigating a leak, an operator determines or has determined that the perimeter of a leak area extends to a building wall, the investigation must continue into the building unless public safety or identifiable urgent circumstances prohibit entry.

e. Once public safety or identifiable urgent circumstances no longer prohibit entry, the investigation, as provided in (d) above, must continue into the building, if the leak has not yet been resolved utilizing a combustible gas indicator.

2.Leak Detection Equipment Calibration and Maintenance

Operators must maintain written procedures for the calibration and maintenance of leak detection equipment. These procedures must consider the type of equipment, frequency of use, manufacturer's calibration recommendations, historical performance, age of equipment, required maintenance intervals and equipment failure protocols.

Operators must review these procedures annually and modify the procedures to the degree necessary to ensure that leak detection equipment used in the field has been properly calibrated and maintained.

E.Leak Classification and Repair

The purpose of the leak grading system is to determine the degree or extent of the potential hazard resulting from gas leakage and to prescribe remedial actions. Operators must promptly respond to any notification of a gas leak or gas odor or any notification of damage to facilities by excavators or other outside sources.

Operators must ensure that leak grading is made only by those individuals who possess training, experience, and knowledge in the field of leak classification and investigation. The judgment of these individuals, based upon all pertinent information and a complete leakage investigation at the scene, must form the basis for the leak grade determination.

1.Leak Response

a. Operators must establish a leak repair priority based on their evaluation of the location and the magnitude of a leak.

b. Operators must assign a classification of leaks in accordance with this subsection;

c. Operators must immediately notify the fire department of the community involved of each Grade 1 leak found to exist in their pipeline systems.

2.Grade 1 Leaks

a. A Grade 1 leak is a leak that represents an existing or probable hazard to persons or property and requires prompt action, immediate repair, or continuous action until the conditions are no longer hazardous. A Grade 1 leak includes but is not limited to:

1. Any leak which, in the judgment of operating personnel at the scene, is regarded as an immediate hazard;

2. Escaping gas that has ignited;

3. Any indication of gas, which has migrated into or under a building, or into a conduit or tunnel;

4. Any reading at the outside wall of a building, or where gas would likely migrate to an outside wall of a building;

5. Any reading of 70% lower explosive limit (LEL) or greater in a confined space;

6. Any reading of 70% LEL or greater in small substructures, other than gas associated substructures, from which gas would likely migrate to the outside wall of a building; or

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

b. A Grade 1 Leak requires an operator to take action immediately to eliminate the hazard and make repairs. The action may require one or more of the following:

1. Implementing an emergency plan;

2. Evacuating premises;

3. Blocking off an area;

4. Rerouting traffic;

5. Eliminating sources of ignition;

6. Venting the area by removing manhole covers, barholing, installing vent holes, or other means;

7. Stopping the flow of gas by closing valves or other means; or

8. Notifying emergency responders.

3.Grade 2 Leaks

a. A Grade 2 leak means a leak that is recognized as being non-hazardous at the time of detection but justifies scheduled repair or removal within six months or less of detection due to the probability of its future hazard.

b. Grade 2 leaks vary greatly in degree of potential hazard. Operators must establish a repair priority for all Grade 2 leaks. In determining the repair priority, Operators must consider criteria such as the following:

1. The amount and migration of gas;

2. The proximity of gas to buildings and subsurface structures;

3. The extent of pavement; and

4. Soil type and conditions, such as frost cap, moisture, and natural venting.

c. Operators must complete Priority 1 repairs within 30 days of detection of any leak:

1. With a sustained reading of 40% LEL, or greater, under a sidewalk in a wall-to-wall paved area that does not qualify as a Grade 1 leak;

2. With a sustained reading of 100% LEL, or greater, under a street in a wall-to-wall paved area that has significant gas migration and does not qualify as a Grade 1 Leak;

3. With a sustained reading less than 70% LEL in small substructures (other than gas associated substructures) from which gas would likely migrate creating a probable future hazard;

4. With a sustained reading between 20% LEL and 70% LEL in a confined space;

5. With a reading on a pipeline operating at 30 percent SMYS, or greater, in a class 3 or 4 location, which does not qualify as a Grade 1 leak;

6. With a reading of 70% LEL, or greater, in gas associated substructures; and

7. Which, in the judgment of operating personnel at the scene, is of sufficient magnitude to justify scheduled repair.

d. Operators must re-evaluate all active Grade 2 leaks at a minimum of every 30 days until the leak is repaired and cleared.

e. Operators must take action ahead of ground freezing or other adverse changes in venting conditions with respect to any leak which, under frozen or other adverse soil conditions, would likely allow gas to migrate to the outside wall of a building.

4.Grade 3 Leaks

a. A Grade 3 leak is a leak that is non-hazardous at the time of detection and can be reasonably expected to remain non-hazardous.

b. Operators must survey and re-evaluate each Grade 3 leak at least once every 180 days from the date of discovery, until the leak is repaired. A leak requiring re-evaluation at periodic intervals includes any reading:

1. Of less than 70% LEL in small, gas-associated substructures;

2. 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; and

3. Of less than 20% LEL in a confined space.

c. Operators must repair each Grade 3 leak within 24 months of its detection unless the leak is located within an approved main replacement program area in which case the operator may extend the time for repair to the scheduled replacement.

5.Bare Steel Service Line Leaks

Operators finding a leak on a bare steel service line must replace the entire service line.

6.Post-Repair Inspections

a. In the case of leak repairs other than Grade 1, the need for a follow-up inspection must be determined by qualified personnel of the operator.

b. Operators must conduct a follow-up inspection as follows:

1. The adequacy of leak repairs must be checked before backfilling;

2. The perimeter of the leak area must be checked with a combustible gas indicator (CGI) or equivalent gas detection equipment; and

3. Where there is residual gas in the ground after the repair of a Grade 1 leak, the operator must conduct a follow-up inspection as soon as practical after allowing the soil atmosphere to vent and stabilize, but in no case later than one month following the repair.

c. A leak is considered to be effectively repaired when an operator's operating personnel obtains a gas concentration reading of 0%.

d. For a repaired leak with a gas concentration reading greater than 0% at the time of repair, operators must conduct a post-repair leak inspection within 30 days after the repair to determine whether the leak has been effectively repaired. If the second post-repair inspection shows a gas concentration reading greater than 0%, operators must continue conducting post-repair leak inspections every 30 days until there is a gas concentration reading of 0%. If on cathodically protected steel or plastic pipe, three post-repair inspections have been performed and the operator is unable to obtain a gas concentration reading of 0%, then the operator must initiate a new repair. For cast iron or unprotected steel pipe, which is included in an MPUC-approved pipe replacement program, and the operator is unable to obtain gas concentration readings of 0% after the third recheck, then these leaks must be regraded and moved to active status. Additional repairs will be required utilizing the requirements established for the new leak grading. If, after the third post-repair leak inspection, an operator regrades a leak and moves it to active status, the new leak classification will be based on the highest gas reading, or other conditions found during the third inspection, that results in the most conservative leak grade, prior to venting or other activity.

e. Post-repair inspections are not required for leak repairs completed by the replacement or insertion of an entire length of pipe or service line, or for the repair of leakage caused by excavator or third-party damage, provided a complete re-evaluation of the leak area after completion of repairs verifies that no further indications of leakage exist.

f. Remedial measures such as lubrication of valves or tightening of packing nuts on valves which seal leaks are considered to be routine maintenance work and do not require a post-repair inspection.

7.Upgrading. When operators upgrade a leak to a higher grade, the time period for repair is the remaining time based on its original classification or the time allowed for repair under its new grade, whichever is less. This requirement does not apply to leaks that, at the time of discovery, the operator classified at a lower grade pending a further, more complete investigation of the leak hazard area.

8.Downgrading. Operators must not downgrade a leak unless it is repaired.

F.Leak Progression Maps. Operators must institute and maintain on a continuing basis a leak progression mapping system of their service areas in a format that conforms with the specifications of Chapter 140. Map attributes to be included for each leak must be: pipe or appurtenance material; location of leak; cause of leak; and type of joint, if joint leak. Operators must enter into the system all leaks that have occurred since January 1, 2009. Operators should enter into the system leak history information prior to January 1, 2009 if the operator can verify the accuracy of the information.

65-407 C.M.R. ch. 420, § 6