PSC 113.0604(3)(a)(a) Route miles of electric distribution line reconstructed during the year. Separate totals for single- and three-phase circuits shall be provided. PSC 113.0604(3)(b)(b) Total route miles of electric distribution line in service at year’s end, segregated by voltage level. PSC 113.0604(3)(d)(d) The average number of calendar days a utility takes to install and energize service to a customer site once it is ready to receive service. A separate average shall be calculated for each month, including all extensions energized during the calendar month. PSC 113.0604(3)(e)(e) The total number of written and telephone customer complaints received in the areas of safety, customer billing, outages, power quality, customer property damage and other areas, by month filed. PSC 113.0604(3)(g)(g) Total annual projected and actual miles of distribution line tree trimmed. PSC 113.0604 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0605PSC 113.0605 Initial historical reliability performance report. PSC 113.0605(1)(1) Each electric utility with 100,000 customers or more that has historically used measures of system, operating area and circuit reliability performance, shall initially submit annual SAIFI, SAIDI and CAIDI data for the previous three years. Those utilities that have this data for some time period less than three years shall submit data for those years it is available. PSC 113.0605(2)(2) Those utilities whose historical reliability performance data is similar or related to those measures defined above, but differs due to how the parameters are defined or calculated, should submit the data it has and explain any material differences from the prescribed indices. After the effective date of this section, utilities shall modify their reliability performance measures to conform to those specified herein for purposes of consistent reporting of comparable data in the future. PSC 113.0605 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0606(1)(1) Each utility shall keep a record of all interruptions to service affecting the entire distribution system of any single community or an important division of a community and include in such record the location, date and time of interruption, the duration, the approximate number of customers affected, the circuit or circuits involved and, when known, the cause of each interruption. PSC 113.0606(2)(2) When complete distribution systems or portions of communities have service furnished from unattended stations, these records shall be kept to the extent practicable. The record of unattended stations shall show interruptions which require attention to restore service, with the estimated time of interruption. Breaker or fuse operations affecting service should also be indicated even though duration of interruption may not be known. PSC 113.0606(3)(3) Each utility shall notify the commission of any event described in par. (a), (b), (c), (d) or (e) involving bulk power supply facilities (any generating unit or electric facilities operating at a nominal voltage of 69 kV or higher): PSC 113.0606(3)(a)(a) Any interruption or loss of service to customers for 15 minutes or more to aggregate firm loads in excess of 200,000 kW. Such notification shall be made by telephone as soon as practicable without unduly interfering with service restoration and, in any event, within one hour after beginning of the interruption. A confirming written report shall be submitted within 2 weeks. PSC 113.0606(3)(b)(b) Any interruption or loss of service to customers for 15 minutes or more to aggregate firm loads exceeding the lesser of 100,000 kW or half of the current annual system peak load and not required to be reported under par. (a). Such notification shall be made by telephone no later than the beginning of the commission’s next regular work day after the interruption occurred. A confirming written report shall be submitted within 2 weeks. PSC 113.0606(3)(c)(c) Any decision to issue a public request for reduction in use of electricity. Notification of such decision shall be made by telephone at the time of issuing such request. A confirming written report shall be submitted within 2 weeks. PSC 113.0606(3)(d)(d) Any action to reduce firm customer loads by reduction of voltage for reasons of maintaining adequacy of bulk electric power supply. Notification of such action shall be made by telephone at the time of taking such action. A confirming written report shall be submitted within 2 weeks. PSC 113.0606(3)(e)(e) Any action to reduce firm customer loads by manual switching, operation of automatic load shedding devices, or any other means for reasons of maintaining adequacy of bulk electric power supply. Notification of such action shall be made by telephone at the time of taking such action. PSC 113.0606(4)(4) Each utility shall notify the commission of service interruptions not involving bulk power supply facilities as follows: PSC 113.0606(4)(a)(a) Interruptions of 60 minutes or more to an entire distribution substation bus or entire feeder serving either 500 or more customers or entire cities or villages having 200 or more customers shall be reported within 2 weeks by a written report. PSC 113.0606(5)(5) The written reports of subs. (3) and (4) shall include the date, time, duration, general location, approximate number of customers affected, identification of circuit or circuits involved and, when known, the cause of the interruption. When extensive interruptions occur, as from a storm, a narrative report including the extent of the interruptions and system damage, estimated number of customers affected and a list of entire communities interrupted may be submitted in lieu of reports of individual interruptions. PSC 113.0606 HistoryHistory: Cr. Register, July, 2000, No. 535, eff. 8-1-00. PSC 113.0607PSC 113.0607 Appropriate inspection and maintenance: system reliability. PSC 113.0607(1)(1) Preventative maintenance plan. Each utility or other person subject to this chapter, including persons who own electric generating facilities in this state who provide service to utilities with contracts of 5 years or more, shall develop and have in place its own preventative maintenance plan. This section is applicable to electric generating facilities as set forth at s. 196.491 (5) (a) 1., Stats. Each plan shall include, among other things, appropriate inspection, maintenance and replacement cycles where applicable for overhead and underground distribution plant, transmission, generation and substation facilities. PSC 113.0607(2)(a)(a) Performance standard. The preventative maintenance plan shall be designed to ensure high quality, safe and reliable service, considering: cost, geography, weather, applicable codes, national electric industry practices, sound engineering judgment and experience. 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.
