PSC 113.0607(2)(b)1.a.a. The plan under sub. (1) shall include a schedule for the periodic inspection of all facilities owned and operated by the utility and used to provide electric service to its customers. The plan under sub. (1) shall describe the method for inspection of each type of equipment as designated by the reporting utility. Checklist/report forms shall be included in the plan under sub. (1). PSC 113.0607(2)(b)1.b.b. The plan under sub. (1) shall include guidelines for inspectors to determine the condition of a facility or piece of equipment. PSC 113.0607(2)(b)2.2. Condition rating criteria. A rating criteria shall be established to grade the condition of a facility or piece of equipment. Rating criteria for generating facilities should conform to generator availability data system (GADS) requirements as reported to the national electric reliability council, or other accepted industry practices. PSC 113.0607(2)(b)3.3. Corrective action schedule. The results of inspections, assessments and condition rating criteria shall be used to define the schedule for implementing maintenance on the facility or piece of equipment. The plan under sub. (1) shall describe how facilities or equipment corrective action schedules are added to the utility’s budget. PSC 113.0607(2)(b)4.4. Record keeping. Each utility shall maintain records to allow auditing of its preventative maintenance plan implementation. The records shall include inspection dates, condition rating, schedule for repair (if applicable) and the date of completion of the repair. Inspection and repair records shall be retained for a minimum of ten years. PSC 113.0607(2)(b)5.5. Filing of plans. Each utility, as well as the transmission company created by s. 196.485, Stats., shall file a plan in compliance with this rule within 180 days of acceptance of the rules or, in the alternative, within 180 days after the utility transmission company or other person subject to this chapter begins operation of a facility subject to this chapter. PSC 113.0607(2)(b)6.6. Reporting requirements. Each utility shall provide a periodic report to the commission showing compliance with its preventative maintenance plan. The report shall include a list of inspected circuits and facilities, the condition of facilities according to established rating criteria, schedules established and success at meeting the established schedules. For generation facilities, the report shall include a summary of each generating unit’s operating performance statistics based on the utility’s GADS data, or other accepted industry data convention. Reported generating unit performance data shall include net dependable capacity, capacity factor, forced outage rate, scheduled outage factor, primary fuel and production technology type. The commission shall establish a periodic report schedule for each utility of at least once every 2 years. PSC 113.0607(2)(b)7.7. Exchange of information. At least annually, utilities shall exchange planned outage information for the coming year for expected maintenance and other outages of generators of 50 MW or more and transmissions lines of 100 kV and higher voltage. Utilities shall also supply the same information for nonutility generators of 50 MW or more in their control areas. Utilities shall exchange updates of such information as soon as reasonably practicable when such updated information becomes known. PSC 113.0607 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00; CR 02-027: am. (2) (a), (b) 1. a. and b. 2. and 3., and (2) (b) 6., Register December 2002 No. 564, eff. 1-1-03. PSC 113.0608PSC 113.0608 Emergency response. Each utility with 25,000 customers or more shall establish procedures to record and monitor its response times for emergencies, such as calls for assistance from police, fire, emergency medical services officials and any calls or reports of wire contacts, dig-ins, wires down, utility facilities on fire, unauthorized entry into utility facilities, unsecured public access to energized equipment, or any similar activity on or near utility facilities constituting a hazardous condition or an immediate threat or danger to persons, customers’ property, customers business operations or general property. In general, the records of these calls should include the date and time received; the identity (if known) of the caller; the identity of the person receiving the call; the location and nature of the problem, incident, or accident; the time the utility responder arrived at the location; the total time to respond; and the final disposition or resolution of the problem. PSC 113.0608 NoteNote: It is recognized that strict compliance with this rule may be difficult during major system-wide or large area emergencies, for example, major wind or ice storms where many outage reports may also involve reports of “wires down.” However, reasonable efforts should still be made to identify and give priority response to calls for assistance from police and fire officials who may be “first responders.” This will allow these locations to be secured so the police or fire units can be released to pursue other duties.
PSC 113.0608 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0609(1)(1) Using methods approved by the commission, each municipally owned electric public utility and each investor-owned utility with a customer count of 20,000 or less, as directed by the commission where there is cause to do so, and each investor-owned electric public utility with a customer count greater than 20,000, on an annual basis, shall fund quantitative assessments, made by an independent entity, of the satisfaction of all customer classes with the services they have received from the utility. The results of these assessments shall be filed with the commission. The utility shall provide to the commission a detailed report of the information from any research it has conducted in the past year to help assess: PSC 113.0609(1)(a)(a) The satisfaction of the utility’s customers with the services they have received from the utility. PSC 113.0609(1)(b)(b) The specific new services or alterations to existing services desired by customers. PSC 113.0609(2)(2) This information shall at a minimum include the following: PSC 113.0609(2)(a)(a) A detailed description of the methods used to conduct the research and analyze the results. PSC 113.0609(2)(b)(b) The results of the research, including mean scores for all variables studied, both for the study sample as a whole and for meaningful sample subgroups. PSC 113.0609 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00; CR 02-027: am. (1) (intro.), Register December 2002 No. 564, eff. 1-1-03. PSC 113.0610(1)(1) Each utility shall investigate and keep a record of complaints received by it from its customers in regard to safety, service, or rates and the operation of its system with appropriate response times designated for critical safety and monetary loss situations. The record shall show the name and address of the complainant, the date and nature of the complaint, the priority assigned to the assistance and its disposition and the time and date thereof. PSC 113.0610(2)(2) Each utility also shall document all contacts and action relative to deferred payment agreements and disputes. PSC 113.0610 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0611PSC 113.0611 Employees authorized to enter customers’ premises. The utility shall keep a record of employees authorized pursuant to s. 196.171, Stats., to enter customers’ premises. PSC 113.0611 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0612PSC 113.0612 Employee safety. Each public utility subject to the accident reporting requirements of OSHA shall provide a safety performance report annually to the commission at the same time it is submitted to OSHA. The report shall include the OSHA Incidence Rate and Lost Time Rate. The report shall also include the last 3 years’ average for each of these rates. PSC 113.0612 NoteNote: Also see ch. PSC 104, Recording and Reporting Utility Accidents. PSC 113.0612 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0613PSC 113.0613 Maps and diagrams. Each utility shall have record systems (maps, records, diagrams, drawings or computer display systems) showing the location of its property, in sufficient detail so that the adequacy of service to existing customers may be checked and facilities located. PSC 113.0613 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0614PSC 113.0614 Preservation of records. A utility shall preserve the following records in a readable format and keep them available for inspection by the commission for the periods indicated. The list is not a complete list of all types of utility records. PSC 113.0614 NoteNote: See also “Investigation to Consider Proposed Changes to Records Retention Requirements for Electric, Gas and Water Utilities” adopted by the commission in docket 5-US-114, December 12, 2006, as amended March 19, 2009, for a more comprehensive listing of retention periods of specific records.
PSC 113.0614 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00; CR 13-033: am. Register July 2015 No. 715, eff. 8-1-15. PSC 113.0615PSC 113.0615 Inventory of conductors. Each utility shall maintain an inventory of Copperweld conductor, sizes 6A and smaller that is more than 50 years old (as of January 1, 1998). The inventory shall include the amount of such conductor by size and age and its location as needed in the distribution system. Each utility shall submit its inventory to the public service commission every four years until all of this conductor is retired and removed from service. PSC 113.0615 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0701(1)(1) “Flicker” or “voltage flicker” means a variation of input voltage sufficient in duration to allow visual observation of a change in electric light intensity. PSC 113.0701(2)(2) “Harmonic distortion” means the mathematical representation of the distortion of the pure sine waveform. Distortion of the pure sine waveform is typically caused by loads that draw current discontinuously or whose impedance varies during the cycle of the input ac voltage waveform. PSC 113.0701(3)(3) “Point of service” means the connection point between the customer electrical system and the utility electrical system. PSC 113.0701(4)(4) “Power quality” means the concept of powering and grounding sensitive electronic equipment in a manner that is suitable to the operation of that equipment. PSC 113.0701(5)(5) “Retail power service” means service furnished principally for electromotive or industrial purposes and may include service for lighting incidental thereto, as defined in the utility’s rates and rules. PSC 113.0701(6)(6) “Sag” means an rms reduction in the ac voltage, at the power frequency, for durations from a half-cycle to a few seconds. PSC 113.0701(7)(7) “Swell” means an rms increase in the ac voltage, at the power frequency, for durations from a half-cycle to a few seconds. PSC 113.0701(8)(8) “Transient” means a subcycle disturbance in the ac waveform that is evidenced by a sharp but brief discontinuity of the wave form. A transient may be of either polarity and may be additive to or subtractive from the nominal waveform. PSC 113.0701 NoteNote: The definitions used in subsections (1), (2), (4), (7), and (8) are based on the definitions in Authoritative Dictionary of IEEE Standards Terms-7th Ed.
PSC 113.0701(9)(9) “Steady state voltage” means the rms voltage after all sags, swells and transients have decayed to a negligible value. PSC 113.0701(10)(10) “Service voltage” means the steady state voltage at the point of service. PSC 113.0701 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00; correction in (intro.) made under s. 13.93 (2m) (b) 7., Stats., Register, January, 2001, No. 541; CR 02-027: am. (1), (2), (4) and (6) to (8), Register December 2002 No. 564, eff. 1-1-03. PSC 113.0702PSC 113.0702 Standard and maintenance of a service voltage. Each utility shall adopt standard nominal service voltages for each of the several areas into which the distribution system or systems may be divided and shall file with the commission a statement of the standard voltages adopted. The service voltage shall be reasonably constant within the following limits: PSC 113.0702(1)(1) For all retail service, except retail power service, the service voltage shall not vary by more than 5% above or below the standard voltage. PSC 113.0702(2)(2) For retail power service furnished to customers having demands of 500 kilowatts or less, the service voltage shall be no more than 5% above or 10% below the standard nominal voltage. PSC 113.0702(3)(3) For retail power service furnished to customers having demands of more than 500 kilowatts, the service voltage shall not vary by more than 10% above or 10% below the standard nominal voltage. PSC 113.0702(4)(4) For polyphase voltage unbalance issues, ANSI C.84.1-1989 Appendix D is the reference that will be followed. The utility and its customers may agree to not be constrained to the reference if it is economically beneficial to the customer. PSC 113.0702(5)(5) For service rendered to public utilities and others for resale the standard nominal voltage shall be as mutually agreed upon by the parties concerned. If no formal agreement exists, the standard nominal voltage shall vary by no more than 10% above or below the secondary nominal voltage. PSC 113.0702(6)(6) The variation in service voltage referred to in subs. (1) to (3) inclusive shall refer to a steady state voltage. PSC 113.0702(7)(7) Upon customer request, the utility shall investigate line voltage variations and disturbances, associated with voltage sags, swells and transients, at the point of service. Requests for tests may be limited in availability, number or frequency for the same customer at the same location where previous tests have indicated that the variations and disturbances are within acceptable industry limits. The utility may establish rules for certain customers to decrease the incidents of these variations and disturbances as seen by other customers. PSC 113.0702 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0703(1)(1) Service interruptions, or voltage sags, swells and transients caused by the action of the elements, temporary separation of parts of the system from the main system, infrequent or unavoidable fluctuations of short duration, equipment failure, normal system operations necessary operations to safeguard employees or the general public, or other causes beyond the control of the utility shall not be considered a violation of these rules. PSC 113.0703 NoteNote: Voltage fluctuations, transients, sags and swells may affect the performance of certain types of equipment or operations and should be considered by the customer. Customers having equipment or operations that are sensitive to such voltage fluctuations, or that require service other than that specified by these rules may find it necessary to install, at their own expense, power conditioning equipment or other modifications to protect, mitigate or otherwise provide the type of service needed.
PSC 113.0703(2)(2) In order to limit the impact of voltage variations, utilities may establish starting and operating criteria for equipment on customer premises. Customer loads shall be sized and operated in accordance with such criteria. PSC 113.0703(3)(3) If procedures for voltage reduction during emergency operating conditions have been filed with and accepted or approved by the commission, variations of voltage in excess of those specified in ss. PSC 113.0702 and 113.0703, resulting from implementation in accordance with the specified procedures, shall not be considered a violation of these rules. PSC 113.0703 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0704PSC 113.0704 Harmonics of 60 Hz voltage waves. Utilities shall make reasonable efforts to investigate equipment operating problems suspected to be associated with harmonic distortion of the 60 Hz voltage sinewave at the point of service. When the source of the harmonic distortion is determined to be equipment operated by a specific customer, the utility shall notify the customer and it shall be the customer’s responsibility to correct the problem. When corrective action is necessary, the guideline to be used is the 1992 IEEE Standard 519. PSC 113.0704 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0705(1)(1) Each utility shall own or otherwise arrange to have available when needed, suitable monitoring equipment for surveying its system and the electrical system of its customers at the point of service for power quality problems; such as harmonic distortion, voltage sags and swells, transients and flicker; that may adversely affect or interfere with the overall adequacy of service to its customers. If the source of the power quality problem is determined to be equipment operated by a specific customer, the utility shall notify the customer and it shall be the customer’s responsibility to correct the problem. If the problem is caused by the utility delivery system operating outside the limits set forth in s. PSC 113.0702 the responsible utility shall correct the problem. PSC 113.0705(2)(2) The utility and the affected and/or offending customer shall cooperate as necessary to promptly investigate, diagnose and resolve power quality complaints and problems. The utility shall share the results of its investigation with the affected and/or offending customer. If a utility offers power quality correction or mitigation services or equipment through a non-regulated affiliate or otherwise as a non-utility service, it may advise the customer of this option, but shall disclose the non-utility nature of this offering and that the customer is not obligated to take such services from the utility or its affiliate. PSC 113.0705 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0706(1)(1) Each utility shall submit to a public service commission-approved calibration facility once each year a portable digital standard watthour meter and once each 2 years a portable digital indicating voltmeter or multimeter, unless waived by the commission under the provisions of s. PSC 113.0902 (1). Smaller Class C and D utilities, may be allowed to continue to use the older electromechanical portable watthour standard for a reasonable future time period, if so authorized by the commission. PSC 113.0706 NoteNote: The rapid movement to the newer fully-electronic digital watthour standards by the measurement industry has limited a laboratory’s ability to get replacement parts needed to maintain and calibrate the older electromechanical standards. All utilities have been advised of the need to acquire electronic/digital standards when it is reasonably feasible to replace the older obsolete electromechanical standards.
PSC 113.0706(2)(2) Each utility shall be equipped with or otherwise arrange to have available when needed, portable digital indicating and recording voltmeters having internal memory channels of an accuracy and quantity sufficient to make a determination that the service voltage supplied to their customers complies with the requirements set forth in ch. PSC 113. This instrument shall be maintained with an error no greater than 0.8% of full scale. PSC 113.0706 NoteNote: (1) Caution should be exercised in using digital meters in areas of high electrical fields such as in close proximity to substations, high voltage lines, transformers, regulators, etc., as unstable or erroneous readings may result.
PSC 113.0706 Note(2) Those utilities which operate standards laboratories will require primary or laboratory grade instruments of a higher accuracy class than required above.
PSC 113.0706(3)(3) Each recording voltmeter shall be checked with an indicating voltmeter when it is placed in operation and when it is removed, or periodically if the instrument is in a permanent location. Notations for each record shall indicate when the registration began (time and date) and when the record was ended, as well as indicate the point where the voltage was taken. For non-digital recorders, also include the results of the check with an indicating voltmeter. PSC 113.0706(4)(4) Utilities with more than 1,000 customers shall have or otherwise arrange to have available when needed, one or more digital recording voltmeters with the appropriate programs to measure both the quality and quantity of the voltage and currents at the point of service. The meters shall be capable of storing the test results in such a manner as the records could be reviewed via a personal computer-based system. PSC 113.0706(5)(5) Upon customer request each utility shall make a sufficient number of voltage measurements at the point of service to verify its compliance with these rules. These voltage records, unless replaced by more recent records, shall be available for inspection by the commission for a period of 2 years PSC 113.0706 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0707(1)(1) Each utility shall own or otherwise arrange to have available when needed, suitable monitoring equipment for surveying its lines and equipment for possible radio and/or television interference. PSC 113.0707(2)(2) Each utility shall establish and routinely utilize in the course of regular operation, means whereby the presence of radio and/or television interference may be detected. PSC 113.0707(3)(3) Each utility shall, upon notification or detection of the presence of radio and/or television interference, survey its lines and equipment for possible sources of radio and television interference. When significant interference is found, reasonable measures shall be taken to locate the source and, if on the utility’s system, to mitigate the interference. Where the magnitude and nature of the interference is found to be so small, intermittent or insignificant that it affects only a few customers or a particular, unique piece of customer equipment that may have limited capabilities to receive weak signals, it may be necessary to limit the utility’s responsibility for mitigation to reasonable, cost-effective measures. PSC 113.0707 NoteNote: In some cases, some interference from the utility’s system may be detected, but found to be insignificant and inconsequential for the majority of customers. Its elimination or mitigation may still not result in adequate reception of some signals. In many areas, radio or television reception of some transmissions is normally inadequate due to frequency, weak signal strength, high ambient noise, distance from the source, terrain or other obstacles beyond the utility’s control. The capabilities and limitations of the customer’s receiver should also be evaluated and considered in determining the nature, extent and cost of the utility’s mitigation activities. Also, other options may be available and more feasible, for example, applying the mitigation to the customer’s equipment or substitution of cable television (CATV) or digital satellite service for local antenna systems.
PSC 113.0707(4)(4) Where the source of interference is determined to be equipment owned by a specific customer, the customer shall be so advised and informed of his or her responsibility to correct the problem (see s. PSC 113.0201). PSC 113.0707 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00.
