PSC 119.08(4)
(4) For any application that is withdrawn by the applicant or deemed withdrawn by the public utility, the public utility shall provide the applicant with a reconciliation of costs from any engineering review, distribution system study, or required distribution system upgrades or modifications performed. Public utilities shall refund to the applicant any fees paid in excess of costs incurred by the utility. Applicants shall pay any additional costs incurred by the utility in excess of previous payments.
PSC 119.08(5)
(5) Public utilities may assess a fee of up to $300 for preparation of a pre-application report, unless the public utility chooses to waive the fee in whole or in part.
PSC 119.08(6)
(6) For each year in which a public utility assessed an engineering review fee or a distribution system study fee for a Category 1 or 2 facility, the public utility shall provide a report to the commission by March 31 of the following year which includes:
PSC 119.08(6)(a)
(a) The number of Category 1 and 2 facilities in which an engineering review fee was assessed and the average engineering review fee that was charged to applicants.
PSC 119.08(6)(b)
(b) The number of Category 1 and 2 facilities in which a distribution system study fee was assessed and the average distribution system study fee that was charged to applicants.
PSC 119.08 History
History: CR 03-003: cr.
Register January 2004 No. 577, eff. 2-1-04;
CR 22-077: am. (1), Table 119.08-1, (2), cr. (4) to (6)
Register April 2024 No. 820, eff. 5-1-24.
PSC 119.09
PSC 119.09 Disconnection. A public utility may refuse to connect or may disconnect a DG facility from the distribution system only under any of the following conditions:
PSC 119.09(1)
(1) Lack of approved standard application form or standard interconnection agreement.
PSC 119.09(2)
(2) Termination of interconnection by mutual agreement.
PSC 119.09(3)
(3) Non-compliance with the technical or contractual requirements.
PSC 119.09(5)
(5) Routine maintenance, repairs, and modifications, but only for a reasonable length of time necessary to perform the required work and upon reasonable notice.
PSC 119.09 History
History: CR 03-003: cr.
Register January 2004 No. 577, eff. 2-1-04.
PSC 119.10(1)(1)
The applicant shall include a one-line schematic diagram with the completed standard application form. ANSI symbols shall be used in the one-line schematic diagram to show the following:
PSC 119.10(1)(b)
(b) Point where the DG facility is electrically connected to the customer's electrical system.
PSC 119.10(1)(e)
(e) Method of grounding, including generator and transformer ground connections.
PSC 119.10(2)
(2) The applicant shall include with the schematic diagram technical specifications of the point where the DG facility is electrically connected to the customer's electrical system, including all unintentional islanding and power quality protective systems. The specifications regarding the unintentional islanding protective systems shall describe all automatic features provided to disconnect the DG facility from the distribution system in case of loss of grid power, including the functions for over/under voltage, over/under frequency, overcurrent, and loss of synchronism. The applicant shall also provide technical specifications for the generator, lockable interconnection disconnect switch, and grounding and shall attach the technical specification sheets for any certified equipment. The applicant shall include with the schematic diagram a statement by the manufacturer that its equipment meets or exceeds the type tested requirements for certification.
PSC 119.11
PSC 119.11 Control schematics. For equipment not certified under s.
PSC 119.26, the applicant shall include with the application a complete set of control schematics showing all protective functions and controls for generator protection and distribution system protection.
PSC 119.11 History
History: CR 03-003: cr.
Register January 2004 No. 577, eff. 2-1-04.
PSC 119.12
PSC 119.12 Site plan. For all categories, the applicant shall include with the application a site plan that shows the location of the interconnection disconnect switch, adjoining street name, and the street address of the DG facility. For Category 2, 3, or 4 DG facilities, the site plan shall show the location of major equipment, electric service entrance, electric meter, interconnection disconnect switch, and interface equipment.
PSC 119.12 History
History: CR 03-003: cr.
Register January 2004 No. 577, eff. 2-1-04.
PSC 119.13(1)(1)
Potential applicants may request a pre-application report in order to obtain information about system conditions at their proposed interconnection location, without submitting an application under s.
PSC 119.04.
PSC 119.13(2)
(2) To request a pre-application report, potential applicants shall complete and submit to its public utility the standard pre-application request form. A request for a pre- application report shall not be considered submitted until applicant submits the standard pre-application form and pays applicable pre-application review fees under s.
PSC 119.08 (5).
PSC 119.13(3)
(3) All submitted pre-application report requests shall be reviewed for completeness in the order in which they fulfill the requirements of sub.
(2).
PSC 119.13(3m)
(3m) Public utilities shall evaluate the submitted pre-application form for completeness within 5 business days of receipt. A complete request shall include location information that allows the public utility to clearly identify a proposed point of interconnection, and information on the proposed DG facility sufficient to identify DG type, nameplate and export capacity, and service configuration.
PSC 119.13(4)
(4) All complete pre-application report requests shall receive pre-application reports in the order in which they fulfill the requirements of sub.
(3). Within 15 business days of determining a pre-application report request complete, the public utility shall respond by providing the applicant with a completed standard pre- application report that provides information on the capacity, network and operating characteristics, and applicable operating constraints at the proposed point of interconnection.
PSC 119.13(4m)
(4m) Completed pre-application reports shall reflect the best available information using existing data readily available to the public utility at the time of reporting. A public utility shall not be obligated to conduct additional analysis of the proposed project or location in order to complete a pre- application report. The report shall communicate to potential applicants that the information provided is subject to change and may not be applicable as of the date when a future application is submitted.
PSC 119.13 History
History: CR 22-077: cr.
Register April 2024 No. 820, eff. 5-1-24; renum. (3) (a), (4) (a) to be (3m) and (4m) under s.
13.92 (4) (b) 1., Stats.,
Register April 2024, No. 820.
PSC 119.20
PSC 119.20 General design requirements. PSC 119.20(1)(1)
The applicant shall install protection devices to ensure that the current supplied by the DG facility is interrupted if a fault or other potentially dangerous event occurs on the distribution system. If such an event occurs and the public utility's distribution system is de-energized, any DG facility that is connected to this distribution system shall automatically disconnect. All DG facilities shall utilize protection devices that prevent electrically closing a DG facility that is out of synchronization with the distribution system.
PSC 119.20(2)
(2) All installations shall include equipment circuit breakers, on the DG facility side of the point where the DG facility is electrically connected to the customer's electrical system, that are capable of interrupting the maximum available fault current. Equipment circuit breakers shall meet all applicable UL, ANSI, and IEEE standards.
PSC 119.20(3)
(3) The public utility may require that the applicant furnish and install an interconnection disconnect switch that opens, with a visual break, all ungrounded poles of the interconnection circuit. The interconnection disconnect switch shall be rated for the voltage and fault current requirements of the DG facility, and shall meet all applicable UL, ANSI, and IEEE standards. The switch enclosure shall be properly grounded. The interconnection disconnect switch shall be accessible at all times, located for ease of access to public utility personnel, and shall be capable of being locked in the open position. The applicant shall follow the public utility's recommended switching, clearance, tagging, and locking procedures.
PSC 119.20 Note
Note: Provisions of the Wisconsin Electrical Safety Code, Volume 2, ch.
SPS 316 also apply to these installations.
PSC 119.20(4)
(4) The applicant shall label the interconnection disconnect switch “Interconnection Disconnect Switch" by means of a permanently attached sign with clearly visible and permanent letters. The applicant shall provide and post its procedure for disconnecting the DG facility next to the switch.
PSC 119.20(5)
(5) The applicant shall install an equipment grounding conductor, in addition to the ungrounded conductors, between the DG facility and the distribution system. The grounding conductors shall be available, permanent, and electrically continuous, shall be capable of safely carrying the maximum fault likely to be imposed on them by the systems to which they are connected, and shall have sufficiently low impedance to facilitate the operation of overcurrent protection devices under fault conditions. All DG transformations shall be multi-grounded. The DG facility may not be designed or implemented such that the earth becomes the sole fault current path.
PSC 119.20 Note
Note: Grounding practices are also regulated by the Wisconsin Electrical Safety Code Volumes 1 and 2, as found in chs.
SPS 316 and
PSC 114.
PSC 119.20(6)(a)(a) All inverter-based DG facilities shall be UL 1741 published September 28, 2021 listed.
PSC 119.20(6)(b)
(b) All DG facilities shall meet the requirements of IEEE Std 1547-2018 and be tested in accordance with IEEE Std 1547.1.
PSC 119.20(6)(b)1.
1. Synchronous machine generation shall use the normal performance category of Category A and the abnormal performance category of Category I. Ride-through and trip settings shall meet the recommendations of the regional transmission operator guidelines.
PSC 119.20(6)(b)2.
2. Inverter-based DG facilities shall use the normal performance category of Category B and the abnormal performance category of Category II. Ride-through and trip settings shall meet the recommendations of the regional transmission operator guidelines. The public utility shall constructively work with the regional transmission operator to provide a recommendation whether abnormal performance category of Category III is the proper category assignment for inverter-based DG facilities.
PSC 119.20(6)(b)3.
3. Exceptions to these performance categories may be reviewed by the public utility on a case-by-case basis.
PSC 119.20(7)(a)(a) All Category 1 and 2 DG facilities shall be operated at a power factor greater than 0.9.
PSC 119.20(7)(b)
(b) All Category 3 and 4 DG facilities shall be operated at unity power factor or as mutually agreed between the public utility and applicant.
PSC 119.20(9)
(9) The applicant shall protect and synchronize its DG facility with the distribution system.
PSC 119.20(10)
(10) Each DG facility shall include an automatic interrupting device that is listed with a nationally recognized testing laboratory and is rated to interrupt available fault current. The interrupting device shall be tripped by any of the required protective functions.
PSC 119.20(11)
(11) An applicant for interconnection of a Category 3 or Category 4 facility shall provide test switches as specified by the public utility, to allow for testing the operation of the protective functions without unwiring or disassembling the equipment.
PSC 119.20(12)
(12) The public utility may require a DG facility to be isolated from other customers by installation of a separate power transformer. When a separate transformer is required, the utility may include its actual cost in the distribution system upgrade costs. The applicant is responsible for supplying and paying for any custom transformer. This requirement does not apply to an induction-type generator with a capacity of 5 kW or less, or to other generating units of 10 kW or less that utilize a line-commutated inverter.
PSC 119.20(13)
(13) The owner of a DG facility designed to operate in parallel with a spot or secondary network service shall provide relaying or control equipment that is rated and listed for the application and is acceptable to the public utility.
PSC 119.20(14)
(14) For a Category 3 or Category 4 DG facility, the public utility may require that the facility owner provide telemetry equipment whose monitoring functions include transfer-trip functionality, voltage, current, real power (watts), reactive power (vars), and breaker status.
PSC 119.20(15)
(15) When the public utility requires two-way communication or control functionality of the DG facility, the applicant shall work with the public utility to establish the minimum standard technical and communication requirements.
PSC 119.20(16)
(16) For interconnection purposes, energy storage systems shall be treated as distributed generation facilities and shall meet the following requirements and standards:
PSC 119.20(16)(a)
(a) Provide operational mode programming that controls the charging, discharging, and bypass (export or non-export) of an energy storage system. Operational mode programming shall be stated in an interconnection agreement.
PSC 119.20 Note
Note: The UL standards are available at
http://ulstandards.ul.com. They may also be viewed at the PSCW Library, 4822 Madison Yards Way, Madison, WI.
PSC 119.20 History
History: CR 03-003: cr.
Register January 2004 No. 577, eff. 2-1-04;
CR 22-077: am. (6) (a), renum. (6) (b) to (6) (b) (intro.) and am., cr. (6) (b) 1. to 3., (15), (16)
Register April 2024 No. 820, eff. 5-1-24; correction in (16) (b) made under s.
35.17, Stats.,
Register April 2024 No. 820.
PSC 119.25
PSC 119.25 Minimum protection requirements. PSC 119.25(1)(1)
Each DG facility shall include protection and unintentional islanding equipment to prevent the facility from adversely affecting the reliability or capability of the distribution system. The applicant shall contact the public utility to determine any specific protection requirements.
PSC 119.25(2)
(2) The protective system functions, which may be met with microprocessor-based multifunction protection systems or discrete relays, are required. Protective relay activation shall not only alarm but shall also trip the generator breaker/contactor.
PSC 119.25(3)
(3) In addition to unintentional islanding protection, a DG facility shall meet the following minimum protection requirements:
PSC 119.25(3)(b)6.
6. Other equipment, such as other protective devices, supervisory control and alarms, telemetry and associated communications channel, that the public utility determines to be necessary and is compliant with applicable codes and standards. The public utility shall advise the applicant of any communications requirements after a preliminary review of the proposed installation.
PSC 119.25(4)
(4) A DG facility certified pursuant to s.
PSC 119.26 shall be deemed to meet the requirements of this section.
PSC 119.25 History
History: CR 03-003: cr.
Register January 2004 No. 577, eff. 2-1-04;
CR 22-077: am. (1), (3) (intro.), (b) 6.
Register April 2024 No. 820, eff. 5-1-24.
PSC 119.26
PSC 119.26 Certified paralleling equipment. DG paralleling equipment that a nationally recognized testing laboratory certifies as meeting the applicable type testing requirements of UL 1741 (September 28, 2021 revision) is acceptable for interconnection, without additional protection systems, to the distribution system. The applicant may use certified paralleling equipment for interconnection to a distribution system without further review or testing of the equipment design by the public utility, but the use of this paralleling equipment does not automatically qualify the applicant to be interconnected to the distribution system at any point in the distribution system. The public utility may still require an engineering review to determine the compatibility of the distributed generation system with the distribution system capabilities at the selected point of common coupling. DG paralleling equipment shall meet applicable codes and standards listed in PSC 119.025.
PSC 119.27
PSC 119.27 Non-certified paralleling equipment.
