CHAPTER 59. GAS SERVICE
GENERAL PROVISIONS Sec.
59.1. Definitions.
SERVICE AND FACILITIES
59.11. Accidents.
59.12. Interruptions of service.
59.13. Complaints.
59.14. Changes in residential or commercial service.
59.15. Measurement of gas at higher than standard service pressure.
59.16. Use of meters.
59.17. Furnishing of meters and regulations.
59.18. Meter, regulator and service line location.
59.19. Testing facilities and records.
59.20. Meter-testing equipment.
59.21. Meter tests.
59.22. Adjustment of bills for meter error.
59.23. Disputed bills.
59.24. Access to meters and discontinuance of service.
59.25. Notice of desire to have service discontinued.
59.26. Refusal to serve applicants or customers.
59.27. Extension of facilities.
59.28. Installation.
59.29. Gas pressure requirements for low-pressure distribution systems.
59.30. Heating value and purity of gas.
59.31. Service from production or transmission lines.
59.32. Temporary service.
59.33. Safety.
59.34. Leakage surveys of customer-owned service lines.
59.35. Increasing pressure in distribution facilities and transmission facilities.
59.36. Abandonment of inactive service lines.
59.37. Maps, plans and records.
59.38. Filing of major construction reports.
ACCOUNTS AND RECORDS
59.41. Classification of gas public utilities.
59.42. Systems of accounts.
59.43. Accounting for merchandising, jobbing and contract work.
59.44. Retirement unit for gas plant.
59.45. Preservation of records.
59.46. Reclassification of gas plant accounts.
59.47. Continuing property records.
59.48. Filing of annual financial reports.
59.51. [Reserved].
REPORTING AND CURTAILMENT OF SERVICE
59.61. [Reserved].
59.62. [Reserved].
59.63. Natural gas emergency plans.
59.64. Notice of curtailment or nonperformance of supply.
59.65. Sales policies filed with the Commission.
59.66. [Reserved].
59.67. [Reserved].
GAS EMERGENCY PLANS
59.71. Definitions.
59.72. Natural gas emergency planning.
59.73. Emergency action.
59.74. Utility liability.
59.75. Penalties for unauthorized takes.
ANNUAL RESOURCE PLANNING REPORT
59.81. Periodic reporting requirements for major gas utilities.
59.82. Annual Conservation Report.
59.83. Evaluation methodology.
59.84. Formats.
STANDARDS FOR CHANGING A CUSTOMER’S
NATURAL GAS SUPPLIER
59.91. Definitions.
59.92. Customer contacts with the NGDC.
59.93. Customer contacts with NGSs.
59.94. Time frame requirement.
59.95. Persons authorized to act on behalf of a customer.
59.96. Valid written authorization.
59.97. Customer dispute procedures.
59.98. Provider of last resort.
59.99. Record maintenance.
UNACCOUNTED-FOR-GAS
59.111. Unaccounted-for-gas.Authority The provisions of this Chapter 59 issued under the Public Utility Code, 66 Pa.C.S. § 501, unless otherwise noted.
Source The provisions of this Chapter 59 adopted January 29, 1946; amended through December 20, 1971, unless otherwise noted.
Cross References This chapter is cited in 52 Pa. Code § 111.5 (relating to agent training); 52 Pa. Code § 111.9 (relating to door-to-door sales); and 52 Pa. Code § 111.10 (relating to telemarketing).
GENERAL PROVISIONS
§ 59.1. Definitions.
The following words and terms, when used in this chapter, have the following meanings, unless the context clearly indicates otherwise:
Class A meter—A diaphragm displacement meter having a rated capacity of not more than 500 cubic feet per hour at 1/2 inch water column differential pressure and operating at a gauge pressure of not more than 15 pounds per square inch and not greater than the maximum pressure rating of the meter expressed in pounds per square inch.
Class B meter—A diaphragm displacement meter having a rated capacity of more than 500 cubic feet but not more than 1,500 cubic feet per hour at 1/2 inch water column differential pressure and operating at a gauge pressure of not more than 15 pounds per square inch and not greater than the maximum pressure rating of the meter expressed in pounds per square inch.
Class C meter—A diaphragm displacement meter having a rate capacity of more than 1,500 cubic feet per hour at 1/2 inch water column differential pressure or a displacement meter operating on a gauge pressure of more than 15 pounds per square inch gauge, regardless of rated capacity.
Combined percentage of error—The sum of the percentage of errors of a meter and its associated instrument or auxiliary device.
Cubic foot of gas—According to purpose, as follows:(i) Testing. For the purpose of testing gas, that amount of gas which, if saturated with water vapor at a temperature of 60° F and subjected to an absolute pressure equal to 30 inches of mercury at 32° F (14.73 pounds per square inch), occupies a volume of one cubic foot.
(ii) Measurement of low pressure. For the purpose of measurement of gas to a customer taking gas at standard service pressure, that amount of gas which occupies a volume of 1 cubic foot at the time metered and under the conditions existing at the meter of the customer; except that where a temperature compensating device is built into the meter and the utility has received Commission approval for its use, the term means that quantity of gas which, at the pressure existing at the meter and the temperature corrected to 60° F, occupies one cubic foot.
(iii) Measurement of high or medium pressure. If gas is supplied to customers through orifice or other type meters at pressures above standard service pressure, that amount of gas which at an absolute pressure of 14.73 pounds per square inch occupies a volume of 1 cubic foot at the temperature base contracted for or established by the utility. Temperature correction, if made, shall be to 60° F.
Customer—A party supplied with gas service by a public utility.
Customer meter—A customer meter is the meter that measures the transfer of gas from an operator to a consumer.
Distribution line—A pipeline other than a gathering or transmission line.
Fast meter—A meter which upon test has an average error exceeding 2.0% fast.
Fast meter ratio—The ratio which the number of fast meters found upon test in a given year bears to the total number of meters tested in that year. Meters permanently retired from service shall be excluded from both the numerator and denominator of this ratio.
First immediately preceding year—The calendar year immediately preceding the testing year.
Gathering line—A pipeline that transports gas from a current production facility to a transmission line or main.
High pressure—The gas pressure, expressed in pounds per square inch gauge pressure (p.s.i.g.) in excess of 60 pounds.
Low pressure—Operating pressure, generally expressed in inches, which does not exceed 27.68 inches water column (one pound).
LNG—Liquefied natural gas—A natural gas or synthetic gas having methane (CH4) as its major constituent which has been changed to a liquid or semisolid.
LNG facility—A pipeline facility that is used for liquefying or solidifying natural gas or synthetic gas or transferring, storing or vaporizing liquefied natural gas.
Main—A distribution line that serves as a common source of supply for more than one service line.
Medium pressure—The gas pressure, expressed in pounds per square inch gauge pressure (p.s.i.g.) between one and 60 pounds, and normally reduced by one regulator.
P.S.I.G.—Pounds per square inch gauge.
Pipeline—All parts of those physical facilities through which gas moves in transportation, including pipe, valves and other appurtenance attached to pipe, compressor units, metering stations, regulator stations, delivery stations, holders and fabricated assemblies.
Pressure designations—‘‘Low pressure,’’ ‘‘medium pressure,’’ or ‘‘high pressure,’’ as defined in this section.
Public utility—Persons or corporations owning or operating in this Commonwealth equipment or facilities for producing, generating, transmitting, distributing, or furnishing gas for the production of light, heat, or power to or for the public for compensation. The term does not include a producer or manufacturer of gas not engaged in distributing the gas directly to the public for compensation.
Public utility service line—The pipe and appurtenances of the public utility which connect any main with either the point of connection of a service line of the customer if the line is provided by the customer in accordance with the rules and regulations of the public utility, or the meter of the public utility if the utility owns all the pipe and appurtenances between its main and meter.
SMYS—Specified minimum yield strength:(i) For steel pipe manufactured in accordance with a listed specification, the yield strength specified as a minimum in that specification.
(ii) For steel pipe manufactured in accordance with an unknown or unlisted specification, the yield strength determined in accordance with 49 CFR 192.107(b) (relating to yield strength).
Service line—A distribution line that transports gas from a common source of supply to a customer meter or the connection to a customer’s piping, whichever is further downstream, or the connection to a customer’s piping if there is no customer meter.
Slow meter—A meter which upon test has an average error exceeding 2.0% slow.
Slow meter ratio—The ratio which the number of slow meters found upon test in a given year bears to the total number of meters tested in that year. Meters permanently retired from service shall be excluded from both the numerator and denominator of this ratio.
Standard service pressure—The distribution pressure established by a public utility under the provisions of § 59.29 (relating to gas pressure requirements for low-pressure distribution systems).
Testing year—The calendar year for which a public utility seeks to apply an extended test schedule.
Test period—The maximum permitted time between the installation of a previously tested meter and the next test or between an in-place test and the next test.
Third immediately preceding year—The calendar year immediately preceding the second immediately preceding year.
Transmission line—A pipeline, other than a gathering line that does one of the following:(i) Transports gas from a gathering line or storage facility to a distribution center or storage facility.
(ii) Operates at a hoop stress of 20% or more of SMYS
(iii) Transports gas within a storage field.
Authority The provisions of this § 59.1 issued and amended under Public Utility Code,66 Pa.C.S. § § 501, 1301, 1304, 1501, 1502, 1504, 1507 and 1508.
Source The provisions of this § 59.1 amended through May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901; amended July 3, 1997, effective August 4, 1997, 27 Pa.B. 3215; amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial pages (232248) to (232251).
SERVICE AND FACILITIES
§ 59.11. Accidents.
(a) General. Each public utility shall submit a report of each reportable accident involving the facilities or operations of the public utility in this Commonwealth as provided in this section. The reports shall be addressed to the Secretary of the Commission.
(b) Reportable accidents. Reportable accidents are those involving utility facilities or operations which result in one or more of the following circumstances:
(1) The death of a person.
(2) Injury to a person sufficient that the injured person requires immediate treatment at a hospital emergency room or in-patient admittance to a hospital, or both.
(3) An event that involves a release of gas from a pipeline or of LNG or gas from an LNG facility, which results in estimated property damage, including the cost of gas lost of the operator or others, of at least $50,000 in market value.
(4) An event that results in an emergency shutdown of an LNG facility.
(5) An occurrence of an unusual nature that is a physical or cyber attack, including attempts against cyber security measures as defined in Chapter 101 (relating to public utility preparedness through self certification) which causes an interruption of service or over $50,000 in damages, or both.
(c) Exceptions. Injuries, as defined in subsection (b)(1) and (2), may not include those suffered as a result of a motor vehicle accident with utility facilities unless one or both of the following circumstances apply:
(1) A vehicle involved in the accident is owned by the utility or driven by a utility employee while on duty.
(2) Some or all of the injuries were as a result of contact with natural gas facilities transporting or storing natural gas or due to gas escaping from natural gas facilities.
(d) Telephone reports. A report by telephone shall be made immediately after the utility becomes aware of the occurrence of a reportable accident under subsection (b)(1), (3), (4) and (5). A report by telephone shall be made within 24 hours after the utility becomes aware of a reportable accident under subsection (b)(2).
(e) Written reports. A written report shall be made on Form UCTA-8 within 30 days of the occurrence of a reportable accident. For reportable accidents under subsection (b)(5), a utility may remove from Form UCTA-8 information that would compromise the security of the utility or hinder an active criminal investigation. Accidents reportable on forms required by the Bureau of Workers’ Compensation, Department of Labor and Industry, or the United States Department of Transportation, Pipeline and Hazardous Materials Safety Administration, may be reported to the Commission by filing a copy of the forms in lieu of a report on Form UCTA-8, as long as the alternative forms, at a minimum, provide the following information:
(1) The utility name.
(2) The date of the reportable accident.
(3) The date of the report.
(4) The location where the reportable accident occurred.
(5) The name, age, residence and occupation of the injured or deceased parties.
(6) The general description of the reportable accident.
(7) The name and telephone number of the reporting officer.
(f) Form availability. Blank UCTA-8 forms are available for download on the Commission’s web site.
(g) Reports not exclusive. The reporting under this chapter is not limited to the requirements in this section and does not limit requests for additional information.
Authority The provisions of this § 59.11 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 1501, 1504, 1507 and 1508.
Source The provisions of this § 59.11 amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050; amended January 6, 2012, effective January 7, 2012, 42 Pa.B. 9. Immediately preceding text appears at serial pages (246407) to (246408).
§ 59.12. Interruptions of service.
(a) Records. Each public utility shall keep a record which shall include data showing the time, duration and cause of each interruption of service affecting its entire system or a major division of its system.
(b) Notification to customers. Each customer who may be affected shall be notified prior to starting work which will result in an interruption of his service.
§ 59.13. Complaints.
(a) Investigations. Each public utility shall make a full and prompt investigation of complaints made to it or through the Commission by its customers.
(b) Records of complaints. Each public utility shall preserve written or recorded service complaints showing the name and address of the complainant, the date and character of the complaint, and the adjustment or disposal made of the complaint. Records required by this chapter shall be kept within this Commonwealth at an office or offices of the utility located in the territory served by it, and shall be open for examination by the Commission or its staff.
§ 59.14. Changes in residential or commercial service.
If any substantial change is made by a public utility in gas composition, gas pressure or other service conditions which would affect efficiency of operation or require adjustment of the appliances of residential or commercial customers in the area affected, the appliances shall be inspected and, if necessary, adjusted, without charge by the utility, to meet the new conditions.
§ 59.15. Measurement of gas at higher than standard service pressure.
(a) Pressure-recording equipment. If gas is measured to customers through displacement meters at a pressure greater than standard service pressure, the meters shall be equipped with reliable pressure-volume recording gauges or other devices for accurately determining the quantity of gas which has passed through the meter in accordance with contract or tariff provisions.
(b) Determination of multiplier. In computing the volume of gas at a given pressure base from a pressure-volume chart, the multiplier shall be obtained by the weighted average method, which consists of determining the average pressure for each indicated unit volume on the chart.
(c) Fixed pressure factor measurement. If the gas metering pressure can be maintained at a constant level so that it will not vary by more than plus or minus 1.0% of the absolute metering pressure, the quantity of gas corrected for pressure for billing purposes may be determined by multiplying the uncorrected volume by the factor of Metering Pressure Plus Atmospheric Pressure Divided by Base Pressure or by a special index with gearing to perform this calculation. The special index shall meet the specifications of ANSI Standard B109.1, § 6.2 (1986) or ANSI Standard B109.1, § 6.9 (1986). The ability of the regulator to maintain the constant pressure shall be verified at or prior to installation. Verification will be established by the use of a verified pressure-indicating gauge (accuracy: ANSI B40.1 Grade 3A), or a pressure-recording gauge, at both high and low flow conditions. When customer load is measured with a meter with a rated capacity of 1,500 cubic feet per hour or less, with metering pressure less than 3 psig, the performance of the regulator shall be verified in accordance with the test schedule of the downstream meter, established under § 59.21 (relating to meter tests). When customer load is measured with a meter with a capacity of over 1,500 cubic feet per hour or metering pressure of 3 psig or more, the performance of the regulator shall be verified at least every 5 years, except that those installed before January 1, 1990, shall be verified at least every 2 years.
(d) Determination of static and differential pressure. In computing the volume of gas at a given pressure base from an orifice meter chart, the average static pressure and the average differential pressure shall be determined for periods not exceeding 1 hour. If pressure variations are extreme during the hour, the average shall be determined for 15-minute intervals.
(e) Mechanical devices. Mechanical devices may be substituted for the method of computing orifice meter charts set forth in this section.
Authority The provisions of this § 59.15 issued and amended under Public Utility Code,66 Pa.C.S. § § 501, 1301, 1304, 1501, 1502, 1504, 1507 and 1508.
Source The provisions of this § 59.15 amended through September 17, 1982, effective September 18, 1982, 12 Pa.B. 3291; amended December 20, 1991, effective January 21, 1992, 21 Pa.B. 5817; amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial pages (232252) to (232253).
§ 59.16. Use of meters.
(a) Gas sold. Gas sold by a public utility shall be charged for by meter measurement, except in case of emergency, flat-rate street lighting, or if otherwise authorized by the Commission.
(b) Other gas. Other gas, either used by a public utility or furnished to others, shall be metered and a record of the meter measurement made, unless otherwise authorized by the Commission.
§ 59.17. Furnishing of meters and regulations.
(a) Installation. Except as provided in § 59.31 (relating to service from production or transmission lines), a public utility shall provide and install at its own expense and shall continue to own, maintain and operate equipment necessary for the regulation and measurement of gas furnished to its customers. If meters or regulators not required by this section are furnished by the utility for the convenience of the customer, a reasonable charge for the meters or regulators may be made. Nothing in this subsection may be construed to require the utility to install regulating equipment on any gas piping system of a customer beyond the point of delivery at the meter outlet of the utility.
(b) Excess pressure protection. If gas is supplied from a high or medium pressure distribution system and the pressure is reduced to standard service pressure for use by the customer, the installation shall be provided with adequate over-pressure protection to prevent the pressure from exceeding 2 pounds per square inch in installations made on or before May 1, 1986, and the safe operating pressure for connected and properly adjusted gas utilization equipment in installations made after that date, in the event of a pressure regulator of failure.
Source The provisions of this § 59.17 amended May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901. Immediately preceding text appears at serial page (73203).
§ 59.18. Meter, regulator and service line location.
(a) General requirements for meter and regulator location.
(1) Unless otherwise allowed or required in this section, meters and regulators must be located outside and aboveground.
(2) Except in the case of an emergency, a utility shall provide written notice to a utility customer by first class mail or by personal delivery at least 30 days prior to relocating and subsequently installing a meter or regulator outside the customer’s building. The notice must request that if the customer is not the owner of the building, the customer shall forward the written notice to the owner of the building. If the utility knows the current address of the owner of the building, notice shall also be mailed or delivered to that address.
(3) The written notice must inform the customer and building owner of the equipment that the utility proposes to relocate, the planned new location and how to contact the utility to provide supplemental information that the utility may not have, such as the building’s historic status. The written notice must include contact information for the Commission’s Bureau of Consumer Services.
(4) When necessary to install meters at multiple locations on a premises, a utility shall provide a tag or other means to indicate there are multiple meter locations.
(5) When selecting a meter or service regulator location, a utility shall consider potential damage by outside forces.
(6) The meter location must accommodate access for meter reading, inspection, repairs, testing, changing and operation of the gas shut-off valve.
(7) When feasible and practical to do so, the meter location must accommodate the installation of the service line in a straight line perpendicular to the main.
(8) Meters and service regulators may not be installed in the following locations:
(i) Beneath or in front of windows or other building openings that may directly obstruct emergency fire exits.
(ii) Under interior stairways.
(iii) Under exterior stairways, unless an alternate means of egress exists and the meter and service regulator are installed in a well-vented location under stairs constructed of noncombustible material.
(iv) A crawl space.
(v) Near building air intakes under local or State building codes.
(vi) In contact with soil or other potentially corrosive materials.
(9) Unless caused by a customer’s or building owner’s violation of applicable gas safety or tariff rules, a utility shall pay the costs of relocating a meter or regulator when the relocation is performed to meet utility or Commission safety requirements.
(10) Unless caused by a customer’s or building owner’s violation of applicable gas safety or tariff rules, a utility shall pay the cost of extending customer-owned facilities to the new meter or regulator location when the relocation is performed to meet utility or Commission safety requirements.
(11) A customer or building owner requesting that a meter or regulator be moved shall pay the costs associated with relocation when the meter and regulator are currently situated in a suitable location under State and Federal regulations.
(12) Utilities shall address meter, regulator and service line location regulations in their tariffs.
(b) Outside meter or service regulator locations. Outside meters or service regulators shall be installed in one of the following locations:
(1) When feasible and practical to do so, aboveground in a protected location adjacent to the building served, or as close as possible to the point where a production or transmission line is tapped.
(2) In a buried vault or meter box.
(i) The vault or meter box must be located on a customer’s or building owner’s property, either adjacent to the building served or near the gas main.
(ii) Vaults may be located in a public right-of-way, subject to the consent of local jurisdictions as may be required.
(c) General requirements for vaults or meter boxes.
(1) A utility shall consider proper design and location criteria for a meter box, including:
(i) Ventilation.
(ii) Vehicular traffic.
(iii) Soil accumulation.
(iv) Surface water runoff.
(v) High water table.
(vi) Proximity to building air intakes or openings.
(vii) Proximity to an excessive heat source as defined in 49 CFR 192.353(c) (relating to customer meters and regulators: location).
(2) Piping installed through vault walls shall be properly coated to protect from corrosion.
(3) Vaults containing gas piping may not be connected by means of a drain connection to any other underground structure.
(4) When a meter box is located outside a paved surface, a utility shall consider fill, topsoil or sod being placed over the vault and, when feasible and practical to do so, choose an alternate location.
(d) Inside meter locations.
(1) Inside meter locations shall be considered only when:
(i) The service line pressure is less than 10 psig.
(ii) A meter is located in a building that meets one of the following criteria:
(A) A building is listed in the National Register of Historic Places or the customer or building owner notifies the utility that the building is eligible to be listed in the National Register of Historic Places and the eligibility can be readily confirmed by the utility.
(B) A building is located within a historic district that is listed in the National Register of Historic Places or the customer or building owner notifies the utility that the historic district is eligible to be listed in the National Register of Historic Places and the eligibility can be readily confirmed by the utility.
(C) A building has been designated as historic under the act of June 13, 1961 (P. L. 282, No. 167) (53 P. S. § § 8001—8006), known as the Pennsylvania Historic District Act, the Pennsylvania Municipalities Planning Code (53 P. S. § § 10101—11202) or a municipal home rule charter.
(D) A building is located within a locally designated historic district or is eligible for the listing, or a building is individually designated under a local ordinance as a historic landmark or is eligible for the listing.
(iii) Protection from ambient temperatures is necessary to avoid meter freeze-ups.
(iv) A utility determines that a meter is subject to a high risk of vandalism based on the utility’s prior experience.
(v) A utility determines that an outside meter location is neither feasible nor practical.
(2) Except for low pressure systems with service line pressure less than 10 psig, regulators must be located outside when a meter is located inside.
(3) Installed inside meters must be attached to an operable outside shut off valve.
(4) Meters installed within a building must be located in a ventilated place not less than 3 feet (914 millimeters) from a source of ignition or source of heat which may damage the meter.
(e) Other meter or service regulator locations. A utility may consider a specially constructed cabinet recessed in the building wall, sealed from inside the building and vented to and accessible from outside the building.
(f) General requirements for new service lines. When feasible and practical to do so:
(1) A building may not have more than one service line.
(2) A service line must terminate at the inlet valve of the meter set in the building in which the service line enters.
(3) The service line must be installed in a straight line perpendicular to the main.
(g) Application of regulation.
(1) Beginning September 13, 2014, utilities shall comply with this section for new meter, regulator and service line installations in new locations.
(2) Beginning September 13, 2014, utilities shall comply with this section when replacing existing meters, regulators and service line facilities.
(3) By September 13, 2034, utilities shall complete replacement of existing facilities in compliance with this section or incorporate the requirements of this section in a distribution integrity management plan, whichever occurs first.
Authority The provisions of this § 59.18 amended under the Public Utility Code, 66 Pa.C.S. § 501.
Source The provisions of this § 59.18 amended September 12, 2014, effective September 13, 2014, 44 Pa.B. 5835. Immediately preceding text appears at serial page (246410).
Notes of Decisions Authorizing natural gas distribution company (NGDC) to decide location of natural gas meter in historic buildings under 52 Pa. Code § 59.18 without providing ‘‘basic policy choices and adequate standards’’ by which the NGDC must determine location of gas meter violated Pennsylvania Constitution’s prohibition against improper delegation of authority. City of Lancaster v. Public Utility Comm’n, 284 A.3d 522, 533 (Pa. Cmwlth. 2022).
§ 59.19. Testing facilities and records.
(a) Testing facilities. Each public utility shall provide and keep available the laboratory meter-testing equipment and auxiliary appliances as may be necessary to make tests required by the Commission. The apparatus and equipment so provided shall be of standard type, and measuring devices shall be accurate within normal laboratory limits and shall be available at all times for the inspection or use of the Commission staff.
(b) Tests and records. Each public utility shall, as a minimum requirement, make tests as prescribed in this chapter with the frequency, in the manner, and at the places as provided in this chapter or as may be approved or ordered by the Commission, and shall keep records of the tests.
§ 59.20. Meter-testing equipment.
(a) General testing equipment. Each public utility furnishing metered gas service shall own and maintain the equipment and facilities necessary for accurately testing the various types and sizes of meters used by such utility for the measurement of gas, unless arrangements are made to have the testing done in a shop or laboratory containing equipment and operated in a manner acceptable to the Commission. The accuracy of provers and method of operation will be checked periodically by the Commission. Alterations, accidents, or repairs to stationary meter-proving equipment, which might affect the accuracy of the equipment or the method of operating it, shall be promptly reported in writing to the Commission. The accuracy of testing instruments and equipment used as utility standards, such as dead-weight testers and precision type pressure gauges, which are used in the testing or calibration of meters or associated metering equipment will be checked periodically by the Commission.
(b) Equipment for testing small capacity meters. Each public utility shall own and maintain, except as provided in subsection (a), one meter prover of approved type and of a capacity adequate for the testing of small capacity meters. Each meter prover shall be supplied with accessories needed for accurate meter testing, be located in a room suitable for meter testing, and be protected from drafts and excessive changes of temperature. If the proving system includes automatic testing equipment or any mechanical devices to provide ‘‘read-out’’ capability—the entire meter proving system, including the basic prover, shall be maintained in good condition and correct adjustment so that it will be capable of determining the accuracy of any service meter to within 0.5%.
(c) Equipment for testing large capacity meters. Each public utility furnishing metered-gas service through orifice, turbine, or large displacement meters—except as provided in subsection (a)—shall have available and maintain in proper adjustment test equipment suitable for determining the accuracy of any orifice or large displacement meter used by the utility to within 0.5%. If the public utility uses a transfer prover standard for testing large capacity meters, the accuracy of the transfer prover and the method of operating will be checked periodically by the Commission in conjunction with all prover tests.
Authority The provisions of this § 59.20 issued under Public Utility Code,66 Pa.C.S. § § 501, 1301, 1304, 1501, 1502 and 1507.
Source The provisions of this § 59.20 amended through September 17, 1982, effective September 18, 1982, 12 Pa.B. 3291. Immediately preceding text appears at serial page (20967).
§ 59.21. Meter tests.
(a) Test schedule for other than Class A, B and C meters. Each public utility shall make and record tests of orifice, rotary displacement and turbine type service meters as follows:
(1) Orifice meters shall have their differential and static recording gauges tested at least once every 2 months, the diameter and condition of the orifice plate checked at least once every year, and the specific gravity of the gas determined at least once every 6 months; however, where previous or subsequent test records show that the specific gravity has not varied by an amount which would make an error in the measurement greater than is consistent with accepted engineering practice, the specific gravity of the gas may be determined at longer intervals not to exceed 1 year.
(2) Rotary displacement meters shall be tested and calibrated at the factory in accordance with recognized and accepted practices and shall be correct to within 1.0% when passing gas at their rated capacities. A record of the test shall be made available to and retained by the utility for the life of the meter. At least once every 10 years’ a differential-rate test shall be made and the results checked against the original test recorded at the time of installation. At least every 5 years’ the meter shall be inspected to observe the condition of the meter bearings noise, vibration, and the like, and the level and condition of the oil in the reservoirs, except that those meters installed before January 1, 1990, shall be inspected every 2 years. An observed problem shall be promptly corrected. A record of the results of these 5 year tests or 2 year tests for the pre 1990 installed meters shall be maintained by the utility for 5 years. In lieu of a differential-rate test, a test method approved by the Commission may be used.
(3) Turbine meters shall be tested and calibrated at the factory in accordance with recognized and accepted practices and shall be correct to within 1.0% when passing gas at their rated capacities. A record of the test shall be made available to and retained by the utility for the life of the meter. At least once every 2 years, a spin test shall be made and the results checked against the minimum spin test time specified by the manufacturer for the size meter being tested. If the spin time is not up to standard value, corrective measures shall be taken. In lieu of a spin test, a test method approved by the Commission may be used.
(b) Standard test schedule for Class A, Class B and Class C Meters. Unless otherwise provided by this section, each public utility shall make and record tests of Class A, Class B and Class C meters on the following schedule:
Test Period Class (Years) A 8 B 5 C 2 (c) Extended test schedule for Class A, Class B or Class C meters. A public utility may depart from the requirements of subsection (b) for Class A, Class B or Class C meters in a testing year, and instead make and record tests using one of the test periods prescribed in paragraph (5), if the following requirements are met:
(1) At the end of the first immediately preceding year, not less than 98% of the meters of that class in service had been removed within whichever is the greater of 2 years plus the test period prescribed therefor in subsection (b), or the test year permitted for that class of meter for that year by paragraph (5); and, as to a meter of that class not so removed, the premises where it was located were visited and a written notice requesting an appointment for meter change was either left at the premises or posted to the mailing address of the customer as it appears in the public utility’s files. Meters removed under this paragraph shall be tested and included in the calculations under paragraph (2) unless a meter was permanently retired from service or damaged by factors other than normal age or wear such as tampering or damage beyond the control of the public utility.
(2) The slow meter ratios and fast meter ratios of the meter class for the second immediately preceding year and the third immediately preceding year fall below the maximum percentages prescribed in paragraph (5). Any conflict between the test periods prescribed in paragraph (5) shall be resolved by using the shortest applicable test period.
(3) On or before March 1 of each testing year, the public utility submits to the Commission a report showing both in absolute numbers and in percentages the facts prescribed in paragraphs (1) and (2).
(4) For each year in which a public utility uses the extended test schedule in this subsection, the public utility may not remove or test any meters of the same class using the statistical sampling program in subsection (d) or the variable interval program in subsection (e).
(5) Subject to the qualifications prescribed in paragraphs (1)—(4), a public utility may make and record tests of Class A, Class B or Class C meters on the following schedule:
Test Results from Test Results from Testing Second Immediately Third Immediately Year’s Preceding Year Preceding Permitted Year Test Period
(Years)CLASS A METERS Slow Meter Fast Meter Slow Meter Fast Meter Ratio Ratio Ratio Ratio Less Less Less Less Than (%) Than (%) Than (%) Than (%) 10 10 12 12 14 8 8 10 10 16 6 6 8 8 18 4 4 6 6 20 CLASS B METERS Slow Fast Slow Fast Meter Meter Meter Meter Ratio Ratio Ratio Ratio Less Less Less Less Than (%) Than (%) Than (%) Than (%) 10 10 12 12 6 8 8 10 10 7 6 6 8 8 8 4 4 6 6 10 CLASS C METERS Slow Fast Slow Fast Meter Meter Meter Meter Ratio Ratio Ratio Ratio Less Less Less Less Than (%) Than (%) Than (%) Than (%) 8 8 10 10 3 6 6 8 8 4 4 4 6 6 5 (d) Statistical sampling for Class A, Class B or Class C meters. A public utility may depart from the requirements of subsection (b) for Class A, Class B or Class C meters, and instead make and record tests of Class A, Class B or Class C meters under a statistical sampling program, if the following requirements are met:
(1) Meters shall be divided into groups in accordance with ANSI Spec, B109.1 Part IV Sec. 4.3.2.1 or its successor. A detailed description of the composition of each group of meters, such as year set, manufacturer, case type and diaphragm material, shall be provided in the annual report to the Commission.
(2) Sufficient meters shall be tested annually to insure a 90% confidence level that the meter groups are performing within accuracy limits.
(3) For a group to remain in service, at least 80% of the meters in the sample test shall meet the accuracy limits of 98% average accuracy (2% slow) and 102% average accuracy (2% fast). If a group of meters does not meet the performance standards, corrective action shall be taken. The corrective action may consist of removing the entire group from service within 4 years or, if the group consists of one or more subgroups, implementing a selective meter removal program to improve the accuracy of the group to within acceptable limits. The selective removal program may be as follows:
(i) If test results indicate one or more subgroups do not meet the performance standards, the subgroup shall be identified and removed within 4 years.
(ii) Once identified as a group or subgroup not meeting the performance standards and during the removal process, that group or subgroup shall be removed from the sampling plan.
(4) The statistical sampling schedule shall be in accordance with the provisions of ANSI Spec. B109.1 Part IV Sec. 4.3.2.1 or its successor.
(5) A utility electing the statistical sampling program shall remain on that program for at least 4 years.
(6) For each year in which a public utility uses the statistical sampling approach in this subsection, the public utility may not remove or test any meters of the same class using the extended test schedules in subsection (c) or the variable interval program in subsection (e).
(e) Variable interval testing for Class A, Class B or Class C meters. A public utility may depart from the requirements of subsection (b) for Class A, Class B or Class C meters, and instead make and record tests of the Class A, Class B or Class C meters under a variable interval program, if the following requirements are met:
(1) Meters shall be divided into groups in accordance with ANSI B109.1 Part IV Sec. 4.3.2.2 or its successor. A detailed description of the composition of each group of meters, such as year set, manufacturer, case type and diaphragm material, shall be provided in the annual report to the Commission.
(2) The number of meters to be removed in any year will be determined from the test results of the second immediately preceding year’s incoming meters. Meters removed under this paragraph shall be tested and included in the calculations under paragraph (3) unless a meter was damaged by factors other than normal age or wear such as tampering or damage beyond the control of the utility.
(3) Except as provided in paragraphs (4) and (5), the ratio (r) of the number of meters in a test group to be removed to those in service in that test group shall be determined by the formula (r = .02 + .3d) where (d) is the ratio of meters which have an average accuracy of less than 98% or more than 102% as reported to the nearest 1/2%, to the total number of meters tested in the group during the second immediately preceding year.
(4) Meters removed in a test group in excess of the ratio (r) as described in paragraph (3) shall be credited towards the ratio (r) for a better performing test group.
(5) A utility may petition the Commission for an Accelerated Retirement Program (ARP) for a specific meter type that the utility may desire to purge from its system. Meters removed in an ARP in excess of the ratio (r) as described in paragraph (3) may be credited towards the ratio (r) for any other test group regardless of performance.
(6) A utility electing the variable interval plan shall remain on that plan for at least 4 years.
(7) For each year in which a public utility uses the variable interval approach in this subsection, the public utility may not remove or test any meters of the same class using the extended test schedules in subsection (c) or the statistical sampling program in subsection (d).
(f) Meter test on request of customer. Meter tests, if requested by a customer, shall conform with all of the following:
(1) If a customer requests, in writing, a test of the accuracy of the meter through which gas service is supplied and the meter is not due for periodic test, the public utility shall notify the customer of the conditions under which the test will be made by the utility or by a referee. If the customer then requests the utility to proceed with the test and remits an amount equal to the scheduled cost of a referee test, the utility shall make the test promptly. If, when tested, the meter is found to be more than 2.0% fast or slow, the testing fee shall be promptly refunded to the customer.
(2) A customer or his representative may be present when the public utility conducts the test on the meter.
(3) A report giving the name of the customer requesting the test, the date of the request, the location of the premises where the meter had been installed, the type, make, size, and serial number of the meter, the date of removal, the date of the test, the result of the test and the amount of refund if the meter was found more than 2.0% fast, shall be supplied to the customer within 10 days after the completion of the test.
(4) The amount of the fee which may be charged by the public utility for testing meters upon the written request of a customer shall be determined by the designated rating of the manufacturer as follows. Displacement meters shall be subject to the following fee schedule:
(i) Meters having a rated capacity of 500 cubic feet per hour or less—$10.
(ii) Meters having a rated capacity of over 500 cubic feet per hour, and not more than 1,500 cubic feet per hour—$20.
(iii) Meters having a rated capacity of over 1,500 cubic feet per hour, orifice meters, and any meters not a displacement type—$30.
(5) The provisions of this section may not interfere with the practice of a public utility with reference to its regular tests of meters; except that, in the event of an application by a customer to the Commission for a referee test, the utility may not knowingly remove, interfere with or adjust the meter to be tested without the written consent of the customer and approval of the Commission.
(g) Installation test. Each gas meter shall be in good order and shall be correct at all test rates of flow to within 2.0% fast or slow before being installed. In the case of new meters or meters reconditioned by a manufacturer, the test results of the manufacturer can be accepted as the installation test if the utility has verified the manufacturer’s reported test results by testing a minimum of 10% or ten meters—whichever is greater—of each shipment of meters. However, in case of an emergency, a meter not meeting the requirements of this section may be installed temporarily. Each meter tested by the utility under this subsection shall also be tested for pressure as follows: every meter shall be subjected to a pressure test before being installed; the minimum test pressure shall be 1.5 times the maximum metering pressure that the meter will be exposed to during its time in service.
(h) Determining accuracy of small meters. For the purpose of determining compliance with subsection (e), the registration of a displacement meter shall be determined by one test at a rate of flow of approximately 1/5 of its rated capacity (check flow) and by a second test at approximately the full rated capacity of the meter. The capacity of the meter for test purposes shall be the capacity at 1/2 inch differential pressure. Prior to installation of a meter, the tests at the two rates of flow shall agree within 2.0%. In determining compliance and for the purpose of computing refunds, the check flow test may be considered as the accuracy of the meter. A utility may, at its option applicable to all of its small meters, consider the accuracy of a meter to be the algebraic mean of two errors found, one at check flow and one at capacity flow. If unusual conditions indicate that an unusual test rate of flow should be used, the test record shall show the rate used.
(i) Meter prover. Tests to determine the accuracy of a gas service meter used to measure gas at standard distribution pressure shall be made with a bell type meter prover unless, because of unusual capacity or construction of a meter, the method of test is considered impracticable, under which condition the test shall be made by some other method approved by the Commission.
(j) Testing large displacement meters. The testing of large displacement meters shall conform with the following:
(1) Tests on displacement meters shall be made with approved testing apparatus. The meters should be tested in their permanent locations on the premises of the customer if practicable. If critical flow provers or low pressure flow provers are used for making such tests, the accuracy should be determined at three or more rates of flow, ranging from 20% of the rated capacity at 1/2 inch differential pressure up to flow at the maximum operating rate.
(2) If testing with the critical flow prover, the meter shall be operated at a static pressure which approximates the average operating static pressure. If similar tests are made with a low pressure flow prover, average operating pressure should be maintained on the meter under test and the prover operated at a range of low pressures required for a prover. In installations where meters operating on pressures higher than standard service pressure are limited in their maximum operating dial rate so as to keep the differential pressure equal to or less than 2 inches water column, low pressure flow prover tests may be run with low pressure on the meter. In the flow tests by either method, the maximum dial rate shall insure that tests being run at meter differential pressures are equivalent to normal operating meter differential pressures in all cases. If it is not practicable to test rotary displacement meters with a flow prover, they shall be inspected and tested by approved methods to determine whether they conform reasonably to the original factory test data.
(3) An instrument or auxiliary device used in conjunction with a gas meter to correct the metered volume for pressure or temperature shall be adjusted to an accuracy level to assure that the combined percentage of error of the instrument or auxiliary device, or both, and the associated meter does not exceed plus or minus 2.0% error. This shall be verified by test prior to installation and at the time of any subsequent meter tests. In tests conducted after installation the meter and its associated auxiliary device may not be tested more than 30 days apart. Each instrument and auxiliary device shall be verified for accuracy or calibrated at least annually to verify the performance. A record of the most recent verifications shall be kept for each instrument and device.
(k) Testing orifice meters. Tests on orifice meters shall be made with approved testing apparatus and in their permanent locations on the premises of the customer. The accuracy of the differential pressure registration shall be determined on a rising and falling pressure throughout the entire operating pressure range of the gauge. The accuracy of the static pressure registration shall be determined at the operating pressure.
(l) Determining accuracy of orifice and large displacement meters. In determining the accuracy of orifice and large displacement meters, the average of the errors determined at the various rates of flow at which the meter was tested shall be taken and shall be considered as its accuracy in determining compliance with subsection (e) and for the purpose of computing refunds; however, if the rates of flow at which the meter has been registering in service may be definitely established, the weighted average error shall be determined and used.
(m) Test record data. Whenever a meter is tested, the original test record shall include information necessary for identifying the meter, the reason for making the test, the date and location of the test, the name of the person making the test, the reading of the meter upon removal from service, the result of the test, and data taken at the time of the test. The record shall be in complete form so as to permit the convenient checking of the methods employed and the calculations made.
(n) Meter records. A record shall be maintained for each meter owned or used by a public utility. It shall indicate whether acquired new or otherwise, the date of purchase, identification, and the results of the most recent test and shall contain any additional test records required to be kept by other provisions of this title relating to gas meters. This record may not be destroyed without Commission authorization.
(o) Capping meters. Incoming meters shall be capped when removed from service and awaiting test. Meters which have been tested or are reading for installation shall be capped and remain capped until installed.
Authority The provisions of this § 59.21 issued and amended under Public Utility Code,66 Pa.C.S. § § 501, 1301, 1304, 1501, 1502, 1504, 1507 and 1508.
Source The provisions of this § 59.21 amended through May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901; amended July 3, 1997, effective August 4, 1997, 27 Pa.B. 3215; amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial pages (232255) to (232263).
Cross References This section cited in 52 Pa. Code § 59.15 (relating to measurement of gas at higher than standard service pressure); and 52 Pa. Code § 59.22 (relating to adjustment of bills for meter error).
§ 59.22. Adjustment of bills for meter error.
(a) Fast meters. If, upon test of a meter, it is found to have an average error of more than 2.0% fast, the public utility shall refund to or credit the customer for the overcharge, based upon what the meter would have registered had it not been fast or slow for a period equal to 1/2 the time elapsed since the last previous test, but not to exceed 12 months or 1/2 the period of occupancy of the premises by the customer, whichever is less. If the period of registration error may be definitely fixed, the overcharge shall be computed for the period. If the meter has not been tested under § 59.21 (relating to meter tests), the period for which it has been in service beyond the regular test period shall be included in computing the refund.
(b) Slow meters. If, upon test of a gas meter it is found to have an average error of more than 2.0% slow, the public utility may render a bill for the gas consumed but not covered by bills previously rendered, for a period equal to 1/2 of the time elapsed since the last previous test, but not to exceed 3 months. If the period of registration error may be definitely fixed, the charge may be computed for the period.
(c) Nonregistering meters. If a meter has failed to register for a period, the public utility may compute the gas used by taking the average of the gas used for the nearest meter-reading period preceding and the meter-reading period immediately following the date when the meter was found to be not registering, which amount shall be assumed to be the amount of gas used by the customer during the billing period in which the meter was found not to have registered. Exceptions will be made only if the facts clearly show that the stated method does not give the correct consumption for the period.
Source The provisions of this § 59.22 amended May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901. Immediately preceding text appears at serial pages (73210) to (73211).
§ 59.23. Disputed bills.
In the event of a dispute between a customer and a public utility respecting a bill, the utility shall immediately make the investigation required by the particular case and report the result of the investigation to the customer.
§ 59.24. Access to meters and discontinuance of service.
(a) Access to meters. Each public utility shall at reasonable times have access to meters, service connections and other property owned by it on the premises of customers, for purposes of maintenance, operation and meter reading. Neglect or refusal on the part of customers to provide reasonable access to their premises for the purposes shall constitute sufficient cause for discontinuance of service.
(b) Notice of discontinuance. No public utility shall discontinue service to a customer for violation of its rules and regulations or for nonpayment of bills without a diligent attempt to induce the customer to comply with the rules and regulations, or to pay the bills when due. Service may not be discontinued until after at least 24-hour written notice has been given by the utility that bills are 5 or more days delinquent, or that the violation of rules shall cease. If fraudulent use of gas is detected, or if the regulating or measuring equipment of the utility has been tampered with, or if a dangerous condition is found to exist on the premises of customers, the gas may be shut off without advance notice.
§ 59.25. Notice of desire to have service discontinued.
A customer who is about to vacate premises supplied with service by a public utility, or who wishes to have service discontinued, shall give at least 24-hour notice to the utility, specifying the date on which it is desired that service be discontinued. In the absence of notice, the customer shall be responsible for services rendered.
§ 59.26. Refusal to serve applicants or customers.
(a) A public utility may initially decline to serve an applicant if, in the judgment of the utility, any of the following conditions are present:
(1) The applicant has not complied with Commonwealth and municipal regulations governing gas service, and with the rules and regulations of the utility.
(2) The installation of piping or gas equipment of the applicant is hazardous or improper.
(3) The service requested by the applicant is unreasonable and improper under the circumstances.
(b) A public utility may decline to serve an existing customer if, in the judgment of the utility, a hazardous condition exists regarding the piping or gas equipment of the customer.
Authority The provisions of this § 59.26 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 1501, 1504, 1507 and 1508.
Source The provisions of this § 59.26 amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial page (225738).
§ 59.27. Extension of facilities.
Each public utility shall file with the Commission, as part of its tariff, a rule setting forth the conditions under which facilities will be extended to supply service to an applicant within all, or designated portions, of its service area. The utility may, upon proper cause shown, refuse or condition the acceptance of a particular application of extension of facilities.
§ 59.28. Installation.
(a) Displacement meters. Each public utility shall adopt standard methods for installing meters.
(b) Orifice meters. All orifice meter settings shall be constructed and maintained in accordance with accepted good practice, which is best indicated by the American Gas Association; 1515 Wilson Boulevard; Arlington, Virginia 22209: Orifice Metering of Natural Gas, ‘‘Gas Measurement Committee Report No. 3,’’ ANSI/API 2530 1978.
(c) Service connection. When connecting the premises of the customer with public utility distribution mains, the public utility shall furnish, install and maintain the service line or connection according to the rules and regulations of its filed tariff.
Authority The provisions of this § 59.28 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 1301, 1304, 1501, 1502 and 1507.
Source The provisions of this § 59.28 amended through September 17, 1982, effective September 18, 1982, 12 Pa.B. 3291. Immediately preceding text appears at serial page (37405).
§ 59.29. Gas pressure requirements for low-pressure distribution systems.
(a) Maximum pressure. The maximum pressure specified for a low pressure system may not be greater than a pressure which will not cause the unsafe operation of connected and properly adjusted gas utilization equipment or 14 inches of water column (8.1 ounces), whichever is less, at the outlet of the service meter of a low pressure customer.
(b) Minimum pressure. The minimum pressure at the outlet of a service meter of a low pressure customer may not be less than a pressure which will not cause the unsafe or inadequate operation of a connected and properly adjusted gas utilization equipment or 2 inches of water column (1.2 ounces), whichever is greater, unless due to insufficient capacity of the service line owned by the customer.
(c) Changing pressure. A public utility may change the distribution pressure for any system, but if a change is made, all appliances of a customer located within the system shall, if necessary, be readjusted by and at the expense of the utility.
(d) Pressure gauges. A public utility shall maintain and operate on the outlet side of the system regulator station, at least one recording gas pressure gauge of suitable range. If more than one regulator station is used to serve a single pressure system, recording pressure gauges need not be installed for each regulator station. A sufficient number of recording pressure gauges shall be installed and operated in each distribution system to furnish a continuous record of the pressure prevailing in all parts of the system.
Authority The provisions of this § 59.29 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 1501, 1504, 1507 and 1508.
Source The provisions of this § 59.29 amended May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901; amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial pages (211171) to (211172).
Cross References This section cited in 52 Pa. Code § 59.1 (relating to definitions).
§ 59.30. Heating value and purity of gas.
(a) Testing apparatus. The accuracy of testing apparatus, as well as the method of making heating-value tests, shall be subject to the approval of the Commission.
(b) Tests. Each public utility shall make or obtain the determinations as may be necessary to ascertain the heating value of the gas introduced into its distribution system and shall maintain an average heating value not less than the minimum authorized. If compression, processing or other factors tend to affect the heat content of all or any portion of its gas, determinations of heating value shall be made of gas drawn from different parts of the distribution system at points remote from the point where the gas enters the distribution system, with the frequency and in the manner as may be necessary to assure compliance with this section.
(c) Records of tests. Each public utility shall adopt a standard printed form for recording the results of heating value tests. Each determination of heating value shall be recorded originally upon the form adopted for that purpose. If heating value is determined by an approved type of recording calorimeter, the charts removed from a calorimeter shall be sufficient to comply with the requirements of this section. If manufactured or mixed gas is served, the average heating value determined by these tests shall be recorded.
(d) Heating value. The heating value of gas shall be as follows:
(1) Natural gas. If a public utility supplies natural gas, its heating value may not fall below 950 Btu total heating value per cubic foot, under standard conditions of temperature and pressure.
(2) Manufactured or mixed gas. Manufactured or mixed gas shall conform with all of the following:
(i) If a public utility supplies manufactured or mixed gas, its heating value shall have a monthly average of not less than 520 Btu total heating value per cubic foot under standard conditions of temperature and pressure. The minimum heating value of manufactured gas shall never fall below 500 Btu.
(ii) To obtain the heating value of gas, the results of the tests of heating value made under standard practice on each day during the calendar month shall be averaged, and the average of the daily averages shall be taken as the monthly average.
(iii) Each public utility serving manufactured or mixed gas shall provide and maintain a calorimeter with necessary accessories of an approved type for the regular determination of the heating value of the gas sold, unless other provision is made with the approval of the Commission.
(iv) The calorimeter required for measuring manufactured or mixed gas shall be installed in a laboratory or other building so located as to insure that thoroughly mixed, stabilized and representative samples of the gas delivered to customers are used for the tests.
(v) Each public utility serving manufactured or mixed gas shall determine the heating value of the gas distributed to its customers daily or more frequently if necessary, or if required by the Commission.
(e) Purity of gas. The purity of gas distributed in this Commonwealth shall conform with the following:
(1) Gas shall be substantially free from dangerous or objectionable quantities of impurities such as hydrogen sulphide, nitrogen or other combustible or noncombustible constituents which, if the gas is completely burned, yield noxious or toxic products of combustion.
(2) Hydrogen sulphide in the gas shall be considered negligible if a strip of white filter paper, moistened with a solution containing 5.0% by weight of lead acetate, is not distinctly darker than a second paper freshly moistened with the same solution, after the first paper has been exposed for one minute in an apparatus of approved form, through which the gas is flowing at the rate of approximately 5 cubic feet per hour, the gas not impinging directly from the jet upon the test paper.
(3) No gas sold shall contain more than 30 grains total of sulphur per 100 cubic feet and not more than five grains of ammonia per 100 cubic feet.
§ 59.31. Service from production or transmission lines.
(a) Conditions of service. Service to applicants directly from production or transmission lines which are not part of the distribution system from which customers are normally supplied shall be furnished under conditions stated in the tariff rules and regulations of the utility.
(b) Excess pressure protection. If the pressure from lines governed by this section is reduced to standard service pressure for use by the customer, the installation shall be provided with adequate over-pressure protection to prevent the pressure from exceeding two pounds per square inch in the event of regulator failure.
(c) Cost of equipment. The utility may require a customer served directly from a line governed by this section to provide and install the regulator and excess pressure protective device necessary to render service, or the utility may provide such equipment and make a reasonable charge for the equipment and its installation.
(d) Location of equipment. If a customer is served directly from a line governed by this section, the regulator and meter shall be located as closely as possible to the point where the line is tapped.
Cross References This section cited in 52 Pa. Code § 59.17 (relating to furnishing of meters and regulations).
§ 59.32. Temporary service.
In the case of temporary service for short-term use, a public utility may either require the customer to pay the costs of marking the service connection and removing the material after the service has been discontinued, or to pay a fixed amount in advance to cover the expenses. However, if the material is removed the customer shall be credited with the reasonable salvage which the public utility will receive on discontinuance of service.
§ 59.33. Safety.
(a) Responsibility. Each public utility shall at all times use every reasonable effort to properly warn and protect the public from danger, and shall exercise reasonable care to reduce the hazards to which employees, customers and others may be subjected to by reason of its equipment and facilities.
(b) Safety code. The minimum safety standards for all natural gas and hazardous liquid public utilities in this Commonwealth shall be those issued under the pipeline safety laws as found in 49 U.S.C.A. § § 60101—60503 and as implemented at 49 CFR Parts 191—193, 195 and 199, including all subsequent amendments thereto. Future Federal amendments to 49 CFR Parts 191—193, 195 and 199, as amended or modified by the Federal government, shall have the effect of amending or modifying the Commission’s regulations with regard to the minimum safety standards for all natural gas and hazardous liquid public utilities. The amendment or modification shall take effect 60 days after the effective date of the Federal amendment or modification, unless the Commission publishes a notice in the Pennsylvania Bulletin stating that the amendment or modification may not take effect.
(c) Definition. For the purposes of this section, ‘‘hazardous liquid public utility’’ means a person or corporation now or hereafter owning or operating in this Commonwealth equipment or facilities for transporting or conveying crude oil, gasoline, petroleum or petroleum products, by pipeline or conduit, for the public for compensation.
(d) Enforcement. Each public utility shall be subject to inspections as may be necessary to assure compliance with this section. The facilities, books and records of each public utility shall be accessible to the Commission and its staff for the inspections. Each public utility shall provide the Commission or its staff the reports, supplemental data and information as it shall from time to time request in the administration and enforcement of this section.
(e) Records. Each public utility shall keep adequate records as required for compliance with the code in subsection (b). The records shall be accessible to the Commission and its staff.
Authority The provisions of this § 59.33 issued and amended under the Public Utility Code, 66 Pa.C.S. § § 102, 331, 501, 1501, 1504, 1507 and 1508.
Source The provisions of this § 59.33 amended through May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901; amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050; amended June 23, 2006, effective June 24, 2006, 36 Pa.B. 3092; amended September 21, 2012, effective September 22, 2012, 42 Pa.B. 5967. Immediately preceding text appears at serial pages (320169) to (320170).
(Editor’s Note: Publication of notice ratifying the amendments to 49 CFR Parts 191, 192, 193 and 199 appeared at 27 Pa.B. 851 (February 15, 1997), 33 Pa.B. 5486 (November 1, 2003) and 34 Pa.B. 3655 (July 10, 2004). See serial pages (800645) to (800646)).
Cross References This section cited in 52 Pa. Code § 59.34 (relating to leakage surveys of customer-owned service lines); 52 Pa. Code § 59.35 (relating to increasing pressure in distribution facilities and transmission facilities); and 52 Pa. Code § 59.36 (relating to abandonment of inactive service lines).
§ 59.34. Leakage surveys of customer-owned service lines.
(a) Plan. A public utility shall establish and execute a plan by which it will periodically survey each customer-owned service line for leakage. The plan shall conform with or exceed the standards estalbished in 49 CFR 192.723 (relating to distributuion systems; leakages and procedures) as of May 1, 1986 and subsequent amendments thereto which have been ratified by the Commission under § 59.33 (relating to safety). The public utility shall file with the Commission a copy of the plan required by this subsection including statements of the type of survey it will use and of the frequency of the survey. As used in this section, the term ‘‘customer-owned service line’’ includes that piping serving a residential or commercial customer which is between the main, pipeline or other source of supply and whichever is the more remote of either the meter set assembly, or the wall of the residence or commercial building if the customer owns part of the piping.
(b) Access to customer premises. If the leakage survey prescribed by subsection (a) requires access to the premises of a customer and the customer refuses access, or if the public utility requires a customer to inform it of the location of a service line and he fails to provide the information, the public utility may shut off gas service until access is permitted or the information is provided. If subsection (a) requires a leakage survey to a meter set assembly inside the wall of a residence or commercial building, and the public utility cannot gain access to the building because of absence of the occupants, the public utility shall leave a notice at the premises, instructing the customer to designate to the public utility a day and time during normal working hours when access may be had. The public utility may defer the leakage survey to the day and time so designated.
(c) Procedure after survey. Upon completion of a survey of a customer-owned service line, the public utility shall make a record showing the date and method of the survey, and the result found. If the result shows that a leak exists in the service line, the public utility shall require the customer to repair or renew the line, and may shut off gas service until repair or renewal has been effected. The public utility shall retain the record of the two most recent surveys made under this section.
Source The provisions of this § 59.34 amended May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901. Immediately preceding text appears at serial page (87817).
§ 59.35. Increasing pressure in distribution facilities and transmission facilities.
A significant increase in the normal operating pressure of a distribution or transmission pipeline shall be made in accordance with 49 CFR Part 192, Subpart K (relating to uprating) as of May 1, 1986, and subsequent amendments thereto which have been ratified by the Commission under § 59.33 (relating to safety). A leak survey of mains and services shall be made prior to increasing the pressure initially and also following each incremental increase in pressure. Structures abutting or adjacent to the gas mains shall be inspected to confirm the utility’s records as to the presence or absence of a gas service line on each property.
Authority The provisions of this § 59.35 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 1501, 1504, 1507 and 1508.
Source The provisions of this § 59.35 amended May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901; amended July 2, 1998, August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial page (225742).
§ 59.36. Abandonment of inactive service lines.
A public utility shall have a plan for abandoning inactive service lines under 49 CFR 192.727 (relating to abandonment or inactivation of facilities) as of May 1, 1986 and subsequent amendments thereto which have been ratified by the Commission under § 59.33 (relating to safety), and shall have a copy of its plan available for inspection. The plan shall require the following:
(1) Service lines which are not constructed of noncorrosive material or part of a cathodic protection system which have been inactive for 3 months and for which there is no prospect of reuse shall be scheduled for abandonment under 49 CFR 192.727 as of May 1, 1986 and subsequent amendments thereto which have been ratified by the Commission under § 59.33, as soon as practicable but not later than 6 months after it has been determined there is no prospect for reuse.
(2) Service lines which have been inactive for 3 months and for which there is a reasonable prospect of future use shall be shut off under 49 CFR 192.727(d) as of May 1, 1986 and subsequent amendments thereto which have been ratified by the Commission under § 59.33. A review of the status of inactive lines shall be made annually, at periods not exceeding 15 months. Lines which no longer qualify for retention shall be abandoned under paragraph (1).
(3) Inactive service lines shall be leakage surveyed periodically under 49 CFR 192.723 (relating to distribution systems; leakage surveys and procedures) as of May 1, 1986 and subsequent amendments thereto which have been ratified by the Commission under § 59.33. An inactive service line found to be leaking shall be abandoned immediately if hazardous. If the leak is not hazardous, the line shall be abandoned within 3 months or repaired within this time period if the line is constructed of noncorrosive material or part of a cathodic protection system.
(4) Unrecorded inactive service lines discovered in the course of leakage surveillance, construction, maintenance or inspection of facilities shall be abandoned as follows: If leaking, abandon immediately; if not leaking, abandon as soon as practicable but not more than 10 days after discovery.
(5) If a building is to be demolished or if there will be a major excavation of property on which there is an active or inactive service line, and if there is no reasonable prospect of future use, the service line shall be abandoned at the main under paragraph (1). If there is a reasonable prospect of future use, the service line may be abandoned at the curb or property like and its status shall be reviewed annually, at periods not exceeding 15 months, under paragraph (2). The service line shall be disconnected either at the main or property line prior to demolition or excavation.
Source The provisions of this § 59.36 amended May 30, 1986, effective May 31, 1986, 16 Pa.B. 1901. Immediately preceding text appears at serial page (20981).
§ 59.37. Maps, plans and records.
Each public utility shall keep complete maps, plans, and records of its entire distribution and other system showing the size, character, and location of each main, district regulator, street valve and drip, and each service connection, together with such other information as may be necessary. The maps, plans, and records required by the provisions of this section shall be kept up to date so that the utility may promptly and accurately furnish any information regarding its facilities, or copies of its maps, upon request by the Commission.
§ 59.38. Filing of major construction reports.
A public utility shall notify the Commission of proposed major construction, reconstruction or maintenance of plant at least 30 days prior to the commencement of work. Major construction, reconstruction or maintenance is defined for this reporting as a single project involving an expenditure in excess of $300,000 or 10% of the cost of the utility’s plant in service, whichever is less, production well drilling to be excluded. This notification of proposed construction shall include the following:
(1) Description and location (city, township, county) of proposed work.
(2) Type of facility (distribution main, transmission pipeline, compressor station, and the like).
(3) Estimated starting date.
(4) Estimated completion date.
(5) Design pressure.
(6) Estimated cost.
(7) Name and address of reporting gas company.
(8) Name, address and telephone number of person to be contacted regarding the project.
(9) Notification to the Commission of the completion date.
Authority The provisions of this § 59.38 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 1501, 1504, 1507 and 1508.
Source The provisions of this § 59.38 amended May 30, 1986 effective May 31, 1986, 16 Pa.B. 1901; amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial page (211177).
ACCOUNTS AND RECORDS
§ 59.41. Classification of gas public utilities.
For accounting and reporting purposes, gas public utilities are classified as follows:
(1) Major. Public utilities having annual gas operating revenues of $1 million or more.
(2) Nonmajor. Public utilities having annual gas operating revenues of less than $1 million.
Authority The provisions of this § 59.41 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 1501, 1504, 1507 and 1508.
Source The provisions of this § 59.41 amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial page (211178).
§ 59.42. Systems of accounts.
(a) Each major gas public utility shall keep its accounts in conformity with the ‘‘Uniform System of Accounts Prescribed for Natural Gas Companies (Major)’’ by the Federal Energy Regulatory Commission (18 CFR Part 201).
(b) Each nonmajor gas public utility shall keep its accounts in conformity with the ‘‘Uniform System of Accounts Prescribed for Natural Gas Companies (Non-Major)’’ by the Federal Energy Regulatory Commission (19 CFR Part 201).
(c) A gas public utility with annual gas operating revenue of less than $25,000 shall keep the accounts as will be adequately informative for reasonable and foreseeable regulatory purposes.
(d) This section applies to manufactured gas public utilities.
Authority The provisions of this § 59.42 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 1501, 1504, 1507 and 1508.
Source The provisions of this § 59.42 amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial page (211178).
Cross References This section cited in 52 Pa. Code § 59.43 (relating to accounting for merchandising, jobbing and contract work); 52 Pa. Code § 59.46 (relating to reclassification of gas plant accounts); and 52 Pa. Code § 59.47 (relating to continuing property records).
§ 59.43. Accounting for merchandising, jobbing and contract work.
(a) All revenues from and costs and expenses pertaining to merchandising, jobbing and contract work shall be recorded appropriately in Accounts 914 and 915, in the case of Class A, Class B and Class C companies and appropriately in Accounts 780 and 781 in the case of Class D companies in the unified system of accounts prescribed in § 59.42 (relating to systems of accounts).
(b) The provisions of this section apply to manufactured gas public utilities.
§ 59.44. Retirement unit for gas plant.
Each public utility having gas operating revenues of $100,000 or more shall, in accounting for plant retirements, conform its accounting to the ‘‘Units of Property for Use in Accounting for Additions and Retirements of Gas Plant,’’ prescribed by Federal Power Commission Order No. 236, dated October 16, 1961 (18 CFR Part 216).
§ 59.45. Preservation of records.
Each gas utility shall keep and preserve its records in conformity with the provisions applicable to it in the most recent publication of the National Association of Regulatory Utility Commissioners, entitled ‘‘Regulations to Govern the Preservation of Records of Electric, Gas and Water Utilities,’’ except as follows when the following retention periods apply:
Item No. and Description Retention Period 6. (a) Minute books of stockholders’, directors’, and directors’ committee meetings. 25 years 6. (b)(4) Licenses (including amendments thereof) granted by Federal or State authorities for construction and operation of utility plant. 5 years after plant is retired or expiration of license, whichever is shorter. 8. (a) Reports of examinations and audits by accountants and auditors not in the regular employ of the utility (such as reports of public accounting firms and regulatory commission accountants). 5 years after date of report or Commission audit, whichever comes last. 8. (b) Internal audit reports and work papers. 5 years after date of report or Commission audit, whichever comes last. 10. (a)(1) General ledgers. 20 years 10. (a)(2) Ledgers subsidiary or auxiliary to general ledgers except ledgers provided for elsewhere. 20 years 10. (b)(1) Indexes to general ledgers. 20 years 10. (b)(2) Indexes to subsidiary ledgers except ledgers provided for elsewhere. 20 years 11. (a) Journals, general and subsidiary. 20 years 12. (a) Journal vouchers and journal entries. 20 years 13. (a) Cash books, general and subsidiary or auxiliary books. 5 years after close of fiscal year. 14. (a) Voucher registers or similar records when used as a source document. 5 years 15. (a) Paid and cancelled vouchers (1 copy analysis sheets showing detailed distribution of charges on individual vouchers and other supporting papers). 5 years 15. (b) Original bills and invoices for materials, services, and the like, paid by vouchers. 5 years 15. (c) Paid checks and receipts for payments by voucher or otherwise. 5 years 15. (d) Authorization for the payment of specific vouchers. 5 years 22.4 (e) Pumping output logs with supporting data. 3 years 26. (a) Authorization for expenditures for maintenance work to be covered by work orders, including memoranda showing the estimates of costs to be incurred. 5 years 26. (b) Work order sheets to which are posted in detail the entries for labor, material and other charges in connection with maintenance and other work pertaining to utility operations. 5 years 26. (c) Summaries of expenditures on maintenance and job orders and clearances to operating and other accounts (exclusive of plant accounts). 5 years 30. (a) Ledgers of utility plant accounts including land and other detailed ledgers showing the costs of utility plant by classes. 30 years 31. (a) Construction work in progress ledgers. 5 years after clearance to the plant account, provided continuing property plant inventory records are maintained; otherwise 6 years after plant is retired. 31. (b) Work order sheets to which are posted in summary form or in detail the entries for labor, materials and other charges for utility plant additions and the entries closing the work orders to utility plant in service at completion. 5 years after clearance to the plant account, provided continuing property plant inventory records are maintained; otherwise 6 years after plant is retired. 31. (f) Analysis or cost reports showing quantities of materials used, unit costs, number of man-hours, and the like, in connection with completed construction project. 5 years after clearance to the plant account, provided continuing property plant inventory records are maintained; otherwise 5 years after plant is retired. 33. Summary sheets, distribution sheets, reports, statements, and papers directly supporting debits and credits to utility plant accounts not covered by construction or retirement work orders and their supporting records. 5 years after clearance to the plant account, provided continuing property plant inventory records are maintained; otherwise 6 years after plant is retired. 41. (a) Ledger sheets and card records of materials and supplies received, issued and on hand. 6 years 45. (a) Applications for utility service for which contracts have been executed. 4 years 45. (g) Applications and contracts for extensions covered by refundable deposits or guarantees of revenue, also records pertaining to such contracts. 4 years after entire amount is refunded. 45. (h) Applications and contracts for extensions for which donations or contributions are made by customers or others. 4 years after expiration. 46. (a) General files of published rate sheets and schedules of utility service (including schedules suspended or superseded). 6 years 51. (a) Summaries of monthly operating revenues according to classes of service for entire utility. 5 years 51. (b) Summaries of monthly operating revenues according to classes of service by towns, districts, or divisions (including summaries of forfeited discounts and penalties). 5 years 53. (e) Cashiers’ stubs for merchandise collection. 1 year 57. (a)(1) Federal income tax returns. 5 years after settlement. 57. (a)(5) Agreements between associate companies as to allocation of consolidated income taxes. 5 years after settlement. 57. (c) Filings with taxing authorities to qualify employee benefit plans. 5 years after settlement of Federal return or discontinuance of plan, whichever is later. 59. (f) Check stubs, registers, or other records of checks issued. 5 years 59. (g) Correspondence and memoranda relating to the stopping of payment of bank checks and to the issuance of duplicate checks. 5 years or destroy at option after check is recovered. 61. (a) Annual financial, operating and statistical reports regularly prepared in the course of business for internal administrative or operating purposes (and not used as the basis for entries to accounts of the companies concerned) to show the results of operations and the financial condition of the utility. 5 years after date of report. 65. (a) Annual financial, operating and statistical reports. 15 years 65. (c)(1) Transaction with associated companies. 5 years 65. (c)(7) Purchases and sales, utility properties. 10 years 65. (c)(9) Service interruptions. 5 years 66. (a) Copies of advertisements by the company on behalf of itself or any associate company in newspapers, magazines and other publications including records thereof (excluding advertising of product, appliances, employment opportunities, services, territory, routine notices and invitations for bids for securities, all of which may be destroyed at option). 3 years
Authority The provisions of this § 59.45 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.45 amended January 24, 1997, effective January 25, 1997, 27 Pa.B. 414; amended December 5, 2003, effective December 6, 2003, 33 Pa.B. 5923; amended March 25, 2005, effective March 26, 2005, 35 Pa.B. 1886. Immediately preceding text appears at serial pages (301434) to (301440).
§ 59.46. Reclassification of gas plant accounts.
(a) A utility whose annual operating revenues are $25,000 or more but less than $100,000 may not be required to reclassify the cost of plant installed prior to January 1, 1961, to an original cost basis until the time as its annual operating revenues reach $100,000 or more.
(b) When the annual operating revenues of a public utility become $100,000 or more, the utility shall be subject to Class C accounting requirements. The public utility shall within 2 years submit the following detailed statements relative to its plant account reclassification at original cost. The statements shall be sworn to or affirmed by the officer of the company responsible for their preparation, as follows:
(1) Statement A. Statement A shall show in outline form the origin and development of the utility, including a description of each consolidation and merger to which the utility or a predecessor was a party, and each acquisition of a gas operating unit or system by the utility or a predecessor. If any transaction relating to such property involved utility property other than the gas plant, that fact shall be stated.
(2) Statement B. Statement B shall show the chartered gas territory of the utility, giving the development of that territory according to each consolidation and merger or gas plant acquisition to which the utility or a predecessor was a party.
(3) Statement C. Statement C shall show a summary of gross debits and credits to Accounts 101, 102, 103, 104, 105, 106, 107 and 114, gas plant, from the date of origin of the gas plant of the utility to the effective date of such system of accounts as prescribed by § 59.42 (relating to systems of accounts), setting forth all of the following:
(i) Plant acquired by merger and consolidation.
(ii) Plant constructed by the utility.
(iii) Plant acquired by purchase.
(iv) Total.
(v) Retirements of plant which cannot be classified by the specific divisions of subparagraphs (i)—(iii).
(vi) Balance at effective date of the system of accounts.
(4) Statement D. Statement D shall show a summary analysis of the accumulated provisions for the depreciation, amortization and depletion of the gas plant, as established by the utility and its predecessors, from the date of origin of the gas plant of the utility to the effective date of the system of accounts as prescribed by § 59.42, showing all of the following:
(i) Credits arising from charges to operating expenses.
(ii) Salvage and other credits detailed by nature of transaction.
(iii) Gross debits for plant retired.
(iv) Cost of removal, and other debits detailed by nature of transaction.
(v) Balance at effective date of the system of accounts.
(5) Statement E. Statement E shall show contributions received by the utility and its predecessors, from customers or others, in the aid of construction of a gas plant, setting forth all of the following:
(i) The gross amount of contributions received from the date of origin of gas service to the effective date of such system of accounts as prescribed by § 59.42.
(ii) The amount of the contributions returned or retired as of the effective date of the system of accounts.
(iii) The difference between subparagraphs (i) and (ii).
(iv) The amount reflected in Account 271, ‘‘Contributions in aid of construction,’’ at the effective date of the system of accounts.
(v) A reconciliation of the difference between subparagraphs (iii) and (iv).
(6) Statement F. Statement F shall conform with all of the following:
(i) Statement F shall show, for each acquisition through consolidation and merger or purchase of a gas operating unit or system by the utility or a predecessor, all of the following:
(A) A description of the property acquired.
(B) The names of parties to the transaction and whether the parties were affiliated.
(C) The date the transaction was consummated.
(D) The original cost, estimated if not known.
(E) The value of the plant, as reflected on books of merger constituent or vendor.
(F) The cost of the plant to the acquirer, and the manner and method of determination of such cost.
(G) The amount recorded on the books of the acquirer with respect to the plant acquired.
(H) The amount accumulated provisions for depreciation applicable to the plant acquired, as reflected on books of merger constituent or vendor.
(I) An adjustment of amortization or depletion of the acquirer in respect to the plant acquired and the basis thereof.
(J) A summary of the appraisal, if any, prepared for the plant acquired at the date of acquisition, showing the elements of value included therein, by whom prepared, and the date. With respect to each acquisition, there shall be shown the difference between original cost and the amount recorded on the books; a summary of all transactions affecting the difference between the date of acquisition and the effective date of such system of accounts prescribed by § 59.42; and the resultant amount on the latter date. The amount to be included in Account 114, ‘‘Gas plant acquisition adjustments,’’ shall be subdivided to show the amounts applicable to plant in service, plant leased to others, and plant held for future use. If practicable, the amount shall be classified according to its nature, that is, structural value, going value, and the like.
(ii) If estimates are used in arriving at original cost or the amount to be included in Account 114 of the uniform system of accounts prescribed by § 59.42, a full disclosure of the method or methods used in preparing the estimates, with the underlying facts, shall be given. The method or methods of determining the original cost of the gas plant acquired as operating units or systems shall be described in sufficient particularity to permit a clear understanding of the investigations which were made for that purpose. The amount claimed as the original cost of acquired property shall be supported by separate statements for each acquisition by the respondent and by each successive predecessor (prepared from the books and records of each predecessor company) showing a summary of gross debits and credits to the gas plant, classified by balance sheet subaccounts, from the date of origin of the gas plant of the predecessor to the date of dissolution or the effective date of sale or other transfer of the gas plant, setting forth all of the following:
(A) Plant acquired by merger and consolidation.
(B) Plant constructed by such predecessor.
(C) Plant acquired by purchase.
(D) Total.
(E) Retirements of plant which cannot be classified by the specific divisions in subparagraphs (i)—(iii).
(F) Balance at date of dissolution or effective date of sale or other transfer of the gas plant.
(iii) There shall also be shown a summary analysis of the related accumulated provisions for depreciation, amortization, and depletion of the gas plant as established by each predecessor, setting forth all of the following:
(A) Credits arising from charges to operating expenses.
(B) Salvage and other credits detailed by nature of transaction.
(C) Gross debits for plant retired.
(D) Costs of removal, and other debits detailed by nature of transaction.
(9) Statement G. Statement G shall show the amounts arrived at by appraisals recorded prior to the effective date of the system of accounts prescribed by § 59.42 in lieu of cost to the reporting company. This statement should give the full journal entry at the time the appraisal was originally recorded, and if the entry had the effect of appreciating or writing up the gas plant account, the amount of the appreciation or write up should be traced, by proper description and explanation of the changes from the date recorded to the effective date of such system of accounts.
(10) Statement H. Statement H shall show gas plant per books immediately prior to reclassification in accordance with the system of accounts prescribed by § 59.42 including, under a descriptive heading, an unclassified amounts applicable jointly to the gas department and other departments of the utility.
(11) Statement I. Statement I shall show a summary of adjustments necessary to record, as of the effective date of the system of accounts prescribed by § 59.42, Accounts 101, 102, 103, 104, 105, 106, 107 and 114, gas plant, and Account 116, ‘‘Other Gas Plant Adjustments.’’
(12) Statement J. Statement J shall show gas plant balance sheet Accounts 101, 102, 103, 104, 105, 106, 107 and 114 as of the effective date of the system of accounts prescribed by § 59.42 classified according to detailed accounts, and showing also the amount includible in Account 116, ‘‘Other Gas Plant Adjustments.’’
(13) Statement K. Statement K shall show a comparative balance sheet, as of the effective date of the system of accounts prescribed by § 59.42 setting forth the accounts and amounts appearing in the books before the adjusting entries have been made and after the entries have been made.
(14) Statement L. Statement L shall show a suggested plan for depreciating, amortizing, or otherwise disposing in whole or in part of the amounts, as of the effective date of such system of accounts prescribed by § 59.42 includible in Account 114, ‘‘Gas Plant Acquisition Adjustments,’’ and Account 116, ‘‘Other Gas Plant Adjustments.’’
§ 59.47. Continuing property records.
(a) Each public utility having annual gas operating revenue of $100,000 or more shall maintain a continuing property record of its gas plant the cost of which is recorded in Accounts 101, 102, 103, 104 and 105 of the uniform accounting system prescribed by § 59.42 (relating to systems of accounts).
(b) An outline of the plan of the company for the establishment and maintenance of its continuing property record shall be submitted to the Commission within 2 years after the effective date of its change of revenue classification for approval. Thereafter, a proposed major changes in the plan shall be submitted to the Commission for approval.
(c) Continuing property records shall contain detailed description and classification of property record units which meet the following objectives:
(1) An inventory of plant by property-record units which may be readily checked for proof of existence.
(2) The association of costs with the units, to assure accurate retirement accounting.
(3) The dates of installation and removal of property-record units, to provide age and life data for use in depreciation studies.
(d) The continuing property record, or records supplemental to those records, shall include information as to the kind, character, size, quantity, location, year of placement and retirement, percentage of ownership, and original cost of gas plant.
(e) Plants comprising a large number of similar units, such as mains, meters, and regulators, may be grouped, and the average cost thereof used for retirement accounting. Grouping should be by years of construction within one cost-keeping area. The entire system may be considered as one cost-keeping area unless otherwise required for regulatory purposes. If it is impracticable to account for construction by years, the company may, with Commission approval, cost certain items by bands of years or by average costs for all years. The grouping does not relieve the utility from its requirement to provide age and life data and to maintain location records for the plant.
§ 59.48. Filing of annual financial reports.
Under 66 Pa.C.S. § § 504 and 3301 (relating to reports by public utilities; and civil penalties for violations), the Commission may require a public utility to file certain reports, and invoke penalties for failure to file the reports. In this regard, the following apply:
(1) Unless prior permission to do otherwise is granted, a public utility, other than transportation subject to the jurisdiction of the Commission, shall file with the Commission annual financial reports by April 30 immediately following the reporting year, for reports based upon the calendar year, and by July 31 immediately following the reporting year, for reports permitted to be based upon the fiscal year ending May 31. A request for an extension of time for filing an annual report shall be submitted to the Commission prior to the filing dates specified in this paragraph.
(2) If a public utility other than transportation fails to file its annual report in compliance with paragraph (1), the public utility may be subject to a penalty as provided under 66 Pa.C.S. § 3301. Continued failure to file annual reports may result in additional penalties.
Authority The provisions of this § 59.48 amended under Public Utility Code,66 Pa.C.S. § § 501 and 504.
Source The provisions of this § 59.48 amended May 6, 1988, effective May 7, 1988, 18 Pa.B. 2106. Immediately preceding text appears at serial page (107928).
Cross References This section cited in 52 Pa. Code § 101.2 (relating to definitions); and 52 Pa. Code § 101.4 (relating to reporting requirements).
SALES PROMOTION PRACTICES
§ 59.51. [Reserved].
Source The provisions of this § 59.51 amended July 23, 1993, effective July 24, 1993, 23 Pa.B. 3472; reserved May 21, 1999, effective May 22, 1999, 29 Pa.B. 2667. Immediately preceding text appears at serial pages (246435) to (246436).
REPORTING AND CURTAILMENT OF SERVICE
Authority The provisions of these § § 59.61—59.67 issued under Public Utility Code,66 Pa.C.S. § § 501, 1501 and 1504, unless otherwise noted.
Source The provisions of these § § 59.61—59.67 adopted June 17, 1977, effective June 18, 1977, 7 Pa.B. 1641, unless otherwise noted.
§ 59.61. [Reserved].
Source The provisions of this § 59.61 adopted June 17, 1977, effective June 18, 1977, 7 Pa.B. 1641; amended June 17, 1977, effective June 18, 1977, 7 Pa.B. 2138; reserved March 22, 1996, effective March 23, 1996, 26 Pa.B. 1265. Immediately preceding text appears at serial pages (196683) to (196684).
Cross References This section cited in 52 Pa. Code § 59.64 (relating to notice of curtailment or nonperformance of supply); and 52 Pa. Code § 59.65 (relating to sales policies filed with the Commission).
§ 59.62. [Reserved].
Source The provisions of this § 59.62 amended through July 1, 1983, effective July 2, 1983, 13 Pa.B. 2062; amended April 29, 1988, effective April 30, 1988, 18 Pa.B. 2028; amended March 22, 1996, effective March 23, 1996, 26 Pa.B. 1265; reserved amended July 2, 1998, effective August 3, 1998, 28 Pa.B. 3050. Immediately preceding text appears at serial pages (213706) and (211185) to (211186).
Notes of Decisions Commission decision refusing exemption under 52 Pa. Code § 59.62(h)(4), because conversion from gas to electricity would not be unduly burdensome, was supported by substantial evidence where commission calculations indicated equal or slightly lower cost over five-year period. John Sheldrake, Inc. v. Pennsylvania Public Utility Commission, 494 A.2d 1171 (Pa. Cmwlth. 1985).
Ban on sale of natural gas for use in commercial outdoor lights, 52 Pa. Code § 59.62(h) does not violate due process or equal protection clauses since it serves purpose of curtailing use of natural gas, aiding in conservation of a finite natural resource. John Sheldrake, Inc. v. Pennsylvania Public Utility Commission, 494 A.2d 1171 (Pa. Cmwlth. 1985).
Voluntary unincorporated association of 30 residents, including Chatham College, owning property along street, is considered a residential customer, thereby entitled to exemption from the ban on outside natural gas lighting under subsection (h). Woodland Road Association v. Pennsylvania Public Utility Commission, 487 A.2d 1030 (Pa. Cmwlth. 1985).
In response to Philadelphia Electric Company’s argument that a significant annual surcharge imposed upon all its residential gas customers using outdoor gas lights would be too costly to administer on an equitable basis, the PUC found that the company’s compliance with this section would allow the company to administer the program without significant additional costs, and such finding was supported by substantial evidence. Philadelphia Electric Co. v. Pennsylvania Public Utility Commission, 470 A.2d 654 (Pa. Cmwlth. 1984).
§ 59.63. Natural gas emergency plans.
As part of its officially filed tariff, each jurisdictional gas utility shall have on file with the Commission natural gas emergency plans. The plans shall be under Commission requirements § § 59.71—59.75 (relating to gas emergency plans).
Authority The provisions of this § 59.63 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 2203(12) and 2208.
Source The provisions of this § 59.63 amended December 14, 2001, effective December 15, 2001, 31 Pa.B. 6800. Immediately preceding text appears at serial page (267663).
§ 59.64. Notice of curtailment or nonperformance of supply.
(a) Each major jurisdictional utility, as defined in § 59.61 (Reserved), shall inform the Commission, in writing, of any curtailment, breach of performance, suspension of performance or nonperformance by a gas supplier, transportation utility or major shipper (defined as any shipper utilizing transportation tariffs whose monthly demand is in excess of 5% of the jurisdictional utility’s monthly throughput in any given month) within 48 hours after the action becomes known to the jurisdictional utility. Notice to the Commission shall include a statement as to the estimated effect on the utility and its customers, including any resulting curtailments, penalties or additional costs.
(b) Each major jurisdictional utility, as defined in § 59.61, shall contemporaneously notify its customers and the Commission whenever curtailments are instituted or changed. The notice shall be provided as soon as practicable.
Authority The provisions of this § 59.64 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 504, 1301, 1304, 1307, 1317 and 1318.
Source The provisions of this § 59.64 amended April 14, 1995, effective June 14, 1995, 25 Pa.B. 1411. Immediately preceding text appears at serial pages (126835) and (187327).
§ 59.65. Sales policies filed with the Commission.
Each major jurisdictional utility, as defined in § 59.61 (Reserved), shall file with the Commission a statement of its gas sales policy. When the policy is changed, supplements shall be filed with the Commission indicating the nature and date of the change as well as the justification for it.
§ 59.66. [Reserved].
Source The provisions of this § 59.66 amended July 23, 1993, effective July 24, 1993, 23 Pa.B. 3472. Immediately preceding text appears at serial page (107935).
§ 59.67. [Reserved].
Source The provisions of this § 59.67 amended November 16, 1979, effective November 17, 1979, 9 Pa.B. 3799; reserved March 22, 1996, effective March 23, 1996, 26 Pa.B. 1265. Immediately preceding text appears at serial pages (196688) to (196689), (107937) to (107940) and (116311).
GAS EMERGENCY PLANS
§ 59.71. Definitions.
The following words and terms, when used in this section and in § § 59.72—59.75, have the following meanings, unless the text clearly indicates otherwise:
Alternate fuel—Any fuel other than natural gas.
Alternate fuel capability—The installed and operable ability to use any fuel other than natural gas on a time sensitive basis.
Commercial use—Gas usage by customers engaged primarily in the sale of goods and services including consumption by office buildings, institutions and government agencies.
Essential human needs use—Gas usage in any building where persons normally dwell including residences, apartment houses, dormitories, hotels, hospitals and nursing homes.
Firm service—Natural gas service offered to consumers under tariffs or contracts that anticipate no interruption.
Industrial use—Gas usage by customers engaged primarily in a process which creates or changes raw or unfinished materials into another form or product including the generation of electric power.
Interruptible service—Natural gas services that can be temporarily discontinued under terms and conditions specified by tariff or contract.
NGDC—Natural gas distribution company.
NGS—Natural gas supplier.
Plant protection use—Minimum usage of natural gas required to prevent physical harm to an industrial or commercial consumer’s facility, or danger to personnel at the facility, when the protection cannot be afforded through the use of an alternate fuel. Plant protection use includes usage necessary for the protection of the material in process as would otherwise be destroyed, but does not include deliveries required to maintain production.
Residential use—Gas usage in a residential dwelling or unit for space heating, air conditioning, cooking, water heating or other domestic purpose.
Authority The provisions of this § 59.71 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 2203(15) and 2208.
Source The provisions of this § 59.71 adopted December 14, 2001, effective December 15, 2001, 31 Pa.B. 6800.
Cross References This section cited in 52 Pa. Code § 59.74 (relating to utility liability).
§ 59.72. Natural gas emergency planning.
(a) By March 15, 2002, each NGDC shall file with the Commission a natural gas emergency plan reflecting its unique operational characteristics and design criteria. Each plan shall contain simplified and understandable rules and regulations so that all of the NGDC’s customers and all NGSs licensed to provide services to their customers can have a responsive action plan in place to protect themselves and their property in the event of a crisis. NGDCs shall file revisions to their plans when and as appropriate, or as directed by the Commission.
(b) As part of their emergency planning, NGDCs shall attempt to make every reasonable effort to make contractual or informal arrangements with their transportation customers, sales customers and others to obtain supplies or, as an alternative, to implement usage reductions, so that resorting to firm service reductions under § 59.73 (relating to emergency action) can be avoided, or the severity of supply or capacity disruption can be mitigated. The purpose of these arrangements is to provide a means to minimize the potential of supply shortfalls that threaten public health and safety, and not to make up for inadequate performance by individual parties.
(c) Each natural gas emergency plan shall include provisions addressing:
(1) Emergency load shedding.
(2) Voluntary usage reductions, for example, reducing space or water heating temperatures to levels specified by the NGDC.
(3) Mandatory usage reductions for certain customers consistent with § 59.73(c).
(4) Issuance of periodic reports to the media concerning the existing natural gas emergency.
(5) Notice to affected customers and NGSs of the expected initiation of emergency actions under § 59.73.
(6) Customer and NGS delivery requirements that apply during the term of emergency action under § 59.73, regardless of customer-specific usage reductions that arise or may arise from end-use curtailments.
(7) A procedure for focusing emergency measures to confined geographic or operational portions, segments or zones of the NGDC system where a natural gas emergency exists.
(8) Procedures for establishing communications with electric system control area operators, if the NGDC provides gas service to electric generation stations.
(d) Each natural gas emergency plan shall specify the procedures the NGDC shall use to provide notices to affected customers, their NGSs and NGDCs. After the NGDC determines the appropriate response, the NGDC shall issue notices to affected customers, their NGSs and NGDCs as soon as reasonably possible. All notices shall be prepared consistent with the Commission’s plain language policy. Notice to the public concerning usage reductions shall be designed to avoid confusion in geographical areas served by more than one NGDC.
Authority The provisions of this § 59.72 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 2203(15) and 2208.
Source The provisions of this § 59.72 adopted December 14, 2001, effective December 15, 2001, 31 Pa.B. 6800.
Cross References This section cited in 52 Pa. Code § 59.71 (relating to definitions); and 52 Pa. Code § 59.74 (relating to utility liability).
§ 59.73. Emergency action.
(a) An emergency exists whenever the aggregate demand of firm service customers on an NGDC’s system or confined segment of the system exceeds or threatens to exceed the gas supply or capacity that is actually and lawfully available to the NGDC to meet the demands, and the actual or threatened excess creates an immediate threat to the NGDC’s system operating integrity with respect to Priority 1 customers as defined in subsection (i).
(b) If, in the sole judgement of the NGDC, there is sufficient time, the NGDC shall use reasonable business and operational efforts to: interrupt all interruptible services, issue operational flow orders, and call for voluntary usage reductions by all customers before taking any action under subsection (c). The NGDC shall take these three actions sequentially to the extent feasible.
(c) In the event of an emergency under subsection (a), the NGDC may require each commercial and industrial retail and transportation customer that is not a Priority 1 customer under subsection (i) to reduce its consumption of gas.
(1) The reduction required shall be determined by the utility without regard to priorities of use, as necessary to minimize the potential threat to public health and safety.
(2) The minimum authorized usage may not be lower than the minimum usage of firm service necessary for plant protection use.
(3) When all other service has been curtailed except for Priority 1 service and the NGDC continues to be unable to meet Priority 1 requirements, the NGDC shall exercise its judgment as to any further curtailment that may be necessary and shall utilize measures designed to minimize harm to customers if curtailments to plant protection use are found to be necessary.
(4) Consistent with its responsibility to maintain system integrity at all times, the NGDC shall restore service as soon as practicable to any gas-fired electric generation facility that is deemed critical to electric system reliability by the electrical system’s control area operator.
(d) Mandatory reductions under subsection (c) shall be for a period specified by the NGDC until further notice. The NGDC may change a customer’s authorized usage, upon notice, at any time during an emergency.
(e) Mandatory reductions under subsection (c) shall be for a maximum duration of 5 business days unless extended by Commission order. As an alternative to extending mandatory reductions under subsection (c), the Commission may order the NGDC to initiate priority-based curtailments under subsection (f).
(f) In determining whether to order the NGDC to initiate priority-based curtailments, the Commission will examine whether the NGDC did the following:
(1) Interrupted all interruptible services.
(2) Issued operational flow orders.
(3) Called for voluntary usage reductions by all customers.
(g) Upon issuance of an order to initiate priority-based curtailments, the NGDC shall provide all affected customers the maximum notice possible, by means of telephone, fax or electronic data interchange, specifying the curtailment percentage of the customer’s firm gas service and resulting allowance as may be the case.
(h) Upon issuance of an order to initiate priority-based curtailments, the available gas supplies to the NGDC shall be prorated, if practicable, among its customers according to the following priorities of use:
(1) Customers in a higher priority category will not be curtailed until all customers falling into a lower priority category have been restricted to plant protection use levels, unless operational circumstances or physical limitations warrant a different result.
(2) Where only a partial restriction of a classification is required, implementation shall be pro rata, to the extent practical under the circumstances, as set forth in the NGDC’s tariff.
(i) Following are the priority categories, listed in descending order, pertaining to the curtailment of firm services:
(1) Priority 1. Service for essential human needs use.
(2) Priority 2. Firm services not included in essential human needs use.
(j) As part of its natural gas emergency plan, an NGDC may divide any or all of the priority of use categories in subsection (i) into subcategories.
Authority The provisions of this § 59.73 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 2203(15) and 2208.
Source The provisions of this § 59.73 adopted December 14, 2001, effective December 15, 2001, 31 Pa.B. 6800.
Cross References This section cited in 52 Pa. Code § 59.71 (relating to definitions); 52 Pa. Code § 59.72 (relating to natural gas emergency planning); and 52 Pa. Code § 59.74 (relating to utility liability).
§ 59.74. Utility liability.
(a) Each NGDC may restrict or discontinue service in accordance with this section and § § 59.71—59.73 and 59.75 without thereby incurring any penalty or liability for any loss, injury or expense that may be sustained by the customer except when the restriction or discontinuation of service is as a result of the NGDC’s willful or wanton misconduct.
(b) NGDC liability for actions taken under § 59.73 (relating to emergency action), or to a regulation, policy statement, directive or order issued by the Commission or an emergency order issued by the Governor shall be governed by the following principles:
(1) If an NGDC appropriates natural gas during an emergency action, the NGDC shall compensate the applicable entity, whether the customer or the customer’s NGS, for the cost of lost, firm gas service. The compensation, in the aggregate, shall equal but not exceed the greater of: the city gate cost of the appropriated natural gas, including transportation charges up to the NGDC’s city gate, or the reasonable cost actually paid by the customer for delivered substitute energy, as documented to the NGDC. NGDCs may provide compensation in kind only at the discretion of the affected customer or NGS.
(2) The NGDC may discontinue service, for the duration of an emergency, to a customer that continues to take gas in violation of the rules found in this subchapter.
Authority The provisions of this § 59.74 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 2203(15) and 2208.
Source The provisions of this § 59.74 adopted December 14, 2001, effective December 15, 2001, 31 Pa.B. 6800.
Cross References This section cited in 52 Pa. Code § 59.71 (relating to definitions).
§ 59.75. Penalties for unauthorized takes.
The tariff, operating practices, and billing periods of the NGDCs and their suppliers differ significantly. Therefore, each NGDC is permitted to utilize its own appropriate billing periods for calculating pipeline transportation, storage service, and balancing or other penalties and its own tariffed procedure for imposing those penalties on customers who take gas service and NGSs who operate in a manner that is contrary to the rules and regulations of this chapter.
Authority The provisions of this § 59.75 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 2203(15) and 2208.
Source The provisions of this § 59.75 adopted December 14, 2001, effective December 15, 2001, 31 Pa.B. 6800.
Cross References This section cited in 52 Pa. Code § 59.71 (relating to definitions); and 52 Pa. Code § 59.74 (relating to utility liability).
ANNUAL RESOURCE PLANNING REPORT
Authority The provisions of these § § 59.81—59.84 issued under the Public Utility Code, 66 Pa.C.S. § § 308(c), 501, 504, 523, 1319 and 1501, unless otherwise noted.
Source The provisions of these § § 59.81—59.84 adopted March 22, 1996, effective March 23, 1996, 26 Pa.B. 1265, unless otherwise noted.
§ 59.81. Periodic reporting requirements for major gas utilities.
(a) For the purposes of this subchapter, each jurisdictional public utility with sales of 8 billion cubic feet per year or more including transportation volume shall submit to the Commission an annual integrated resource planning report. Except for Form 1A/2A, whose filing date is March 1, an original copy of the report shall be submitted on or before June 1, 1996, and June 1 of successive years. This report shall include a plan that includes the past year’s historical data, program changes, and the next 3-year forecast. One copy of the report shall also be submitted to the Office of Consumer Advocate, the Office of Small Business Advocate and the Bureau of Investigation and Enforcement. The information contained within the report shall conform to the following requirements:
(1) The name and telephone number of persons having knowledge of the matters, and to whom inquiries should be addressed.
(2) A forecast of annual and peak day energy demand requirements in million cubic feet displayed by component parts, as indicated in Form-IRP-Gas-1A and Form-IRP-Gas-lB. The load growth projections shall reflect the effects of price elasticity, market-induced conservation, building and appliance efficiency standards and the effects of the utility’s existing and planned conservation and load management activities.
(3) A forecast of annual and peak day energy supply resources in million cubic feet indicating sources of presently available and new supplies which the utility estimates will become available displayed by component parts, as indicated in Form-IRP-Gas-2A, a list of contracts for gas transportation, to the reporting utility’s city gate, upstream of the city gate and related to transportation as indicated in Form-IRP-Gas-2B and a list of contracts for gas storage services provided to the reporting utility, as indicated in Form-IRP-Gas-2C.
(4) A forecast of the number of customers (year end) displayed by component parts, as indicated in Form-IRP-Gas-3.
(5) A summary forecast of annual and peak day energy supply resources and demand requirements in million cubic feet, as indicated in Form-IRP-Gas-4A and Form-IRP-Gas-4B.
(6) The data required under paragraphs (1)—(5) shall consist of the past 2 years actual historical data, the current year (both actual and projected) and a 3-year forecast. For the purpose of this section, the term “current year” refers to the year in which the filing is being made.
(7) A detailed discussion of the methodologies, data sources and assumptions used in preparing the information required by this section shall be included.
(b) The reporting formats referred to in this section are contained in § 59.84 (relating to formats). Annual data shall be submitted on a calendar year basis, January 1 through December 31. If the utility purchases gas on a contract basis other than a calendar year, the contract time interval shall be identified.
(c) Annual integrated resource planning reports submitted under subsection (a) shall be accompanied by a summary suitable for public distribution. The summary shall include an implementation plan specifying activities scheduled for the acquisition and development of the resources delineated in the report, which are to take place during the planning period. Utilities shall maintain copies of the summary open for public inspection during normal business hours.
(d) Informal sessions may be scheduled for reviewing integrated resource plans and providing an opportunity for interested parties to participate in the review process.
Authority The provisions of this § 59.81 amended under the Public Utility Code, 66 Pa.C.S. § § 501, 504, 523, 1301, 1501 and 1504.
Source The provisions of this § 59.81 amended June 23, 2000, effective June 24, 2000, 30 Pa.B. 3172; amended January 10, 2014, effective January 11, 2014, 44 Pa.B. 249. Immediately preceding text appears at serial pages (285478) and (267665).
Cross References This section cited in 52 Pa. Code § 59.82 (relating to Annual Conservation Report).
§ 59.82. Annual Conservation Report.
(a) For purposes of this subchapter, each jurisdictional gas utility with sales of 8 billion cubic feet per year or more including transportation volume, shall submit its Annual Conservation Activities Report and incorporate it with the reporting requirements found at § 59.81(a) (relating to periodic reporting requirements for major gas utilities) on or before June 1 of each year except for Form 1 which is due March 1. The report shall contain a description of conservation and load management programs implemented or operational during the past calendar year and programs which are proposed to be implemented within 1 year following the filing of the report.
(1) A conservation program shall include a method designed to produce a reduction in total annual energy use, regardless of its effect on peak demand.
(2) A load management program shall include a method to reduce the peak or maximum load or demand, with little or no change in total annual energy use.
(b) The description shall conform to the Form-IRP-Gas-5 and shall contain:
(1) A descriptive title of the program.
(2) The purpose or objective.
(3) The details of program activity and implementation schedule.
(4) An accounting of the monetary and personnel resources actually or proposed to be expended or devoted to the program.
(5) The actual or anticipated results of the program in terms of energy savings, reduction of utility on peak demand or other appropriate measure of the program’s objective.
(c) The report shall also contain, for each class or type of energy user the number of customers in each class as of the end of the previous year, the total energy consumed by each class and the individual target consumption reductions for each class, as indicated on Form-IRP-Gas-6.
(d) The report shall include a summary of programs, as indicated on Form-IRP-Gas-7.
(e) For each program with an annual utility expenditure of more than $100,000 or more than 0.1% of total annual revenue, whichever is less, excepting informational, educational or research and development programs, the utility shall submit a cost-benefit analysis using the common evaluation methodology in § 59.83 (relating to evaluation methodology), as indicated on Forms-IRP-Gas-8 and IRP-Gas-9.
(f) The Commission, through its Bureau of Conservation, Economics and Energy Planning, may issue a list of specific conservation and load management programs which shall be considered for implementation by each designated utility. The utility shall provide information documenting the consideration of these and other conservation and load management options and supporting the utility’s decision of whether or not to implement the options.
(g) Utilities shall maintain copies of the annual conservation reports open to public inspection during normal business hours. Customers shall be notified, in writing, of the availability of the reports for public inspection. Notification may be included with customers’ monthly bills.
(h) The following forms have been provided for under this chapter as a format to be used in preparing the annual conservation report:
(1) Form-IRP-Gas-5—Program Description.
(2) Form-IRP-Gas-6—Energy Users.
(3) Form-IRP-Gas-7—Program Summary.
(4) Form-IRP-Gas-8—Cost-Benefit Analysis Inputs.
(5) Form-IRP-Gas-9—Cost-Benefit Analysis Results.
§ 59.83. Evaluation methodology.
For purposes of this subchapter, each jurisdictional utility with sales of 8 billion cubic feet per year or more including transportation volume, shall utilize benefit-cost methodologies as prescribed by the Bureau of Conservation, Economics and Energy Planning to evaluate the costs and benefits of conservation and load management programs, and demand-side management programs. The cost-benefit methodologies shall be utilized by the utility during the next program year after they are prescribed.
Cross References This section cited in 52 Pa. Code § 59.82 (relating to Annual Conservation Report).
§ 59.84. Formats.
In preparing the annual integrated resource planning reports required by § 59.81(a) (relating to periodic reporting requirements for major gas utilities), each jurisdictional utility shall use the forms and schedules specified by the Bureau of Conservation, Economics and Energy Planning, which shall include the following:
(1) Form-IRP-Gas-lA—Annual Gas Demand Requirements; Form-IRP-Gas-1B—Peak Day Gas Requirements.
(2) Form-IRP-Gas-2A—Natural Gas Supply; Form-IRP-Gas-2B—Natural Gas Transportation; Form-IRP-Gas-2C—Natural Gas Storage.
(3) Form-IRP-Gas-3—Number of Customers (Year End).
(4) Form-IRP-Gas-4A—Annual Supply and Demand Requirements Summary; Form-IRP-Gas-4B—Peak Day Supply and Demand Requirements Summary.
(5) Form-IRP-Gas-5—Program Description.
(6) Form-IRP-Gas-6—Energy Users.
(7) Form-IRP-Gas-7—Program Summary.
(8) Form-IRP-Gas-8—Cost-Benefit Analysis Inputs.
(9) Form-IRP-Gas-9—Cost-Benefit Analysis Results.
Source The provisions of this § 59.84 amended June 23, 2000, effective June 24, 2000, 30 Pa.B. 3172. Immediately preceding text appears at serial pages (246441) to (246442).
Cross References This section cited in 52 Pa. Code § 59.81 (relating to periodic reporting requirements for major gas utilities).
STANDARDS FOR CHANGING A CUSTOMER’S NATURAL GAS SUPPLIER
§ 59.91. Definitions.
The following words and terms, when used in this section and § § 59.92—59.99, have the following meanings, unless the context clearly indicates otherwise:
Customer—A retail gas customer as defined by 66 Pa.C.S. § 2202 (relating to definitions). The term includes all persons identified by the NGDC ratepayer of record, under § 59.95 (relating to persons authorized to act on behalf of a customer), as authorized to act on behalf of the NGDC ratepayer of record in changing the NGS for the account.
Data element—One or more characters that represent numeric or alphanumeric fields of data.
NGDC—Natural Gas Distribution Company—An NGDC as defined by 66 Pa.C.S. § 2202.
NGS—Natural gas supplier—A supplier as defined by 66 Pa.C.S. § 2202.
Authority The provisions of this § 59.91 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.91 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline).
§ 59.92. Customer contacts with the NGDC.
When a customer orally contacts the NGDC to request a change of NGS, the NGDC shall notify the customer that the selected NGS shall be contacted directly to initiate the change.
Authority The provisions of this § 59.92 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.92 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline).
§ 59.93. Customer contacts with NGSs.
When a contact occurs between a customer and an NGS to request a change of the NGS, upon receiving direct oral confirmation or written authorization from the customer to change the NGS, the customer’s new NGS shall:
(1) Notify the NGDC of the customer’s NGS selection by the end of the next business day following completion of the application process. The NGDC shall verify the accuracy of the information provided by the NGS by matching at least two data elements such as name and account number, or address and account number, with NGDC records.
(2) Upon receipt of this notification, the NGDC shall send the NGDC ratepayer of record a confirmation letter noting the proposed change of NGS. This letter shall include notice of a 10-day waiting period in which the order may be canceled before the change of the NGS takes place. The notice shall include the date service with the new NGS will begin unless the customer contacts the NGDC to cancel the change. The 10-day waiting period shall begin on the day the letter is mailed. The letter shall be mailed by the end of the next business day following the receipt of the notification of the customer’s selection of a NGS.
Authority The provisions of this § 59.93 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.93 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline).
§ 59.94. Time frame requirement.
When a customer has provided the NGS with oral confirmation or written authorization to change NGSs, the NGDC shall make the change at the beginning of the first feasible billing period following the 10-day waiting period, as prescribed in § 59.93 (relating to customer contacts with NGSs).
Authority The provisions of this § 59.94 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.94 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline).
§ 59.95. Persons authorized to act on behalf of a customer.
A customer may identify persons authorized to make changes to the customer’s account. To accomplish this, the customer shall provide the NGDC with a signed document identifying by name those persons who have the authority to initiate a change of the customer’s NGS.
Authority The provisions of this § 59.95 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.95 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline).
§ 59.96. Valid written authorization.
A document signed by the customer whose sole purpose is to obtain the customer’s consent to change NGSs shall be accepted as valid and result in the initiation of the customer’s request. Documents not considered as valid include canceled checks, signed entries into contests and documents used to claim prizes won in contests.
Authority The provisions of this § 59.96 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.96 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline).
§ 59.97. Customer dispute procedures.
(a) When a customer contacts an NGDC or an NGS and alleges that the customer’s NGS has been changed without consent, the company contacted shall:
(1) Consider the matter a customer registered dispute.
(2) Investigate and respond to the dispute consistent with the requirements in § § 56.151 and 56.152 (relating to utility company dispute procedures).
(b) When the customer’s dispute has been filed within the first two billing periods since the customer should reasonably have known of a change of NGSs and the dispute investigation establishes that the change occurred without the customer’s consent, the customer is not responsible for NGS charges rendered during that period. If the customer has made payments during this period, the company responsible for initiating the change of supplier shall issue a complete refund within 30 days of the close of the dispute. The refund or credit provision applies only to the natural gas supply charges.
(c) A customer who has had a NGS changed without having consented to that change shall be switched back to the original NGS for no additional fee. Charges involved in the switch back to the prior NGS shall be the responsibility of the company that initiated the change without the customer’s consent.
(d) If a customer files an informal complaint with the Commission alleging that the customer’s NGS was changed without the customer’s consent, the Bureau of Consumer Services will issue an informal decision that includes a determination of customer liability for any NGS bills or administrative charges that might otherwise apply, rendered since the change of the NGS.
(e) In addition to customer-specific remedies, the Commission may, after investigation and decision, assess fines under 66 Pa.C.S. Chapter 33 (relating to violations and penalties), and initiate proceedings to revoke the license of any NGS that demonstrates a pattern of violating this chapter. The Commission may order a particular NGS that has a pattern of violating this chapter to obtain written authorization from every new customer as a condition of providing service in this Commonwealth. Nothing in this section limits the Commission’s authority.
Authority The provisions of this § 59.97 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.97 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline); 52 Pa. Code § 111.7 (relating to customer authorization to transfer account; transaction; verification; documentation); and 52 Pa. Code § 111.13 (relating to customer complaints).
§ 59.98. Provider of last resort.
Sections 59.91—59.99 do not apply in instances when the customer’s service is discontinued by the NGS and subsequently provided by the provider of last resort because no other NGS is willing to provide service to the customer.
Authority The provisions of this § 59.98 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.98 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline).
§ 59.99. Record maintenance.
Each NGDC and each NGS shall preserve all records relating to unauthorized change of NGS disputes for 3 years from the date the customers filed the disputes. These records shall be made available to the Commission or its staff upon request.
Authority The provisions of this § 59.99 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504—506, 1301 and 1501.
Source The provisions of this § 59.99 adopted July 7, 2000, effective July 8, 2000, 30 Pa.B. 3451.
Cross References This section cited in 52 Pa. Code § 111.6 (relating to discipline).
UNACCOUNTED-FOR-GAS
§ 59.111. Unaccounted-for-gas.
(a) Definitions. The following words and terms, when used in this section, have the following meanings, unless the text clearly indicates otherwise:
Adjustments—Gas used by an NGDC or city natural gas distribution operation for safe and reliable service, such as company use, calculable losses from construction, purging, storage migration, other temperature and pressure adjustments, and adjustments for heat content of natural gas.
Gas delivered—Gas provided by the distribution, transmission, storage or production/gathering facilities of an NGDC or city natural gas distribution operation, regardless of use, adjusted for temperature or pressure variations. This category includes quantities of gas consumed by an end user, exchange gas supplied to another utility, gas delivered to transportation customers or other gas delivered to a user other than the utility. When bill timing issues arise, an effort shall be made to reasonably estimate consumption.
Gas received—Gas that is supplied to the distribution, transmission, storage or production/gathering facilities of an NGDC or city natural gas distribution operation, regardless of use, adjusted for temperature or pressure variations. This category includes gas for sales, storage, transportation quantities, exchange gas received or other quantity of gas that otherwise enters the utility’s facilities.
NGDC—Natural gas distribution company.
UFG—Unaccounted-for-gas—The difference between the total gas available from all sources and the total gas accounted for as sales, net interchange and company use. This difference includes leakage or other actual losses, discrepancies due to meter inaccuracies, variations of temperatures or pressures, or both, and other variants, particularly billing lag.(b) Calculation.
(1) UFGx = Gas Receivedx - Gas Deliveredx - Adjustmentsx
(2) %UFGx = (UFGx/Gas Received) * 100
(3) X denotes the system type (distribution, transmission, storage or production/gathering). When possible, UFG must be computed and reported by system type.
(4) Gas received, gas delivered and adjustments must represent actual gas quantities. Estimates may be provided but must be clearly identified and have supporting justification, assumptions and calculations.
(5) Adjustments must be individually identified by category (such as company use, calculable losses from construction, purging, storage migration, other temperature and pressure adjustments, and adjustments for heat content of natural gas). Adjustments must be supported by metered data, sound engineering practices or other quantifiable results that clearly support the utility’s need for the adjustment. Adjustments must be consistent from filing to filing.
(6) The definition of ‘‘UFG’’ in subsection (a) and the calculation under this subsection apply to UFG filed with the Commission.
(c) Metrics for distribution system losses.
(1) Each NGDC and city natural gas distribution operation shall, at a minimum, reduce distribution system loss performance in accordance with the metrics in the following table, beginning with its first subsequent Purchased Gas Cost (PGC) or Gas Cost Rate (GCR) filing after August 11, 2014. The metric starts with 5% in the first year and decreases by 0.5% every year in the subsequent years until it reaches 3% as shown in the following table:
Year Percent UFG 1 5.00% 2 4.50% 3 4.00% 4 3.50% 5 3.00% (2) The distribution metrics shall be applied on an annual basis for the 12 months ending August 31. UFG reports, as described by the Commission and relating to this section, shall be filed by September 30th of each year.
(3) UFG levels above the applicable annual targets in paragraph (1) shall be presumed to be excessive absent evidence to the contrary and may not be recovered within the current or a future PGC or GCR filing. If an NGDC’s actual UFG exceeds an applicable target, the NGDC may demonstrate that its level of UFG is warranted.
Authority The provisions of this § 59.111 issued under the Public Utility Code, 66 Pa.C.S. § § 501, 504, 523, 1301, 1501 and 1504.
Source The provisions of this § 59.111 adopted August 9, 2013, effective August 10, 2013, 43 Pa.B. 4586.
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