The Public Utilities Article, Annotated Code of Maryland, provides that the Commission shall have the power to make such reasonable regulations as it deems necessary to carry out the provisions of this law and any other law relating to the Commission. Application. These regulations apply to a gas utility or gas master meter operator operating within the State, under the jurisdiction of the Public Service Commission. Purpose. These regulations are intended to promote safe and adequate service to the public, to provide standards for uniform and reasonable practices, and to outline the responsibility of the public in requesting and receiving service from a utility. Exemption. If unreasonable hardship to a utility, gas master meter operator, or to a customer results from the application of any of these regulations, application may be made to the Commission for the modification of the regulation or for temporary or permanent exemption from its requirements. Modification. The adoption of these regulations does not preclude the Commission from altering or amending them, or from making such modifications with respect to their application as may be found necessary to meet exceptional conditions. Duties Under Other Statutes. These regulations do not relieve any utility from any of its duties under the laws of this State. In this subtitle the following terms have the meanings indicated. Terms Defined. Abbreviations. “Btu” means British thermal unit. “LNG” means liquefied natural gas. “LPG” means liquefied petroleum gas. “PSIG” means pounds per square inch, gauge. “W.C.” means water column. “Accuracy” means the degree of conformity of a measure to a standard or true value. “Check flow” means a flow between 20 percent and 50 percent of the rated capacity of a meter. “Commission” means the Public Service Commission of Maryland. “Cubic foot” of gas means: Where gas is supplied and metered to customers at the pressure normally maintained on residential customers' meters, a cubic foot of gas is that quantity of gas which, at the temperature and pressure existing in the meter, occupies 1 cubic foot. Where gas is supplied and measured with corrections made for pressure or temperature conditions, or both, existing in the meter, a cubic foot of gas is that quantity of gas which occupies a cubic foot after the metered quantity has been corrected to the absolute pressure or the temperature, or both, specified in the utility's tariff (see COMAR 20.55.03.01B(8)). The standard cubic foot of gas for testing the gas itself for heating value shall be that quantity of gas, saturated with water vapor, which at a temperature of 60°F and a pressure of 30 inches of mercury occupies 1 cubic foot. (Temperature of mercury = 32°F; acceleration due to gravity = 32.17 feet per second per second; density of mercury = 13.595 grams per cubic centimeter.) “Customer” means a person, partnership, association, corporation, or governmental agency being supplied with gas service and whose name appears on the application for service. “Division” means the Engineering Division of the Commission. “Full rated flow” means a flow of approximately 100 percent of the rated capacity of a meter. “Gas master meter operator” has the meaning stated in Public Utilities Article, §1-101, Annotated Code of Maryland. “Gas plant” or “pipeline facility” means new and existing pipelines, rights-of-way, and any equipment, facility, or building used in the transportation of gas or in the treatment of gas during the course of transportation. “Incident” has the meaning stated in 49 CFR §191.3, as amended, which is incorporated by reference. “Main” means a distribution line that serves as a common source of supply for more than one service line. “Meter”, without other qualification, means a device which is used by a utility in measuring a quantity of gas. “Percent accuracy” means the ratio expressed in percent of the meter indicated volume (numerator) to the prover or other working standard volume (denominator) obtained in volumetric testing of gas meters. “Percent proof” means the ratio expressed in percent of the prover or other working standard volume (numerator) to the meter indicated volume (denominator) obtained in volumetric testing of gas meters. “Pipeline” means all parts of those physical facilities through which gas moves in transportation, including pipe, valves, and other appurtenances attached to pipe, compressor units, metering stations, regulator stations, delivery stations, holders, and fabricated assemblies. “Places of public assembly” means a building or portions of a building used for gathering together of 100 or more persons, the capacity being designated by the fire department for common purposes of deliberation, worship, or services, such as but not limited to churches, schools, hospitals, halls, theaters, and municipal facilities. “Premises” means a tract of land or real estate, including buildings and other appurtenances on it. “Rated capacity of a meter” means the capacity of the meter as specified by the manufacturer under the conditions of use. “Service line” means a gas pipe owned, operated, or maintained by a utility that runs from a main or a pipeline to the meter serving a customer. “Utility” or “company” means any gas company operating under the jurisdiction of the Commission. “Working standard” means the prover, test meter, or other approved device used to test customer meters or associated devices, or both. State Government Article, §7-207(a); Public Utilities Article, §§2-113, 2-121, 5-101, and 7-301; Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .02A amended effective April 10, 1995 (22:7 Md. R. 538) Regulation .02B, C amended effective February 7, 2000 (27:2 Md. R. 145) Regulation .03 repealed effective May 5, 1986 (13:9 Md. R. 1031) Regulation .04 amended effective May 5, 1986 (13:9 Md. R. 1031); December 25, 1989 (16:25 Md. R. 2714); July 20, 1992 (19:14 Md. R. 1285) Regulation .04B amended effective April 10, 1995 (22:7 Md. R. 538); December 29, 1997 (24:26 Md. R. 1759); February 7, 2000 (27:2 Md. R. 145); March 26, 2007 (34:6 Md. R. 629) The gas plant of the utility or gas master meter operator shall be constructed, installed, maintained, and operated in accordance with accepted good engineering practice in the gas industry to ensure, as far as reasonably possible, continuity of service, uniformity in the quality of service furnished, and the safety of persons and property. In addition to the regulations found in this chapter, each utility or gas master meter operator shall comply with the following federal regulations, which are incorporated by reference: 49 CFR 40, “Procedures for Transportation Workplace Drug and Alcohol Testing Programs”, as amended; 49 CFR 191, “Transportation of Natural and Other Gas by Pipeline; Annual Reports, Incident Reports, and Safety Related Condition Reports”, as amended; 49 CFR 192, “Transportation of Natural and Other Gas by Pipeline: Minimum Federal Safety Standards”, as amended; 49 CFR 193, “Liquefied Natural Gas Facilities: Federal Safety Standards”, as amended; 49 CFR 199, “Drug and Alcohol Testing”, as amended. Each utility or gas master meter operator shall use as accepted good engineering practice the applicable provisions in: The GPTC Guide for Gas Transmission and Distribution Piping Systems 2003, Volume One with Addenda No. 1—4, which are incorporated by reference; The American National Standard, “National Fuel Gas Code”, ANSI Z223.1 (1988), which is incorporated by reference; “Orifice Metering of Natural Gas”, Report No. 3 of American Gas Association Gas Measurement Committee; The American National Standard for Gas Displacement Meters (500 Cubic Feet per Hour Capacity and Under), (ANSI B109.1 and ANSI B109.2), which is incorporated by reference; The American National Standard for Diaphragm Type Gas Displacement Meters (Over 500 Cubic Feet per Hour Capacity), (ANSI B109.2), which is incorporated by reference; The American National Standard for Rotary Type Gas Displacement Meters, (ANSI B109.3), which is incorporated by reference. The production or storage capacity, or both, of the utility's plant, combined with the gas supply regularly available from other sources, shall be sufficiently large to meet all reasonably expectable demands for service. Each utility or gas master meter operator shall adopt a program of inspection of its gas plant in order to determine the necessity for replacement and repair. The frequency of the various inspections shall be based on experience and accepted good practice. Sufficient records shall be kept to give evidence of compliance with the inspection program. Each utility or gas master meter operator shall inspect its gas pipeline system to ensure that it is constructed in accordance with the applicable requirements of this subtitle. State Government Article, §7-207(a); Public Utilities Article, §§2-121, 5-101, 5-302, 5-303, and 11-101; Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .01 amended effective January 15, 1996 (23:1 Md. R. 35) Regulation .02 amended effective May 5, 1986 (13:9 Md. R. 1032); January 15, 1996 (23:1 Md. R. 35); February 7, 2000 (27:2 Md. R. 145); March 26, 2007 (34:6 Md. R. 629) Regulation .02A amended as an emergency provision effective October 30, 1985 (12:22 Md. R. 2102)(Emergency provisions are temporary and not printed in COMAR) Regulation .02C amended effective December 25, 1989 (16:25 Md. R. 2715) Regulation .04 amended effective January 15, 1996 (23:1 Md. R. 35); January 15, 1996 (23:1 Md. R. 35); February 7, 2000 (27:2 Md. R. 145) Each utility shall file with the Commission a copy of its tariff which shall include: Rates. Each schedule of rates for service together with the applicable riders. Rules. The utility's rules, or terms and conditions, describing the utility's policies and practices in rendering service. These rules shall include: Extension Plan. The utility's plan for the installation of extensions of main and service lines where these facilities are in excess of those included in the regular rates for service and for which the customer shall be required to pay all or part of the cost. The customer's payment under this plan should be related to the investment that the utility prudently can make in consideration of the probable revenue. Heating Value. The total heating value of the gas in Btu per standard cubic foot. Material Furnished by Utility. A list of the items which the utility furnishes, owns, and maintains on the customer's premises, such as meters, service line, regulators, vents, and shut-off valves. No Charge Service. A general statement indicating the extent to which the utility will provide service at no charge for the adjustment of customers' appliances. Wastage of Gas. A general statement of the utility's policy in making adjustments for wastage of gas when wastage occurs without the knowledge of the customer. Billing Period. A statement indicating the minimum and maximum number of days for which the utility will bill a customer at its regular monthly rates for service. Payment Period. A statement indicating the minimum number of days allowed for payment of the gross amount of the customer's bill before service will be terminated for non-payment. Measurement Base. A statement indicating the atmospheric pressure, the absolute pressure or temperature, or both, used when pressure or temperature correction is made to the metered volume of gas. (See COMAR 20.55.01.04B(5)) Each utility shall file with the Commission the following items necessary in the administration of these regulations: Special Contracts. A copy of each contract for service not covered by the utility's filed tariff. Installation Rules. A copy of the utility's rules, if any, designed by the utility for the use of engineers, architects, plumbing and heating contractors, etc., covering meter and service installations. Bill Forms. A sample of each type of customer bill form, which shall include the information normally shown on a customer's bill for service. Monthly Payment Plan. Each utility offering to its customers an even or equal monthly payment plan shall file a copy of the plan with the Commission. Map of System. A map showing the utility's operating area. This map shall be revised annually unless no revision is necessary, to reflect a material change in the items listed below. The map on file should reflect the current status of the following items: Source of supply (gate stations and gate meters); LNG, LPG and other major storage facilities; Principal mains by size; Peak shaving plants; State boundary crossings; Franchise service areas approved by the Commission; Names of all communities (post offices) served. Persons to Contact. The name, title, address, and telephone number of the person who should be contacted in connection with the following areas of operation: General management duties; Customer relations (complaints); Engineering operations; Meter tests and repairs; Safety; and Emergencies during non-office hours. Telephone Notice of Incidents. Each utility or gas master meter operator shall promptly notify a representative of the Public Service Commission by telephone of each incident as defined in COMAR 20.55.01.04B(9). Written Notice of Incidents. As soon as practicable but not later than 30 days after discovery, a utility shall file a written report of each incident with the Public Service Commission. This report shall be a copy of the report submitted to the U.S. Department of Transportation. An “incident” is defined in COMAR 20.55.01.04B(9). Annual Reports. Each utility shall submit to the Public Service Commission a copy of the annual report filed with the U.S. Department of Transportation. This report shall be submitted each year not later than March 15 for the preceding calendar year. Those utilities who also operate transmission pipelines shall submit to the Public Service Commission a copy of the annual report filed with the U.S. Department of Transportation. This report shall be submitted each year not later than March 15 for the preceding calendar year. Construction Notice. A utility or gas master meter operator shall notify the Engineering Division of the Commission in writing at least 10 days before the estimated start date of major construction projects. Under this regulation a major construction project includes: New pressure-regulating stations; Significant modifications to gas supply equipment at existing pressure-regulating stations; New natural gas, LNG, or peak shaving propane plants; Significant modifications to process equipment at existing natural gas, LNG, or peak shaving propane plants; or New pipeline installations of: 500 or more feet of main or transmission pipeline for all gas master meter operators and utilities with 50,000 or less customers, or 2,000 or more feet of main or transmission pipeline for all utilities with more than 50,000 customers. The notification as required by this regulation shall be on a form provided by the Division. Gas Service Monthly Reports. A gas service monthly report, on forms provided by the Commission, showing information concerning the utility's operations. These reports shall be due in the Commission's office within 30 days after the end of the month reported. Location of Records. The location at which the utility keeps the various classes of records required by these regulations. Organizations. Each company shall designate a representative to meet with other company representatives on a regular basis, such as with the Maryland Gas Operators Advisory Committee, Maryland-D.C. Utilities Association or other organizations, for the purpose of establishing and maintaining: Uniform formats and practices for reporting to the Commission and the Office of Pipeline Safety; A state-of-the-art information and data exchange between companies regarding equipment, facilities, suppliers, practices, and procedures; and Other pertinent programs. The companies shall from time to time advise the Commission as to the status of the meetings. Records. A utility or gas master meter operator shall make available to the Commission or its authorized representative all records required by these regulations or necessary for the administration of these regulations. Location of Pipeline. The utility or gas master meter operator shall: Record and retain records indicating the location of all pipelines which it owns so that the records are as accurate as reasonably practicable; Update the records so that all pipelines are included within 6 months of being placed in service; and Make the information available, upon reasonable request, to: Contractors, Other utilities, Governmental agencies, or Other interested persons. Pipeline Location Services. A utility shall make available suitable equipment and personnel to provide pipeline location services upon reasonable request of interested persons, in compliance with Public Utilities Article, Title 12, Subtitle 1, Annotated Code of Maryland. A utility or gas master meter operator shall preserve all records required by these regulations for the time specified in 18 CFR 125, as amended, which is incorporated by reference, unless otherwise specified by the Commission. State Government Article, §7-207(a); Public Utilities Article, §§2-121, 5-101, 5-302, and 6-203—6-207; Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .01 amended effective May 5, 1986 (13:9 Md. R. 1032); July 20, 1992 (19:14 Md. R. 1285) Regulation .02 adopted effective May 5, 1986 (13:9 Md. R. 1032); amended effective August 25, 1986 (13:17 Md. R. 1924) Regulation .02E amended effective March 18, 2013 (40:5 Md. R. 412) Regulation .02G amended effective December 25, 1989 (16:25 Md. R. 2715); July 31, 1995 (22:15 Md. R. 1121) Regulation .02H amended effective December 25, 1989 (16:25 Md. R. 2715); July 31, 1995 (22:15 Md. R. 1121); December 29, 1997 (24:26 Md. R. 1760) Regulation .02I repealed and new Regulation .02I adopted effective December 25, 1989 (16:25 Md. R. 2715) Regulation .02J amended effective September 18, 1989 (16:18 Md. R. 2024); July 31, 1995 (22:15 Md. R. 1121); March 26, 2007 (34:6 Md. R. 629) Regulation .02M amended effective February 7, 2000 (27:2 Md. R. 145) Regulations .03 and .04 adopted effective May 5, 1986 (13:9 Md. R. 1032) Regulation .03A amended effective April 10, 1995 (22:7 Md. R. 538) Regulation .03B amended effective November 17, 1986 (13:23 Md. R. 2481); April 10, 1995 (22:7 Md. R. 538); February 7, 2000 (27:2 Md. R. 145) Regulation .04 amended effective February 7, 2000 (27:2 Md. R. 145); March 26, 2007 (34:6 Md. R. 629) System Maps or Records. Each utility shall maintain up-to-date maps, plans, or records of its entire transmission and distribution systems, with such other information as may be necessary to enable the utility to advise prospective customers, and others entitled to the information, as to the facilities available for serving any locality. Selecting Rate Schedule. Each utility shall assist the customer or prospective customer in selecting the most economical rate schedule. Notifying Customers. Each utility shall notify customers affected by a change in rates or schedule classification. Tariff Notice. Each utility shall post a notice in a conspicuous place in each office of the utility where applications for service are received, informing the public that a copy of its tariff, as filed with the Commission, is available for inspection. A utility shall post its tariff and pending tariff changes on its website. After Commission acceptance of a tariff change, a utility shall update the tariff posted on its website not later than 3 business days after the date of acceptance. Meter Reading Instruction. Upon request, each utility shall inform its customers as to the method of reading meters. Hazards of Gas. At least twice each year, a notice shall be distributed to each customer, informing him of the hazards of leaking gas and instructing him of the procedures to be followed in reporting gas leaks. At the same time, notices to the general public informing them of the same information shall be made through newspaper ads. Notices (customer and general public) shall make mention of the possible entry of gas by the various means including leakage along other routes, possibly even if the party does not have gas service. In addition, a sample odor indicator shall be distributed to each customer at least biennially. Other Information. Each utility shall furnish such additional information as the customer may reasonably request. A utility may accept either written or verbal applications for service. Each verbal application for service shall be promptly confirmed in writing by the utility. A utility may require an applicant to sign and return a copy of the written confirmation. The application shall include the: Name, address, home and work telephone numbers, and employer of the customer of record; Address of the premises for which gas service is requested; Mailing address and telephone numbers of the customer of record if he is not an occupant of the premises for which service is requested; and Customer of record's former gas service address and the date customer moved, if applicable. A utility may require an applicant to sign and return a copy of the written confirmation before providing service. Upon request of the applicant, a gas utility shall accept more than one individual customer name on applications for service. All persons named on an account shall be customers of record. When the name of the person applying for service is different from the name of the applicant, when more than one name is to be on an account, or when there is a reasonable basis for questioning the authority of a person requesting service in the name of the applicant, the utility may request that the applicant or applicants appear at the utility's designated office, present satisfactory identification, and execute a written application for service. Customer Identification. A utility may require a customer to provide a written, signed statement attesting to an order, decree, or agreement formalizing a name change, but may not request a copy of the actual order, divorce decree, or separation agreement. Payment of Outstanding Bills. Except as prohibited by State or federal law, a utility may refuse to provide service for a former customer unless the customer has paid or has made satisfactory arrangements to pay any outstanding bill or undisputed portion of a disputed bill for prior residential service. A utility may not refuse service to a customer for nonpayment of any outstanding bill that is over 7 years old, unless the: Customer signed an agreement to pay the outstanding bill before the expiration of this period; or Outstanding bill is for service obtained by the customer in any manner described in COMAR 20.31.02.03D or COMAR 20.31.02.04A(1)—(4). Refusal to Connect Service. A utility may refuse to connect service if an attempt to secure service is made in any manner described below. If application is made: In a fictitious name; In the name of an individual who is not an occupant of the premises, without disclosure of the individual's actual address; In the name of a third party without disclosing that fact or without bona fide authority from the third party; Without disclosure of a material fact or by misrepresentation of a material fact; For connection of service to a residence where there are co-occupants, if a service account for that dwelling unit was previously maintained in a current co-occupant's name during a period of co-occupancy with the applicant and the co-occupant has failed to pay or make satisfactory arrangements to pay an outstanding bill or undisputed portion of a disputed bill for service at the dwelling unit, the collection of which is not barred under applicable State or federal law; For connection of service to a dwelling unit where there are co-occupants, if the service account of a prior dwelling unit of the applicant was listed in a current co-occupant's name and the co-occupant has failed to pay or to make satisfactory arrangement to pay an outstanding bill or undisputed portion of a disputed bill for service at the prior dwelling unit, the collection of which is not barred under applicable State or federal law; or By an individual for the purpose of assisting another occupant of a dwelling unit to avoid payment of that occupant's prior outstanding bill. For purposes of §B, “co-occupants” means two or more adults who occupy the same dwelling unit as their primary domicile, or legal residence within the State. For purposes of this regulation, a utility may provide service conditionally for not more than 30 days after the date of application. If, during this time, a utility discovers that an application has been made in one of the manners enumerated in this regulation, it may disconnect service in accordance with §§E and F. If a utility denies or disconnects service pursuant to this regulation, the utility shall notify the individual in writing of the reason for the denial or disconnection including the facts or circumstances upon which the utility bases its determination that service should be denied or disconnected. An individual who disputes the proposed denial or disconnection shall do so in accordance with the provisions of COMAR 20.32.01. The Commission’s Consumer Affairs Division may direct a utility to connect service, if deemed safe, in a customer’s name during the pendency of an investigation if a utility denies an application for service due to an unpaid arrearage for unauthorized use or tampering with equipment furnished and owned by the utility but does not provide the amount necessary to reconnect service within 3 business days of a filed complaint, provided that the applicant makes a payment to the utility: In an amount that represents 2/12 of the estimated charges for service for the ensuing 12 months; and Of any outstanding prior bill or in accordance with an alternate payment plan as described in COMAR 20.31.01.08 and agreed to by the utility. Each utility may require from a customer a deposit to be applied against any unpaid balance due the utility for service at the time service is terminated, in accordance with the provisions of Subtitle 30 of this title. The bill forms shall show: The readings of all meters used for billing purposes at the end of the period for which the bill is rendered; The meter reading date; The number and kind of units metered; The applicable rate schedule, or identification of the applicable rate schedule, including any applicable seasonal rates; Any State or local surcharges; The applicable late payment charge, if any, separately stated or labelled a late payment charge, or a statement that the total amount due includes a late payment charge, and an explanation of the calculation of the date of applicability of the late payment charge; The total due, including any prior unpaid amount but excluding the current late payment charge; The date by which the customer shall pay the bill in order to avoid a late payment charge; A distinct marking to identify an estimated bill; Information concerning the customer's gas usage during the same billing period in the prior year; The utility's appropriate business address and telephone number for billing inquiries; and Any conversions from meter reading units to billing units, or any calculations to determine billing units from recording or other devices, and any other factors used in determining the bill. Rate Schedule. If the actual rates are not shown on the bill form as required in §A(4) of this regulation, the bill shall carry a statement to the effect that the applicable rate schedule, including the actual seasonal, purchased gas or thermal adjustments, and the customer charge, will be furnished on request. The Commission may, for good cause, grant a waiver or exemption from provisions in this regulation. A utility may request a waiver or exemption by filing an application with the Commission which sets forth the facts and reasons for the waiver or exemption. The utility shall retain customer billing records for the length of time necessary to permit the utility to comply with Regulation .05 of this chapter, but not less than 3 years. Fast Meters. Whenever a meter is tested and found to have over-registered more than 2 percent, the utility shall recalculate the bills for service of the last customer of record receiving service through the meter and shall make a refund if the amount of the adjustment exceeds $1. The refund shall be for the period that the customer received service through the meter, but for not more than the periods established in §A(2) of this regulation. Known Date of Error. If the date on which the error first developed or occurred can be established, then the utility shall make a refund based on that known date. If the known date of error cannot be established, then it shall be assumed that the over-registration existed for a period of 3 years or a period equal to one-half of the time since the meter was last tested, whichever is less. Non-registering Meters. Whenever a meter is found not to register, the utility may render an estimated bill. Slow Meters. Whenever a meter is found to be more than 2 percent slow, the utility may bill the customer one-half of the unbilled undercharge for a period of 12 months, unless the meter has been tested within that 12-month period, in which event the utility may bill the customer one-half the unbilled undercharge for the period since the meter was last tested. If the amount of under-registration is less than $5, the utility may not bill the customer for the undercharge. Accuracy Calculation. Billing adjustments due to fast or slow meters shall be calculated on the basis that the meter should be 100 percent accurate. For the purpose of billing adjustment, the meter error shall be the error at check flow. Overcharge--Undercharge Adjustment. When a customer has been overcharged or undercharged for services because of incorrect application of the rate schedule, incorrect calculation of charges, or other similar reasons, the amount of overcharge or undercharge adjustment shall be determined separately during the period of time the discrepancy occurred, in accordance with the following: Overcharge Adjustment. The total overcharge for the period the discrepancy occurred shall be refunded or credited to the customer, except for an overcharge resulting from an incorrect reading of the meter when the amount shall automatically be corrected in a subsequent billing based on the correct meter reading. Undercharge Adjustment. Unless authorized by the Commission, retroactive billing may not be for undercharging which occurred more than 12 months before the discovery of the error. A utility may seek the Commission's authorization for retroactive billing for undercharges which occurred more than 12 months but not more than 3 years before the discovery of the error if the customer knew, or reasonably should have known, that the bills were in error. The utility's request to the Commission shall be in writing and shall explain the factual basis for the request to the customer with a notice of the customer's right to write to the Commission, within 20 days, if the customer is in opposition to the request. If the total undercharge is more than 35 percent of the customer's average monthly bill during the preceding 3 months, the customer shall be allowed to enter into an installment plan to pay the total retroactive billing, without interest. In such a plan the monthly payments against the undercharge may not exceed 35 percent of the customer's average monthly bill during the preceding 3 months. However, if the installment plan will not recover within a 12-month period the total undercharge, the monthly payment may be equal to the total undercharge divided by 12 or a number greater than 12. Unless otherwise authorized by the Commission, the utility may deny service for nonpayment only for that portion of the undercharge applicable to the 4 months immediately before the discovery of the error. If requested by a customer, a utility shall provide means by which any undercharge may be paid in installments over a reasonable period of time, but not less than the same time period in which any undercharges were incurred. Theft of Service. If a meter is found not to register, in whole or in part, due to tampering or interference with the company’s material, equipment, or facilities, the utility may issue an estimated bill. The company shall retain all information relied on to calculate the estimated bill for not less than 3 years or until the conclusion of a Commission investigation, whichever is longer. If local authorities require an inspection of customer's piping, the utility may not provide a customer with gas service until the inspecting authority certifies that the piping conforms to the applicable code. The utility shall investigate promptly and thoroughly any complaint concerning its charges, practices, facilities, or service. The utility shall keep such records of customer complaints as will enable it to review and analyze its procedures and actions as an aid in rendering improved service. Grading. Rights-of-way, easements, and service routes shall be cleared and graded to within 6 inches of final grade by the applicant, including certification by the applicant that the grade has been achieved before the utility will commence construction. The clearing and grading shall be maintained by the applicant during construction by the utility. (Agency note: Applicant is either company or customer.) Change in Grade. If, subsequent to construction, the clearance or grade is changed in such a manner as to require relocation of pipelines or other facilities, the cost of the relocation shall be borne by the applicant or his successor. Public Utilities Article, §§2-113, 2-121, 5-101, and 7-301, Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .01D amended effective September 21, 2009 (36:19 Md. R. 1438) Regulation .01F amended effective March 6, 1989 (16:4 Md. R. 498) Regulation .01-1 adopted effective November 18, 1985 (12:23 Md. R. 2225); amended effective July 28, 1986 (13:15 Md. R. 1736) Regulation .01-2 adopted effective April 21, 1986 (13:8 Md. R. 905); amended effective July 28, 1986 (13:15 Md. R. 1736) Regulation .01-2A amended effective May 10, 1993 (20:9 Md. R. 780) Regulation .01-2G adopted effective August 29, 2016 (43:17 Md. R. 957) Regulation .02 amended effective January 23, 1981 (8:2 Md. R. 117) Regulation .03 amended effective November 18, 1985 (12:23 Md. R. 2225) Regulation .05 amended effective November 18, 1985 (12:23 Md. R. 2225); April 21, 1986 (13:8 Md. R. 905); February 7, 2000 (27:2 Md. R. 145) Regulations .06—.08 repealed effective October 14, 1991 (18:20 Md. R. 2200) Regulation .05G adopted effective August 29, 2016 (43:17 Md. R. 957) Regulation .13 adopted effective August 6, 1976 (Order No. 61881) Regulation .13 repealed effective November 18, 1985 (12:23 Md. R. 2225) Customer Use. All gas sold by a utility shall be on the basis of meter measurement, except for installations where the usage is constant and the consumption may readily be computed, or as provided for in its filed rates. Utility Use. Wherever practicable, consumption of gas within the utility itself, or by administrative units associated with it, shall be metered, except for installations where the usage is constant and the consumption may readily be computed. Meters. Before any meter may be installed for use for revenue billing purposes, the type and design of the meter shall be approved by the Commission. Correcting Devices. Before any pressure or temperature device may be used for the purpose of correcting the registration of a meter, the type and design of the device or devices shall be approved by the Commission. Testing Equipment. Before any type of prover or other item of testing equipment may be used to test meters and associated devices, the type and design of the provers or testing equipment shall be approved by the Commission. Condition. A meter may not be installed if it is mechanically defective, has incorrect constants, or has not been tested, and adjusted if necessary. Capacity. The capacity of the metering installation and the index mechanism should be consistent with the gas requirements of the customer. If it is necessary to apply a multiplier such as 10, 100, 1000, etc. to a meter reading to obtain the actual consumption, the information shall be shown on the face of the meter register. Meters shall be read at approximate monthly intervals, unless otherwise authorized by the Commission. The meter reading sheets, cards, or records from which bills are prepared shall show: Customer's name, address, and rate schedule; Identifying number or description of the meter; Meter readings; Date of meter reading; If the reading has been estimated; Any applicable fixed multiplier or constant. Each utility shall maintain records of each meter and associated metering device which will identify each item as to its design, capacity, and application. The identifying information may include, as applicable: manufacturer, number, type, capacity, multiplier, constants, pressure rating, and compensated index with associated pressure. Each utility shall maintain records for each meter and associated metering device, which shall show, as applicable, the date of installation, the date of removal from service, and the location at the present address. Each utility shall maintain the latest test records for each meter which shall include the following: The date and reason for the test; The reading of the meter before making any test; The proof “as found” at check flow; The proof “as left” at check and full rated flow; and If a test of the meter is made by using a working standard other than a bell prover, the utility shall retain all data taken at the time of the test in sufficiently complete form to permit the convenient checking of the test methods and the calculations. Public Utilities Article, §§2-121, 5-101, and 7-301, Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .06F amended effective February 7, 2000 (27:2 Md. R. 146) Meter Shop. Each utility shall maintain or designate a meter shop for the purpose of inspecting, testing, and repairing meters. The shop shall be open for inspection by authorized representatives of the Commission at all reasonable times, and the facilities and equipment, as well as the methods of making the measurements and tests employed, shall be subject to the approval of the Commission. Temperature Control. The area within the meter shop used for the testing of meters shall be designed so that the meters and meter testing equipment are protected from drafts and excessive changes of temperature. The meter shop shall be air-conditioned, if necessary, in order to achieve satisfactory temperature control. Meter Storage. Unless the proving equipment corrects for temperature differences, the meters to be tested shall be stored in such manner that, at the time of the test, the temperature of the meters is substantially the same as the temperature of the prover. Required. Each utility shall own and maintain, or have access to, one or more calibrated meter provers of appropriate size, and all other equipment necessary to test meters. Temperature Control of Bell Provers. Means shall be provided to maintain the temperature of the liquid in the bell provers at substantially the same level as the air temperature in the prover room. The maximum difference in temperature should not be more than 2°F. Accuracy. Each meter prover shall be maintained in good condition, in correct adjustment, and accurate to within ±0.3 percent at each point used in testing meters. A prover shall be calibrated at least once every 3 years and if moved or disassembled. The accuracy of a bell prover shall be determined by one or more of the methods indicated below: By comparison to a 1 cubic foot standard calibrated by the National Institute of Standards and Technology; By comparison to an approved transfer standard for a bell prover in excess of 5 cubic feet; or By strapping the bell prover with a calibrated tape whose accuracy is traceable to the National Institute of Standards and Technology. The accuracy of any other type of prover shall be determined by appropriate standards traceable to the National Institute of Standards and Technology. Attachments. A device used in conjunction with a prover is calibrated to the following accuracy standards: If the accuracy of the attachment is determined independently of the system accuracy it shall be within ±0.2 percent; or If the accuracy of the system includes the accuracy of the attachment the system accuracy shall be within ±0.3 percent at each point used in testing meters. Approved. Utilities may test meters by other methods approved by the Commission or by use of other working standards approved by the Commission. Accuracy. The approved working standards shall be maintained in good condition and correct adjustment, shall have a high degree of repeatability, and shall be capable of determining the actual proof of the meter under test to within ±0.5 percent at rates of flow between 15 percent and 100 percent of rated capacity of the meter under test. Test Period. The approved working standards shall be tested for accuracy by comparison with an acceptable standard at least once each 3 years. Each utility which corrects meter readings to compensate for pressure shall have dead weight testers, test quality electronic pressure transducer gauges, test quality precision type bourdon tube spring gauges, mercury manometers, or field type dead weight pressure gauges as necessary for the proper testing of the pressure correcting devices. Each utility which corrects meter readings to compensate for temperature shall have accurate thermometers and other equipment as necessary for the proper testing of the temperature correcting devices. Each standard shall be accompanied at all times by a certificate or calibration card, duly signed and dated, on which are recorded the corrections required to compensate for errors found at the customary test points at the time of the last previous test. Care shall be exercised in the use and handling of test equipment to assure that the accuracy is not impaired. Public Utilities Article, §§2-121, 5-101, and 7-301, Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .01C amended effective February 7, 2000 (27:2 Md. R. 146) Regulation .02 amended effective May 5, 1986 (13:9 Md. R. 1032); February 7, 2000 (27:2 Md. R. 146) Regulation .03A amended effective February 7, 2000 (27:2 Md. R. 146) Regulation .04 amended effective February 7, 2000 (27:2 Md. R. 146) General. The test of any meter or associated devices, or both, shall consist of a comparison of its accuracy with the accuracy of a working standard or may consist of other methods referenced in these regulations. Test Equipment Capacity. The test equipment shall be of sufficient capacity and ranges to test meters or associated devices, or both, under the conditions specified in Regulation .02 of this chapter. Accepted Good Practice. The Commission will use the applicable provisions of the publications listed in COMAR 20.55.02.02 as criteria of accepted good practice in the testing of meters. Bell Provers. Bell provers may be used to test diaphragm, rotary, and turbine type meters. A prover that is used to test rotary and turbine type meters shall be properly automated and have a satisfactory readout. The test shall consist of passing a specific volume of air through the prover and the meter. The accuracy or proof is either read or calculated from the prover scale or the readout. Working Standards Other Than Bell Provers. Approved working standards other than bell provers may be used to test diaphragm, rotary, and turbine type meters. The meter to be tested is connected to the approved working standard so that the same volume of air, either under pressure or vacuum, passes through both. The uncorrected accuracy is calculated or read directly from the readout on the working standard. Corrections shall be made for pressure and temperature differentials between the meter under test and the working standard to determine the corrected accuracy. Rotary Displacement Meters. Rotary meters on which an original test record of the differential pressures is established as soon as practicable, but not longer than 6 months, after installation may subsequently be tested by comparing the new differential pressures with the original test record. This subsequent test may be in lieu of normal testing with a meter prover or other approved working standard. In establishing the original test record, the pressure differential shall be recorded at two or more load levels, with the minimum being no less than 10 percent of the rated capacity at the operating pressure of the meter. The meters shall be given a differential pressure test at least once every 5 years. When the test differential pressure differs from the original test record by more than 50 percent, the meter may not be used for measurement for revenue billing purposes until, by cleaning or repairing, the differential pressure is not more than 50 percent in excess of the original test record. If the differential pressure cannot be brought within the above limits by cleaning or repairing, the meter shall be removed from service and replaced with an accurate meter. The differential pressure test may not be used as a periodic test on rotary meters on which the results of a differential pressure test would not be conclusive, such as meters connected to loads which are less than 10 percent of the rated capacity of the meters. Pressure Correcting Devices. The test of a pressure correcting device shall consist of driving the mechanism or by direct comparison of device measured pressure while the pressure element is actuated. A dead weight tester or regulated air or gas pressure may be used to actuate the pressure element. If regulated air or gas pressure is used, a pressure gauge having an accuracy of ±0.25 percent of full scale shall be used to indicate the pressure on the element. The accuracy is calculated by comparing the correction factor applied by the correcting device with the correction factor that should be applied for the pressure at which the test was made. Temperature Correcting Devices. The test of a temperature correcting device shall consist of driving the mechanism or by direct comparison of device-measured temperature while the temperature sensor is immersed in a temperature bath containing a precision thermometer that has an accuracy of ±0.5°F. Specific, reasonably constant temperatures are applied to the temperature sensor. The temperatures used may be the operating (flowing gas) temperature, ambient temperature, and an ice bath (32°F). The device shall be tested at not less than 2 points, preferably with temperatures at least 20°F apart. The accuracy is calculated by comparing the correction factor applied by the correcting device with the correction factor that should be applied for the temperature at which the test was made. Timing Devices. The test of a timing device shall consist of precisely synchronizing the timing device and the working standard at the start of the test time interval. At the end of the test time interval the working standard is stopped and the reading recorded. The accuracy is calculated by comparing the actual time elapsed with the test time interval. Use of Tolerances. All tolerances are to be interpreted as maximum permissible variation from the condition of zero error. In making adjustments, no advantage of the prescribed tolerance limits may be taken to set meters fast. Reading and Recording Data. Maximum Readability. In any test or calibration, the devices or instruments used in the test or calibration shall be read to the maximum degree of readability. Degree of Accuracy. The degree of accuracy achieved in the calculations involved in determining the accuracy of a meter, prover, device, or instrument in any test or calibration shall be consistent with the purpose for which the resultant accuracy is to be used. Recording. The final accuracy or proof shall be recorded to the nearest 0.5 percent. Overall Accuracies. The overall accuracy or proof of a meter and an associated device, which affects the meter readings for billing purposes, may not be more than 0.5 percent fast or more than 1.5 percent slow. Diaphragm Type Meters. Diaphragm meters may not be placed or left in service unless found upon test to comply with the following: The meter may not be more than 0.5 percent fast nor more than 1.5 percent slow at check flow or at full rated flow. The proof at full rated flow may not differ from the proof at check flow by more than 1 percent. When air is used for testing meters, the rate of flow shall be adjusted to compensate for the difference in the specific gravity of air and the specific gravity of gas. Rotary Type Meters. Rotary type meters shall be tested at not less than 15 percent of full rated flow. A utility may not install a rotary meter which is more than 0.5 percent fast or more than 1.5 percent slow at the points of test. Turbine Type Meters. Turbine type meters shall be tested at not less than 15 percent of full rated flow. The meters may not be more than 0.5 percent fast or more than 1.5 percent slow at the points of test. Pressure Correcting Devices. Pressure correcting devices may not be more than 0.5 percent fast or more than 1.5 percent slow in the pressure range for which the instrument is intended to be used. Temperature Correcting Devices. Temperature correcting devices may not be more than 0.5 percent fast or more than 1.5 percent slow at the points at which they are tested. Timing Devices. Timing devices may not have an error more than 0.25 percent. Meter Condition. Before a meter may be installed for revenue billing purposes the utility shall inspect and test the meter, and adjust it if necessary, so that its proof is within the tolerances specified in Regulation .02. Sample Testing New Meters. New meters may be sample tested for proof in accordance with a utility's sample plan of testing acceptable to the Commission. Leak Test. The meter may not leak when subjected to pressure and checked for leaks by: Immersion; Soap test; or A pressure drop test of a type acceptable to the Commission. Tinned Steel Case Meters. Each meter shall be subjected to an internal pressure of at least 2 psig when testing for leaks. Iron or Aluminum Case Meters. Iron or aluminum case meters shall be tested at a pressure at least 50 percent above operating pressure. The meters may be sample tested in accordance with the plan described in §B. If one or more meters in the sample is found to leak, additional testing shall be done as described in §B. Commission Test. A representative of the Commission will check the condition of meters in the meter shop of the utility from time to time by testing random samples of meters ready for installation. Re-test. When any meter is inactive, whether installed in service or not, for a period of 2 years or longer, it shall be tested, and adjusted if necessary before being placed in service again. Request For Test. Upon request by a customer and at no charge, the utility shall make a test of the accuracy of registration of the meter serving the customer, provided that these tests need not be made more frequently than once in 18 months. Customer May Observe. The customer, or his representative, may be present when the meter is tested. Report to Customer. A report of the results of the test shall be made to the customer within a reasonable time after the completion of the test, and a record of the report, together with a complete record of the test, shall be kept on file at the office of the utility for at least 3 years. Application For Test. Upon written application to the Commission by a customer or a utility, a test will be made of the customer's meter as soon as practicable by a representative of the Commission, provided that these tests need not be made more frequently than once in 18 months. Deposit For Test. The application shall be accompanied by a deposit as indicated: Gas meter—$10. Notice to Utility. On receipt of the request from a customer, the Commission will notify the utility and the utility may not knowingly remove or adjust the meter until instructed by the Commission. The utility shall furnish to the Commission's representative such reasonable assistance as may be required to make the test. Customer May Observe. The customer, or his representative, may be present when the meter is tested. Report to Customer. A written report of the results of the test will be sent to the customer and to the utility. Disposition of Deposit. If the meter is found to over-register more than 2 percent, calculated in accordance with COMAR 20.55.04.05D and Regulation .02B(3) of this chapter, the deposit shall be refunded by the Commission and the utility billed the amount of the deposit. If the meter is found to be not more than 2 percent fast, the deposit will be retained and disposed of according to law. Meters or associated metering devices, or both, shall be tested before they are adjusted, repaired, or retired. Test Program. A utility in-service performance test program shall be designed to automatically adjust the number of meters required to be tested by a utility based solely on the performance of the utility's meters. In-service performance tests shall be made in accordance with the requirements of COMAR 20.55.02.02B. Location of Tests. In-service performance tests may be made on the customer's premises, in the utility's shop, or in an approved meter shop. Analysis of Meter Tests. By Commission. The Commission will review the annual reports of meter test results. By Utility. Each utility shall analyze its meter test results for the purpose of identifying the meter types which have poor accuracy characteristics. Public Utilities Article, §§2-121, 5-101, 7-301, and 7-302, Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .05A, B amended effective May 5, 1986 (13:9 Md. R. 1032) Chapter revised effective February 7, 2000 (27:2 Md. R. 146) All gas supplied to customers shall be substantially free of impurities which may cause corrosion of mains or piping or form corrosive or harmful fumes when burned in a properly designed and adjusted burner. The operating pressure on a low pressure distribution system shall be such that it will not cause unsafe operation of any connected and properly adjusted low pressure gas burning equipment. Pressure Measurements. Each utility shall make a sufficient number of pressure measurements using recording pressure gauges so that it will have a substantially accurate knowledge of the pressures provided to its customers. Pressure Records. Pressure records obtained in complying with this regulation shall be retained by the utility for at least 2 years and shall be available for inspection by the Commission's representatives. Notations on each record shall indicate the following: The location where the pressure check was made; and The time and date of the check. When the heating value of the gas distributed in the system is under the control of the utility, the following limits shall apply: Daily Btu. The average heating value on any one day may not exceed or fall below the total heating value (see COMAR 20.55.03.03B(2)) by more than 5 percent, except that the heating value may be increased by more than 5 percent during peak shaving or emergency operations in order to maintain the proper combustibility of the gas supplied to the customer. Monthly Average Btu. The monthly average heating value shall be not less than the total heating value filed in the utility's tariff. Calorimeter or Chromatograph. The utility shall provide, or designate, a calorimeter, chromatograph, or other device of a type acceptable to the Commission for the regular determination of the heating value of the gas sold. Installation. The equipment used to determine heating value shall be installed in a suitably located testing station acceptable to the Commission and subject to its inspection. Accuracy. The accuracy of all equipment used to determine heating value, as well as the method of making heating value tests, shall be acceptable to the Commission. Recording calorimeters or other equipment used to determine heating value shall be tested with a standard gas at least once each month. Records. Heating value test records shall be preserved for at least 3 years. LP-Air. The utility shall determine the heating value of LP-Air once each hour when LP-Air is being injected into the distribution system. Natural Gas and LPG. The utility shall determine the heating value of natural gas and undiluted LPG at least once each month, except that utilities selling gas subject to a thermal adjustment shall determine the heating value at least twice each day and shall make the tests during the period of the morning and afternoon peak demands. Endeavor to Avoid Interruptions. Each utility shall make reasonable efforts to avoid interruptions of service, but when interruptions occur, service shall be re-established within the shortest time practicable, consistent with safety. Notification to Commission. Each utility shall notify the Commission by telephone or telegraph of any interruption to the service of a major portion of its distribution system. Planned Interruptions. Planned interruptions shall be made at a time that will not cause unreasonable inconvenience to customers and shall be preceded by adequate notice to those who will be affected. Record of Interruptions. Each utility shall keep records of interruptions of service on its system and shall make an analysis of the records for the purpose of determining steps to be taken to prevent recurrence of interruptions. The records should include the following information concerning the interruptions: Cause; Date and time; and Duration. Public Utilities Article, §§2-121 and 5-101, Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .04A amended effective May 6, 1986 (13:9 Md. R. 1033) Regulation .05 amended effective February 7, 2000 (27:2 Md. R. 146) Exercise Reasonable Care. Each utility or gas master meter operator shall exercise reasonable care to reduce the hazards to which its employees, its customers, its contractors, and the general public may be subjected. Investigation by Commission. The utility or gas master meter operator shall give reasonable assistance to the Commission in the investigation of the cause of accidents and in the determination of suitable means of preventing accidents. Record of Accidents. Each utility or gas master meter operator shall maintain a summary of all reportable accidents arising from its operations or from contractor operations. Adopt Safety Program. Each utility, including its contractors, shall adopt and execute a safety program, fitted to the size and type of its operations. Use Suitable Tools and Equipment. Each utility or gas master meter operator may require its employees and contractors to use suitable tools and equipment in order that they may perform their work in a safe manner. Promote Safe Work Methods. Each utility or gas master meter operator may instruct its employees and contractors in safe methods of performing their work. Instruct In Artificial Respiration. Each utility should instruct its employees and contractors who, in the course of their work, are subject to the hazard of electric shock, asphyxiation, or drowning, in accepted methods of artificial respiration. Before permitting the use of gas at any location, the piping shall be tested for tightness and leaks in accordance with Part 4 of the American National Standard “National Fuel Gas Code”, ANSI Z223.1 (1988), which is incorporated by reference under COMAR 20.55.02.02. Pressure Test. Before any system of gas piping is finally put in service, it shall be tested for tightness and certified by the proper inspection authority that the test has been made. Leakage Test. Before turning gas into any piping, it shall be tested for leaks. Each utility or gas master meter operator shall respond promptly to all reports of gas leaks. The response shall include investigating the reports of gas leaks in accordance with COMAR 20.55.02.02B(1). Procedures and Methods. Each utility or gas master meter operator shall establish procedures for making periodic gas leakage surveys as specified in these regulations. For residential customers with meters located outdoors, leakage surveys shall be performed up to the building entry. The leakage surveys shall be conducted by one or more of the following methods: Flame ionization; Combustible gas indicator and bar hole; Optical methane detector; or Other method approved by the Commission. Frequency of Surveys. Leakage detection surveys shall be made at frequencies that comply with 49 CFR §§192.706 and 192.723, as amended, which are incorporated by reference, and the requirements of §B(2) and (3) of this regulation. Places of Public Assembly. Service lines to places of public assembly shall be leakage surveyed at least once each calendar year, but with intervals not exceeding 15 months. The customer shall cooperate with the company in the conduct of these tests as regards accessibility to meters and service lines. Cast iron, ductile iron, and cathodically unprotected steel pipelines shall be leak surveyed at least once every 3 years. Except as provided in §B(1) of this regulation, segments of these pipelines located inside a building shall be leak surveyed at least once every 5 years. Field Operations. After a leak repair, a leakage survey shall be performed in accordance with COMAR 20.55.02.02B(1). When a utility service person enters a customer's premises for the purpose of inspecting or servicing any gas equipment (excluding meter reading), a leakage survey shall be conducted at appropriate locations, including atmosphere samples, and at all utility service entrances. In multiple-occupancy buildings, an individual apartment or dwelling unit shall constitute the customer's premises specified above. The customer shall cooperate with the company in the conduct of the tests as regards accessibility to meters and service lines. Leakage surveys shall be conducted on each new or replaced service line before being placed in service but after backfilling and after a reasonable period of gas pressurizing. Leaks Without Presence of Odorant. A review system shall be established to continuously analyze and monitor the results of all leakage surveys specified in these regulations to determine any areas where leaks were detected without presence of odorant. Any areas so determined shall be leakage surveyed immediately to determine the possible extent of the area, and shall then be leakage surveyed at least annually as long as the condition of odorant absorption exists. Leak Repairs. Leaks located by leakage surveys shall be investigated promptly and corrective action initiated. Records of Surveys. Each utility or gas master meter operator shall maintain a record of each leak survey showing by location and date: Leaks detected; Severity of each leak; and Action taken to repair leaks. These records are to be kept as long as the segment of pipeline involved remains in service. Distinctive Odor Required. The odorant level throughout the entire company distribution system shall be sufficient so that gas is detectable at 1/10 of the lower explosive limit. Tests. A system to monitor the odorant level within the distribution system shall be installed and maintained to insure the requirements of §A of this regulation. Odorant Injection. On-site odorant injection or other recognized protection means shall be provided to prevent odor fading wherever necessary when new steel mains are installed, to insure the requirements of §A of this regulation. Burial. All pipelines shall be buried a minimum of 24 inches, or 18 inches in solid rock, where the term solid rock indicates the necessity for blasting or the use of pneumatic equipment. Exceptions. Burial depths less than that specified but not less than 12 inches will be allowed if underground obstructions preclude those depths, if special line protection as accepted by the Commission is provided. The above requirements shall be applicable to existing pipelines within a reasonable period of time upon discovery of burial depth 12 inches or less, or of burial depths less than specified and deemed to be hazardous. Identification. Tracer wire shall be installed with all plastic pipe. When the open trenching method of pipeline construction is used, suitable identification tape shall be installed at a minimum of 12 inches above the top of the pipe. Location of Residential Service Lines and Meters. Residential customer meters shall be placed as close to the exterior building wall as possible. Gas service may not be provided to new or renewed service lines if there is any underground pipeline after the meter, unless the pipeline carries gas only to gas utilization equipment located outdoors. If it is not possible to comply with §D(2) of this regulation, written permission shall be obtained from the Commission before placing the meter. If a residential service line is replaced, the new service line shall be installed as provided in §D(1)—(3) of this regulation. A utility or gas master meter operator may not increase the maximum allowable operating pressure of a pipeline until it has submitted to the Engineering Division a copy of the written procedure required by 49 CFR §192.553(c), as amended, which is incorporated by reference. State Government Article, §7-207(a); Public Utilities Article, §§2-113, 2-121, and 5-101; Annotated Code of Maryland Effective date: July 1, 1964 (Order No. 55567) Chapter revised effective October 21, 1974 (Order No. 60922) Regulation .01 amended effective January 15, 1996 (23:1 Md. R. 35) Regulation .02 amended effective February 7, 2000 (27:2 Md. R. 146) Regulation .02E adopted effective December 25, 1989 (16:25 Md. R. 2715) Regulation .03A amended effective December 25, 1989 (16:25 Md. R. 2715) Regulation .04 amended effective February 7, 2000 (27:2 Md. R. 146) Regulation .05A amended effective February 7, 2000 (27:2 Md. R. 146) Regulation .05A, F amended effective January 15, 1996 (23:1 Md. R. 35) Regulation. 05B amended effective October 23, 1975 (Order No. 61510); January 23, 1981 (8:2 Md. R. 117); April 10, 1995 (22:7 Md. R. 538); March 26, 2007 (34:6 Md. R. 629) Regulation .07C amended effective March 19, 1990 (17:5 Md. R. 639) Regulation .07D adopted effective April 10, 1995 (22:7 Md. R. 538) Regulation .07D amended effective December 29, 1997 (24:26 Md. R. 1760) Regulation .08 adopted effective December 29, 1997 (24:26 Md. R. 1760) Regulation .08 amended effective March 26, 2007 (34:6 Md. R. 629) This chapter applies to gas company approval requirements for gas pipeline engineering plans or specifications for engineering work or services on designed projects after January 1, 2022. This chapter does not apply to small system operators with less complex gas distribution systems as determined in the Guidance Manual for Operators of Small Natural Gas Systems (US Department of Transportation, Pipeline and Hazardous Materials Safety Administration, Office of Pipeline Safety, January 2017), which is incorporated by reference in Regulation .03 of this chapter, except for small system operators with multiple pressure distribution main pipeline systems. In this chapter, the following terms have the meanings indicated. Terms Defined. “Covered project” means natural gas infrastructure project work that is designed and must be approved and stamped by a professional engineer licensed in Maryland. “District regulator awareness zone” means a delineated area around a district regulator station which is reasonably expected to encompass all control lines or other appurtenances necessary for continued safe operation and control where additional precautions are required to control work within the identified zone to minimize the risk of damage to critical facilities. “Division” has the meaning stated in COMAR 20.57.01.02B. “Gas company” has the meaning stated in COMAR 20.57.01.02B. “Noncovered project” means natural gas infrastructure project work that is designed and must be approved by a relevant qualified person. “Relevant qualified person” means a person such as an licensed professional engineer, subject matter expert, or other employee who possesses the necessary knowledge, experience, and skills regarding natural gas distribution systems to review and certify construction plans for accuracy, completeness, and correctness. In this chapter, the following documents are incorporated by reference: Guidance Manual for Operators of Small Natural Gas Systems (US Department of Transportation, Pipeline and Hazardous Materials Safety Administration, Office of Pipeline Safety, January 2017); and 49 CFR Part 192, Transportation of Natural and Other Gas By Pipeline: Minimum Federal Safety Standards, as amended. Each gas company shall incorporate their work approval requirements for both covered and noncovered projects into their written operations and maintenance procedures under 49 CFR Part 192, Transportation of Natural and Other Gas By Pipeline: Minimum Federal Safety Standards, as amended, which is incorporated by reference in Regulation .03 of this chapter. Each gas company shall incorporate their training, initial qualification, and requalification requirements for a Relevant Qualified Person into their written operations and maintenance procedures under 49 CFR Part 192, Transportation of Natural and Other Gas By Pipeline: Minimum Federal Safety Standards, as amended, which is incorporated by reference in Regulation .03 of this chapter. Licensed professional engineers retained by a gas company shall have the necessary knowledge, experience, and skills regarding natural gas distribution systems to review and certify construction plans for accuracy, completeness, and correctness, but are not subject to §B of this regulation. The following types of designed natural gas infrastructure project work are designated as covered projects and require documented approval by a licensed professional engineer: New installation or modification that creates or alters the designed operating pressure of a district pressure regulator station or gate station. Installation of new or substantial reconfiguration of compressor stations. Installation, uprating, or abandonment of intrastate transmission lines. Any distribution main piping modifications or replacement work falling within the established district regulator awareness zones established by each operator. Any construction work on distribution mains which uprates the piping maximum allowable operating pressure. Installation of distribution mains, including replacements and extension projects, which attach to bridges or other engineered structures. Trenchless technology installations where the force used to pull the pipe and the path that the pipe follows while being pulled might result in damage to the pipe as a consequence of using that technology. Peak shaving facility installations and modifications or reconfigurations that would alter its pressure delivery characteristics. Any other designed natural gas infrastructure project work that presents a material risk of high consequence to public safety as determined by the gas company. All types of designed natural gas infrastructure project work not listed in §D of this regulation are designated as noncovered projects and require documented approval by a relevant qualified person. During emergencies, a relevant qualified person may approve a covered project, in which case documented licensed professional engineer approval shall be required as soon as practical after the emergency has been resolved. The Division may grant a waiver to the regulations in this chapter to a gas company for good cause. Public Utilities Article, §§2-113, 2-121, 5-101, 7-207(a), and 7-301, Annotated Code of Maryland Effective date: June 14, 2021 (48:12 Md. R. 474)