reliability plan, inspection and maintenance plan, and

Prairie Energy Cooperative

Reliability Plan, Inspection and

Maintenance Plan, and Meter Testing

Plan

Pursuant to Iowa Administrative Code 25.3.

Effective 01/01/2021

Filed with the Iowa Utilities Board on April 16, 2021, RE-0932

1.0 Overview of Prairie Energy Cooperative’s Reliability Plan filed Pursuant to Iowa

Administrative Code 199—20.18(8)"a" and 25.3.

Prairie Energy Cooperative is organized as a Cooperative and is governed by the member-consumers through a democratic approach of electing member-consumers to serve on a board of directors to direct the cooperative in its business activities. Prairie Energy Cooperative has its main office in Clarion, Iowa. Prairie Energy Cooperative provides distribution electric service to about 3200 member-consumers in the counties of Kossuth, Humboldt, Webster, Hamilton, Hardin, Wright, Franklin, Cerro Gordo, Hancock, Winnebago and Worth. Prairie Energy Cooperative has about 2.0 of consumers per mile of distribution line. Prairie Energy Cooperative has an all requirements power supply contract with Corn Belt Power Cooperative. The Corn Belt Power Cooperative owns and operates the distribution substations. The geographic areas served by Prairie Energy Cooperative are very rural in nature and is generally very flat. The area served also has a significant amount of vegetation including trees. Member-consumers are able to contact the cooperative 24 hours a day, 7 days a week through the Basin Power Cooperative Service Response Services (SRS) and an after-hours telephone number. Members are able to report service interruptions and any other problems they may experience with electric service. 2.0 Reliability Plan (IAC 199—20.18(8)"a" and 25.3) Prairie Energy Cooperative’s reliability plan is an integrated approach addressing:

System design System construction System operation System maintenance and inspections Data recording Data reporting and Communications

Providing safe, reliable, environmentally responsible and affordable electric service to meet the expectations of the member-consumers requires an intricate balance and consideration of all of the above as well as the resources available to achieve results. Prairie Energy Cooperative will make reasonable efforts to avoid and prevent interruptions of service. However, when interruptions occur, service shall be reestablished within the shortest time practicable, consistent with safety. Prairie Energy Cooperative’s electric facilities will be designed, constructed, maintained, and electrically reinforced and supplemented as required to reliably perform the power delivery burden placed upon them in the storm and traffic hazard environment in which they are located.


Prairie Energy Cooperative will carry on an effective preventive maintenance program and will be capable of emergency repair work on a scale which its storm and traffic damage record indicates as appropriate to its scope of operations and to the physical condition of its electric facilities. Prairie Energy Cooperative in appraising the reliability of its electric system will consider the condition of the physical property and the size, training, supervision, availability, equipment, and mobility of the maintenance forces all as demonstrated in actual cases of storm and traffic damage to the facilities. Prairie Energy Cooperative will keep records of interruptions of service on its primary distribution system and will make an analysis of the records for the purpose of determining reasonable steps to be taken to prevent recurrence of such interruptions. Prairie Energy Cooperative will make reasonable efforts to reduce the risk of future interruptions by taking into account the age, condition, design, and performance of electric facilities, and providing adequate investment in the maintenance, repair, replacement, and upgrade of facilities and equipment. 2.1 Standards for System Design and Construction Prairie Energy Cooperative’s distribution system is designed, constructed, and maintained in accordance with accepted engineering standards. In an effort to provide reliable service to our members the distribution system is designed to meet power requirement needs under normal operating conditions as well as certain contingency situations. Prairie Energy Cooperative has retained the services of a professional engineer licensed in the State of Iowa to assist in the design of its distribution system and to assist as needed with the construction, inspection and maintenance of its system and to ensure that all applicable codes and standards are met. The following standards are used in the design, construction, and maintenance of Prairie Energy Cooperative’s electric facilities:

• Iowa Electrical Safety Code, as defined in the Iowa Administrative Code 199, Chapter 25

• National Electrical Code, ANSI/NFPA 70-2014*

• American National Standard Requirements for Instrument Transformers, ANSI/IEEE C57.13.1-2006; C57.13.3-2005*

• American National Standard Voltage Ratings for Electric Power Systems and Equipment – Voltage Ratings (60 Hz), ANSI C84.1-2011*

• Grounding of Industrial and Commercial Power Systems, IEEE 142-2007*

• IEEE Standard 1159-2009, IEEE Recommended Practice for Monitoring Electric Power Quality*


• IEEE Standard 519-2014, IEEE Recommended Practices and Requirements for Harmonic Control in Electric Power Systems.*

• At railroad crossings, 199 IAC 42.6(476), “Engineering standards for electric and communications lines.”*

*or any successor Code or Standard adopted by the Iowa Utilities Board.

Prairie Energy Cooperative has been financed in part from the Federal Government through the United States Department of Agriculture, Rural Utilities Service (RUS) and as such has been subject to certain requirements related to system design, construction, operation, maintenance, inspections and data collection. The following is a list of the major RUS documents addressing standards in the design, construction, and maintenance of its’ distribution system:

• Unguyed Distribution Poles – Strength Requirements, RUS Bulletin 1724E-150 (26 Pages, Dated 8/14/2014) http://www.rd.usda.gov/files/UEP_Bulletin_1724E-150.pdf

• Mechanical Loading on Distribution Crossarms, RUS Bulletin 1724E-151 (19 Pages, Dated 2/23/2016) http://www.rd.usda.gov/files/UEP_Bulletin_1724E-151.pdf

• The Mechanics of Overhead Distribution Line Conductors, RUS Bulletin 1724E-152 (20 Pages, Dated 7/30/2003) http://www.rd.usda.gov/files/UEP_Bulletin_1724E-152.pdf

• Electric Distribution Line Guys and Anchors, RUS Bulletin 1724E-153 (29 Pages, Dated 4/25/2001) http://www.rd.usda.gov/files/UEP_Bulletin_1724E-153.pdf

• Distribution Conductor Clearances and Span Limitations, RUS Bulletin 1724E-154 (18 Pages, Dated 7/30/2003) http://www.rd.usda.gov/files/UEP_Bulletin_1724E-154.pdf

• Specifications and Drawings for Underground Electric Distribution Lines, RUS Bulletin 1728F-806 (145 Pages, Dated 10/11/2018) http://www.rd.usda.gov/files/1728f-806.pdf

• Specifications and Drawings for 12.5/7.2 kV Line Construction, RUS Bulletin 1728F-804 (345 Pages, Dated 4/21/2005) http://www.rd.usda.gov/files/UEP_Bulletin_1728f-804.pdf

• Design Guide for Rural Substations, RUS Bulletin 1724E-300 (764 Pages, Dated 6/07/01) http://www.rd.usda.gov/files/UEP_Bulletin_1724E-300.pdf

• Wood Pole Inspection and Maintenance, RUS Bulletin 1730B-121 (20 Pages, Dated 8/13/13) http://www.rd.usda.gov/files/UEP_Bulletin_1730B-121.pdf

• Electric System Operation and Maintenance, RUS Bulletin 1730-1 (17 Pages, Dated 9/23/2016) http://www.rd.usda.gov/files/UEP_Bulletin_1730-1.pdf


• Electric System Long-Range Plan, RUS Bulletin 1724D-101A (87 Pages, Dated 2/16/2017) http://www.rd.usda.gov/files/UEP_Bulletin_1724D-101A.pdf

• System Planning Guide, Construction Work Plan, RUS Bulletin 1724D-101B (12 Pages, Dated 12/18/12) http://www.rd.usda.gov/files/UEP_Bulletin_1724D-101B.pdf

• Interruption Reporting and Service Continuity Objectives for Electric Distribution Systems, RUS Bulletin 1730A-119 (32 Pages, Dated 3/24/09) http://www.rd.usda.gov/files/UEP_Bulletin_1730A-119.pdf

Any successor or replacement bulletin or successor regulation to any of the above adopted by RUS is incorporated into this reliability plan. See

https://link.edgepilot.com/s/c6d580de/6B_fkBdDjU2uPCxM6XxZBQ?u=https://www.rd.usda.gov/resources/regulations/bulletins

2.2 Standards for Operation, Maintenance and Inspection of the System Prairie Energy Cooperative has adopted a written program for inspecting and maintaining its electric supply lines and substations (excluding generating stations) in order to determine the necessity for replacement, maintenance and repair, and for tree pruning or other vegetation management. If the plan is amended or altered, revised copies of the appropriate plan pages will be filed with the Iowa Utilities Board. Continued system inspection and maintenance is a requirement of both the RUS and Iowa Utilities Board and is a common industry practice. RUS requires a Form 300, System Inspection Report, to be filed at least every three years. The Iowa Utilities Board requires the filing of a Facilities Inspection and Maintenance Plan pursuant to IAC 199—25.3. If the plan is amended or altered, revised copies of the appropriate plan pages must be filed with the IUB. Additionally, as a part of its annual report to the Iowa Utilities Board, as required by 199—Chapter 23, certification of compliance with each area of the inspection plan or a detailed statement on areas of noncompliance must be provided. Prairie Energy Cooperative’s Inspection and Maintenance plans are summarized in this Reliability Plan and includes the following:

• Vegetation Management (IAC 199—20.18(8)a.(1) and 25.3(3) c.)

• Detailed Overhead and Underground Line Inspection (IAC 199-25.3)

• Substation Inspection and Maintenance (IAC 199-25.3)

• Pole Inspection and Treatment (IAC 199-25.3)

• Meter Testing (IAC 199-25.3 and 20.6)

• Oil Circuit Reclosers and Sectionalizer Maintenance (IAC 199-25.3)

• Infrared Inspection (IAC 199-25.3)


Prairie Energy Cooperative has electric supply lines in the following counties and parts of counties: Kossuth County – provide electric service to about two dozen accounts on the eastern edge of the county. Humboldt County – provide electric service to about a dozen and a half accounts in the southeast part of the county. Webster County – primarily provide electric service to the east 1/3 of the county but not to all accounts in that area. Hamilton County – provide electric service to accounts in the north and west portions of the county but not to all accounts in that area. Hardin County – provide electric service to a couple of accounts in the northwest corner of the county. Wright County – provide electric service in all areas of the county but not to all accounts in the county. Franklin County – provide electric service to about a dozen and a half accounts on the western edge of the county. Cerro Gordo – provide electric service to accounts in the northwest corner and southwest corner but not to all accounts in that area. Hancock County-provide electric service in all areas of the county but not to all accounts in the county. Winnebago County – provide electric service to the southern edge of the county but not to all accounts in that area. Worth County – provide electric service to the southwest corner of the county but not to all accounts in that area. All facilities are managed from the Clarion office, although local line personnel have been assigned specific districts for after hours outage call outs. In addition to the above Inspection and Maintenance plans, Prairie Energy Cooperative has several programs in place to monitor and improve the reliability of electric service to member-consumers. They are summarized in the Reliability Plan and include:

• Lightning Strike Mitigation Program (IAC 199-20.18(8)a.(1)

• Animal Contact Reduction Program (IAC 199-20.18(8)a.(1)

• Planned Interruption Notification Program (IAC 199-20.7(11)

• Supervisory Control and Data Acquisition (SCADA)

• Power Quality Monitoring Programs IAC 199-20.7(12)

• Harmonics Program (IAC 199-20.7(13)

• Long Range Engineering Plans

• Computerized Mapping System


The Iowa Utilities Board staff completes independent routine inspections of the electric system and RUS requires all new construction to be certified by a registered engineer familiar with RUS standards.

2.2.1 Vegetation Management – Right of Way Maintenance Program Representatives of Prairie Energy Cooperative, as well as contractors, complete Prairie Energy Cooperative’s right-of-way maintenance program. The program consists of a combination of tree pruning, brush pruning, and chemical treatment to impede future growth. Chemicals may be used in impeding future growth. The cycles and methods are determined using best judgment and knowledge of local factors and in conformance with Section 35 of the Lineman’s and Cableman’s Handbook and ANSI A300 (Part 1)-2008 (R2014), “Pruning”. Prairie Energy Cooperative uses information from the various inspections to determine which parts of the system are in need of vegetation management in the near term. Information is also used from member-consumers to determine areas in need of vegetation management in the near term. Prairie Energy Cooperative generally attempts to prune trees and manage vegetation on 100% of the system annually either by scheduled line inspection or unscheduled (line patrol). However, it is important to note that weather in the local area as well as regionally can impact the amount of work completed in a given time period.

2.2.2 Lightning Outage Mitigation Program In an attempt to prevent outages due to lightning, Prairie Energy Cooperative installs lightning arresters at intervals according to the cooperative's engineering study on all new line construction (not to exceed every 1000 feet). 2.2.3 Animal Contact Reduction Prairie Energy Cooperative does not have a formal program at this time. However, a number of animal and bird guards are installed in areas that may be prone to more activity. 2.2.4 Line Inspection and Maintenance Plan

Overhead Distribution Line Inspection Schedules, Coverage, Conduct of Inspections and Instructions to Inspectors Prairie Energy Cooperative’s detailed line inspection program calls for the inspection of all overhead electric lines below 34.5 kV over a (10)-year period with


approximately 10% of the system inspected each year. Prairie Energy Cooperative does not operate electric lines at or above 34.5

A detailed inspection is made of all the overhead lines on a pole by pole basis to check the condition of the pole and pole top assemblies as well as verify the lines meet the requirements of the Iowa Electrical Safety Code. Prairie Energy Cooperative coordinates these inspections through its licensed professional engineer as necessary.

All substandard conditions and violations of Iowa Electrical Safety Code requirements are noted and reported to management. As deemed necessary by Prairie Energy Cooperative’s coordinators, job orders and/or staking sheets are then made up to address the deficiencies in a timely manner. The areas to be inspected are recorded on system maps set up in 20 inspection areas with 2 completed yearly.

Underground Distribution Line Inspection Schedules, Coverage, Conduct of Inspections and Instructions to Inspectors

At the present time Prairie Energy Cooperative has approximately 130 miles of underground cable installed on its distribution system. This underground consists of both bare concentric neutral cable and jacketed concentric neutral cable. Underground cabinets and transformers are inspected as part of the detailed line inspection program, with all underground being inspected over a 10 year period. This work is coordinated through Prairie Energy Cooperative’s licensed professional engineer as necessary.

In addition to the regular outage records, documents are maintained to track faults in underground cable. This records information is related to the location of each fault as well as the overall visible condition of the cable. These records along with the outage records are used to schedule underground cable replacement projects. In the past 10 years, Prairie Energy Cooperative has replaced approximately 3 miles of aging underground cable because of unacceptable numbers of faults.

In addition to the detailed line inspection every 10 years, Prairie Energy Cooperative’s maintenance crews complete a drive by inspection (Line Patrol) on the rest of the system annually.

The line inspection for underground and overhead, for lines operated at below 34.5 kV, shall include but shall not be limited to, the following items:

A. Pad mount transformers B. Locks and seals


C. Switching cabinets D. High voltage switches E. Secondary pedestals and vaults F. Underground connections G. Pole mounted transformers H. Ground connections I. Guys, guy anchors and guy guards J. Cutouts, arresters, and switches K. Clearance to structures, ground, and trees L. Conductor condition and sag M. Cross arms, insulator, and pole top hardware N. Pole condition at and above the ground

See attached form related to overhead line inspections for more details on each item. More detailed inspection and testing may be conducted as deemed necessary by the cooperative. It is the practice of Prairie Energy Cooperative to indicate on the inspection form that no defects have been observed. Additional inspection or patrols will be carried out following damaging storms and as necessary in areas subject to high rates of vandalism. Records sufficient to show compliance with the inspection program will be maintained by the cooperative. The Cooperative or a representative engaged by the Cooperative shall investigate any stray voltage complaints as set forth in the Iowa Stray Voltage Guide, including conducting the testing described therein. The Guide can be obtained by contacting the Cooperative or through: www.iowastrayvoltageguide.com.

2.2.5 Substation Inspection Schedules, Coverage, Conduct of Inspections and Instructions to Inspectors Prairie Energy Cooperative’s G&T, Corn Belt Power Cooperative, owns and operates all substations.

2.2.6 Pole Inspection and Treatment Schedules, Coverage, Conduct of Inspections and Instructions to Inspectors Prairie Energy Cooperative has a program of regular above and below ground line pole inspection and treatment, with the complete system scheduled to be completed on a 10-year cycle. The inspections are done on an area basis with all


http://www.iowastrayvoltageguide.com/

Cooperative owned poles, within a given area, being inspected each year. The program consists of a complete inspection of the poles, ground line treatment of all poles over 15 years of age, and a report on all rejected poles that are to be replaced. Poles are generally replaced within six months. The following table is an example of a summary of the poles tested over the last ten years. The completed table and supporting details are maintained at the cooperative office.

Year Poles on System

Poles Tested

Poles Rejected

Poles Replaced

Rejection Rate

1

2

3

4

5

6

7

8

9

10

Total

Inspections and treatments are done by a combination of in-house crews and contractors.

2.2.7 Meter Testing Prairie Energy Cooperative will test watt hour meters for accuracy and mechanical condition, in accordance with Iowa Administrative Code 199-20.6. All meters and associated metering devices shall, when tested, be adjusted as closely as practicable to the condition of zero error, if returned to service. All meters will be tested within 180 days after they are removed from service. Such tests will be made before the meters and associated devices are adjusted, repaired, returned to active service, or retired. All watt-hour meters must be accurate to within plus or minus 2% at full and light load. Demand meters shall be accurate to within 1.5% The Cooperative will sample test new meters to ascertain if they meet the required accuracy limits. Upon request by a member-consumer, the Cooperative will test the meter servicing that member-consumer, except that such tests will not be made more frequently than once in 18 months.


A written report of the test results will be mailed to the customer within 10 days of the completed test and a record of each test shall be kept on file at the Cooperative's office. Prairie Energy Cooperative will give the member-consumer or a representative of the member-consumer the opportunity to be present while the test is conducted. If the test finds the meter is accurate within the limit accepted by Prairie Energy Cooperative in its meter inspection and testing program, Prairie Energy Cooperative may charge the member-consumer $25 or the cost of conducting the test, whichever is less. The member-consumer will be advised of any potential charge before the meter is removed for testing. Prairie Energy Cooperative’s meter testing schedule is based on the type of meter and the level of load being metered and can be found in the following tables. For meters tested using a statistical sampling method, the statistical sampling shall be in compliance with ANSI ASQ Z1.4-2008 as described in ANSI C12.1-2008. Prairie Energy’s automatic test board is tested every year on a Master Standard while the field test unit is tested every three months on a Master Standard.

Single Phase Meters

Form Voltage Amps Meter Count

Testing Method

Test Period (Years) (if applicable)

1S 120 15 0

2S 240 15 0

2S 240 30 4095 Statistical

2S 240 50 0

3S 240 2.5 875 Statistical

4S 240 2.5 29 Periodic

Multi Phase Meters

Form Voltage Amps Meter Count

Testing Method

Test Period (Years) (if applicable)

5S 120 2.5 4 Periodic

6S 120 2.5 0

8S 240 2.5 0

9S 120 2.5 196 Statistical

14S 120 15 0

12S 120 30 1 Periodic

15S 240 15 0

15S 240 30 8 Periodic

16S 120 30 0

Meter testing records are maintained on the National Information Solutions Cooperative (NISC) database and include meter location, meter size, meter


manufacturer, install date, and test history for each meter. The following table is an example of a summary of the meters tested over the last five years. The completed table and supporting details are maintained at the cooperative office.

Year 2020 2019 2018 2017 2016 5 Year Total

Single Phase 788 817 115 124 106 1950

Three Phase 30 53 16 18 16 133

Total 818 870 131 142 122 2083

2.2.8 Oil Circuit Reclosers, Sectionalizers and Regulators Prairie Energy Cooperative has a maintenance program in which all oil circuit reclosers on the Cooperative’s system are scheduled for maintenance every five years. Vacuum reclosures every eight years. The units are disassembled, inspected, repaired as necessary, filled with new oil, cleaned and painted. Information concerning the location, size, type, manufacturer, and maintenance history of reclosers and sectionalizers is maintained in a database at the Cooperative. The following table is an example of a summary of the total number of reclosers and sectionalizers on Prairie Energy Cooperative’s system and the number serviced for the past five years. The completed table and supporting details are maintained at the cooperative office.

Year Total Reclosers Total

Serviced

1

2

3

4

5

Voltage Regulators Biannually Inspected a. Record Voltages b. Record current, maximum, and minimum drag hands then reset c. Signs of oil leakage d. Cracked or damaged bushings or arrester e. Oil level not correct f. Indicating lights not operating g. Record counter readings h. Perform manual operation check

2.2.9 Infrared Inspection

Prairie Energy Cooperative performs infrared testing on underground cabinets, transformers, and other equipment related to underground inspections.


2.2.10 Planned Interruptions

Planned interruptions are scheduled at the most convenient time for customers and Prairie Energy Cooperative representatives. Any interruption scheduled for more than fifteen minutes is preceded by adequate notice to those customers who will be affected. This notification is usually done by phone or visit.

2.2.11 Supervisory Control and Data Acquisition (SCADA)

Prairie Energy Cooperative has a system wide SCADA system. The SCADA system allows Prairie Energy Cooperative to monitor voltage and current values by circuit and phase for all 22 substations. The SCADA system alarms the Operations Department when voltage levels fall outside the allowable range, when fault currents are detected, and when substation reclosers have locked out. 22 substations have electronic capability that allow Prairie Energy Cooperative to operate the reclosers from the Operations Center in the case of an outage and reduce outage time and improve customer reliability.

2.2.12 Quality of Service

Substation and Feeder Loading Substation load balance is studied as part of the Construction Work Plan (CWP). One of the objectives of the CWP was to attempt to balance loads on all feeders by limiting the unbalance of currents to 10% at peak load levels. The SCADA system allows Prairie Energy Cooperative to monitor current values by circuit and phase in order to maintain acceptable load balance on substation feeders. Voltage Conditions Substation voltage levels are checked each month as part of Corn Belt’s monthly substation inspections. During this inspection the regulators and load tap changers are also tested to verify they are operating properly within the specified bandwidths. Prairie Energy Cooperative’s SCADA system also monitors substation voltage levels and alarms the Operations Department when voltage levels fall outside of the allowable range.

The cooperative handles individual voltage complaints by members. Engineering and Operations departments of the cooperative are responsible for assisting all members with any problems they have concerning the Cooperative. A representative of this department meets with the member to discuss the problem and install voltage recorders. The Engineering Department then analyzes the data and the appropriate corrections are made.


Any complaints or concerns regarding stray voltage will be addressed as set forth in the Iowa Stray Voltage Guide, which can be obtained by contacting the Cooperative or through:www.iowastrayvoltageguide.com.

2.2.13 Harmonics Prairie Energy Cooperative has adopted the IEEE Standard 519-2014, IEEE Recommended Practices and Requirements for Harmonic Control in Electric Power Systems or its successor standard. When excessive harmonics problems arise, Prairie Energy Cooperative will investigate and take actions to rectify the problem as it relates to facilities owned, operated and maintained by Prairie Energy Cooperative. In addressing harmonics problems, Prairie Energy Cooperative will implement to the extent practicable and in conformance with prudent operation the practices outlined in the above standard. 2.2.14 Power Quality Prairie Energy Cooperative has adopted the IEEE Standard 1159-2009, IEEE Recommended Practice for Monitoring Electric Power Quality or any successor standard. Prairie Energy Cooperative will investigate power quality complaints from its member-consumers and determine if the cause of the problem is on Prairie Energy Cooperative’s system. When power quality problems arise, Prairie Energy Cooperative will investigate and take actions to rectify the problem as it relates to facilities owned, operated and maintained by Prairie Energy Cooperative. In addressing power quality problems, Prairie Energy Cooperative will implement to the extent practicable and in conformance with prudent operation the practices outlined in the above standard. While not recorded in the past, Prairie Energy Cooperative receives very few radio interference complaints. Each complaint is investigated by the Cooperative using detection equipment. Voltage flicker complaints are tracked in a database or records created to monitor member complaints. A Cooperative Representative meets with each member filing a complaint to identify the source of the problem, which is usually found to be on the members’ side of the meter. 2.2.15 Load Studies and Planning In order to continue to provide reliable service to Prairie Energy Cooperative customers in the future, the Engineering Department develops both short and long-range plans. The new Construction Work Plan was completed in 2016 and covered the years 2016-2019. It has been extended to the year 2022.


The Engineering Department prepared the Cooperative’s current long-range plan in 2002. The long-range plan covers the years 2002-2021 and is scheduled to be updated in 2022 if load growth continues to remain limited. The latest Sectionalizing Study was completed in 2006. Prairie Energy Cooperative completed a limited updated Sectionalizing Study in 2010. Milsoft computer software is used to perform system studies and analyze voltage profiles and amperage loading on each circuit within Prairie Energy Cooperative’s system. The highest of the summer, winter, or fall peak load is allocated to each line section based upon actual kilo-Watt-hour sales to each member during the peak load month. Load data is transferred from the NISC billing system to Milsoft by phase and line section. 2.2.16 Current System Maps - Operating Maps Prairie Energy Cooperative uses National Information Solutions Cooperative’s (NISC) computerized mapping system. The mapping is done using the ESRI software package and shows the locations of all consumers, substations and substation boundaries, overhead and underground line, line equipment, normal open points, service area boundaries, roads, waterways, and other landmarks. Map books are located in every Cooperative vehicle and throughout the office. The computerized maps are updated on a periodic basis with new map books being printed at least once a year. 2.2.17 Emergency Restoration Plan Prairie Energy Cooperative participates with the Iowa Association of Electric Cooperatives (IAEC) through its Safety Department in an Emergency Restoration Plan for sharing of and securing of resources on widespread interruptions. A part of the service provided through this department is the coordination of a statewide Disaster Plan for participating member rural electric cooperatives. The plan includes procedures for securing help when disasters or emergencies strike. The plan includes processes to help facilitate and coordinate the management of the disaster. The REC personnel are trained in this area as well. This plan is in place 7 days a week 24 hours a day. Communications are maintained between the IAEC and the affected cooperative(s) throughout the day and typically a day-end status report is provided. The plan takes advantage of lessons learned from experiences in previous disasters by other cooperatives and other utilities to better facilitate management of the situation on a going forward basis. The plan includes detailed information on radio frequencies and other pertinent information for each of the cooperatives to facilitate efficient coordination of communication between the cooperatives providing assistance to each other during a disaster. The plan includes information on tracking work locations, rest periods and crew status to ensure safety of the crews. The plan also includes many other tools that


the cooperatives utilize for effective and efficient management in a disaster situation.

3.0 Current Ability to Track and Monitor Interruptions (IAC 199—20.18(8) a. (2)) Prairie Energy Cooperative records and maintains sufficient records and reports to enable it to calculate for the most recent year, the average annual hours of interruption per consumer due to causes in each of the following four major categories:

Power Supply, Major Event, Planned, and All Other.

The category "planned" refers to any interruption scheduled by the distribution system to safely perform routine maintenance. “Power Supply” includes any interruption originating from the transmission system, sub-transmission system, or the substation, regardless of ownership. The category "major event” means an interruption or group of interruptions caused by conditions that exceed the design and operational limits of a system. See IEEE Standard 1366-2003 and Exhibit E. The "all other" category includes all interruptions excluding power supply, major event, and those that are planned. Prairie Energy Cooperative has the ability to record interruptions using the detailed standard codes for interruption analysis recommended by the United States Department of Agriculture, Rural Utilities Service (RUS) Bulletin 1730A-119, Tables 1 and 2. This includes the major cause categories of equipment or installation, age or deterioration, weather, birds or animals, member (or public), and unknown. Prairie Energy Cooperative also has the capability to include the subcategories recommended by RUS for each of these major cause categories. Prairie Energy Cooperative maintains and records data sufficient to enable it to compute system-wide calculated indices for System Average Interruption Frequency Index (SAIFI), System Average Interruption Duration Index (SAIDI), and Customer Average Interruption Duration Index (CAIDI) type measurements, once with the data associated with "major events" and once without. SAIFI is the average number of interruptions per customer during the year. It is calculated by dividing the total annual number of customer interruptions by the total number of customers served during the year.

SAIFI = Total Number of Customer Interruptions Total Number of Customers Served


SAIDI is the average interruption duration per customer served during the year. It is calculated by dividing the sum of the customer interruption durations by the total number of customers served during the year.

SAIDI = Sum of All Customer Interruption Durations Total Number of Customers Served

CAIDI is the average interruption duration for those customers who experience interruptions during the year. It is calculated by dividing the annual sum of all customer interruption durations by the total number of customer interruptions.

CAIDI = Sum of All Customer Interruption Durations Total Number of Customer Interruptions

Total number of customers served means the total number of customers served on the last day of the reporting period. Prairie Energy Cooperative will maintain sufficient records for the most recent seven-years. However, indices will not be computed on a seven year time frame.

4.0 Plans to Communicate the Reliability Plan to Member-Consumers (IAC

199—20.18(8) a. (3)) Iowa Administrative Code 199—20.18(8) a. (3) requires Prairie Energy Cooperative to identify plans to communicate its reliability plan with the member-consumers.

When communicating with member consumers about issues involving reliability, cooperatives must effectively translate very technical information into more, common everyday language. Prairie Energy Cooperative communicates with member-consumers with the cooperative principle of education in mind. This applies not only to provide reliability information to members but also information on other topics as well. This mission is accomplished through a variety of communications tools and methods.

• Governance— Prairie Energy Cooperative is organized as a cooperative and is

governed as such. The member-consumers govern the organization. Prairie Energy Cooperative has a board of directors comprised of seven member-consumers. Prairie Energy Cooperative is organized by having seven districts from which directors are elected by the membership of the cooperative to represent them. This method of geographic organization allows member-consumers throughout the area served by Prairie Energy Cooperative to have access to the board and within a reasonable geographic distance of the community in which the members reside. Communications take place on a regular basis between the board and the members. This communication can take place in many different settings. This local presence and manner of communication has been an integral part of the cooperative and is expected to


continue into the future.

• Annual Meetings — Every year, Prairie Energy Cooperative conducts an annual meeting. During this meeting, Prairie Energy Cooperative has the opportunity to address any reliability issues that the member-consumers of the cooperative believe need to be addressed.

• Newsletters — Newsletters are used to provide timely information on a monthly

basis on information and resources related to reliability. Some examples include manager’s columns on vegetation management or system upgrades as a result of routine inspection and maintenance. The Newsletter also offers opportunities to show visual impacts depicting reliability. These could come in the form of graphs and charts illustrating causes of outages – i.e. storms, animals, human intervention, etc. Newsletters also report to the member consumers certain reliability information. Prairie Energy Cooperative communicates this information to member-consumers on a monthly basis.

• Community Relations — Cooperative members are often active community

leaders participating in church, school events and other social events for employees and directors. These activities provide a unique forum available to member-consumers of Prairie Energy Cooperative to provide input on an informal basis to the directors of the Cooperative as well as employees.

• Iowa One Call Program — Iowa One Call is an effective mechanism for member-

consumers of Prairie Energy Cooperatives to use to maintain system reliability. On a regular basis the cooperatives publish information about this program to maintain awareness among their member consumers.

• Planned Interruptions — Prairie Energy Cooperative notifies members of

planned interruptions of service. Planned interruptions are made at a time that will not cause unreasonable inconvenience to members and interruptions planned for longer than one hour is preceded by notice to those who will be affected.

• Restoration of Service Process — Cooperatives communicate with member-

consumers in numerous ways when system reliability is impacted during the restoration of service process. For unplanned outages, much of the communication falls under the cooperatives’ disaster and communications plan. In an emergency or crisis situation, cooperatives follow basic steps to inform key audiences.

For example in the case of a major power outage caused by weather-related incidents, cooperatives will provide up-to-date, accurate information to member consumers via the news media. The primary communications tools include:

• Fact Sheet


• Official Statement

• News Release

• Social Media • Grain Bin Notices —Prairie Energy Cooperative conducts an annual public

information campaign concerning the construction of grain bins. Through this campaign farmers, farm lenders, grain bin merchants, and city and county zoning officials are informed of the requirements associated with grain bins that could ultimately impact reliability. Cooperatives disseminate this information to members through direct mailings, newsletter articles and Living with Energy in Iowa magazine.

• Living with Energy in Iowa Magazine — Prairie Energy Cooperative subscribes

to Living with Energy in Iowa magazine for their members and topics involving reliability are often covered. This is done in a variety of ways including Perspective columns, stories on infrastructure improvements, new technology, and safety features. Since all of these topics ultimately impact reliability it provides a good forum to reach the captive member consumer audience.

• Day-to-day Contact Call Centers — When a cooperative receives an inquiry

about service that requires the provision of information related to reliability Prairie Energy Cooperative does not charge for the information. When a member registers an inquiry the REC typically reviews the available outage information. Most of the time the operations department at the REC is aware of the outage performance before the member makes the inquiry.

• IAEC Outage Map – The Iowa Association of Electric Cooperatives has developed an outage map to keep member-consumers, regulators, legislators, and media informed of the number of outages occurring during widespread outages. The map shows outages both by county and by cooperative service territory. The map can be accessed at http://www.iowarec.org/outages.

• Stray Voltage Guide- The Iowa Stray Voltage Guide outlines the steps farmers, electricians, utilities and their advisors can take to discover and resolve stray voltage concerns on livestock farms. When farmer and utility companies can work together, stray voltage concerns are more likely to be satisfactorily resolved. This compilation of information was a collaborative effort of Alliant Energy, Iowa Association of Electric Cooperatives, Iowa Farm Bureau Federation and the Iowa State Dairy Association. A copy of said publication can be obtained by contacting the Cooperative or through: www.iowastrayvoltageguide.com.

Prairie Energy Cooperative Electric Cooperative YEARLY WORK SCHEDULE

Year: 2021


http://www.iowastrayvoltageguide.com/

January February March • Line patrol

• Scheduled Line inspection

• Line construction per work plan

• Reclosure maintenance

• Line patrol



• Regulator Inspection

• Vegetation management


• Line patrol


• Line Inspection repairs


• Line Maintenance



April May June • Line patrol


• Pole Inspection replacements

• Schedule line inspection



• Line patrol repairs

• Pole ground line inspection

• Line inspection repairs

• Pole inspection replacements


• Recloser maintenance









July August September • Line patrol repairs












• Regulator Inspection









October November December • Line patrol repairs



















Prairie Energy Cooperative Electric Cooperative Vegetation Management Schedule

Vegetation Management Schedule and Current Status

Year 12

Year 13

Year 14

Year 15

Year 16

Year 17

Year 18

Year 19

Year 20

Year 21

Circuits 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 ALL

Symbols: Scheduled and Unscheduled Vegetation Management (e.g., trimming or spraying) Vegetation Management Completed


Prairie Energy Cooperative Electric Cooperative Overhead Line Inspection Schedule

Inspection Schedule and Current Status

Year 7 Year 8 Year 9 Year 10

Year 11

Year 12

Year 13

Year 14

Year 15

Year 16

Circuit 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 6,16

7,17 8,18 9,19 10,20 1,11

2,12

3,13 4,14

5,15

Symbols: Unscheduled Line Patrol Inspection Circuit Scheduled for Inspection Inspection Completed Replacements & Repairs to Correct Violations Completed


Prairie Energy Cooperative Electric Cooperative

Underground Line Inspection Schedule

Inspection Schedule and Current Status

Year 7 Year 8 Year 9 Year 10

Year 11

Year 12

Year 13

Year 14

Year 16

Year 16

Circuit 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 6,16 7,17 8,18 9,19 10,20

1,11

2,12 3,13 4,14 5,15

Symbols: Scheduled Inspection Circuit Scheduled for Inspection Inspection Completed Replacements & Repairs to Correct Violations Completed


Overhead Underground Inspection and Line Patrol Job Order


Overhead Underground Inspection Form


INSTRUCTION TO INSPECTORS

Purpose: the purpose of the inspection is to determine whether a facility is in compliance with applicable codes and standards, in need of maintenance or corrective action, requires further investigation, or in acceptable condition. Guideline and code requirements for the conduct of inspections can be found in: REA bulletins on Inspection Maintenance of distribution lines, poles and substations. Other reference materials will include, but not limited to current issue of Lineman’s and Cableman’s Handbook, National Electric Code, NFPA and National Electric Safety Code. A. Poles

1. Leaning (2 foot or more out of line at top, except in cases of tree clearances) 2. Rotting 3. Splitting 4. Burns 5. Insect Damage 6. Mechanical damage 7. Poles in conflict 8. Pole Numbers 9. Woodpecker damage

B. Metal Structures

1. Loose structural elements 2. Oxidation (rust) 3. Footings (providing proper support) 4. Grounding (intended or unintended)

C. Crossarms

1. Rotten (decaying) 2. Split 3. Crossarm brace wood (spilt – decaying) 4. Firmly attached and properly braced (loose at carriage bolts or lags)

D. Hardware

1. Missing washers and nuts 2. Burns around the bolts 3. Loose washers, nuts and locknuts on machine bolts 4. Crossarm pins out of arms 5. Location of ground wire near metal parts 6. Items bent, twisted, pulling out of or into support

E. Insulators

1. Chipped 2. Broken 3. Flashed over 4. Deteriorating 5. Floaters 6. Suspension insulators (cotter keys all the way in place)

F. Conductor Clearance (Horizontal, Vertical, Diagonal)


1. Above ground or water (note land underneath lines) a. Open ground b. Roads, driveways, parking lots c. Railroads d. Water

2. From buildings but attached 3. Conductor separation

a. Other conductors b. Communication and CATV wires c. Pole mounted equipment

4. Roofs, walls, windows, metal surfaces, etc. a. Buildings b. Tanks c. Towers d. Poles e. Grain bins

5. Trees

G. Conductors 1. Broken strands 2. Burns 3. Twisted 4. Ties 5. Shoes (dead end) 6. Sag 7. Armor Rod 8. Dampeners 9. Splices

H. Guys

1. Insulated or grounded 2. Markers (highly visible color, 8 feet long) 3. Loose or cut 4. Damage, broken strands 5. Condition of insulators (broken) 6. Anchor eye exposed 7. Location of insulators (below conductors, at least 8 ft above ground)

I. Equipment (includes transformers, switches (oil, vacuum, air), arrestors, etc.

1. Bushings (chipped, burnt, flashed over) 2. Hangers 3. Blown surge arrestors 4. Broken jumpers 5. Loose hot line clamp 6. Bulged tanks 7. Oil leakage 8. Loose nuts, bolts and missing hardware 9. Metal equipment grounded 10. Animal nests 11. Dead animals 12. Overloaded transformers


13. Accessible

J. Underground 1. Warning or caution signs in place (pad mounted transformers) 2. Equipment locked 3. Penta head bolts in place 4. Tipped padmount equipment 5. Tipped URD enclosures 6. Transclosures dead fronted 7. URD riser grounded if metal guard used 8. Metal brackets grounded 9. Metal cases grounded 10. Elbows grounded 11. Stress cones grounded 12. Dead end receptacle grounded 13. Bushing leaking oil 14. Arrestors (feed through) 15. Connectors (compression or mechanical) 16. Ground rod (connections, depth)

K. Substations

1. Clearances 2. Condition of fence and gates (Including washouts, crawl space) 3. Locks 4. Warning signs 5. Grounding of equipment 6. Grounding of fences and gates 7. General cleanliness (weeds, paint, gravel) 8. Storage of materials near structures and phases 9. Insulators 10. Buss works 11. Arrestors 12. Building or structures near fence

L. Miscellaneous

1. Vines on poles and guys 2. Clearance from pole to fire hydrant 3. Clearance to equipment to gasoline/LP storage 4. Climbable towers 5. Warning signs 6. Barriers 7. Proximity of poles or guys to traveled ways or parking 8. Junk piled near or under towers 9. Aircraft warning devices 10. Foreign objects blown or thrown into conductors 11. Abandoned facilities which should be removed

M. Obstruction on structures

1. Basketball hoops 2. Nails (spikes, posters) 3. Bird houses


4. Anything else that should not be on the structure

N. Grounds 1. Broken or disconnected wires 2. Wires loose on pole 3. Exposed rods

This list is not a substitute for common sense, observation, and judgement by the inspector.


Prairie Energy Cooperative

DISTRIBUTED GENERATION IDENTIFICATION FORM

Member Name (if known) E911 Address Generation Type (Wind, Solar, etc.)

Date


General Information Annual Report of Prairie Energy Cooperative Year ended Dec. 31, 2020

Please indicate (check appropriate box) either certification of compliance for each area of the cooperative’s inspection plan, or provide a detailed statement on areas of noncompliance with your cooperative’s inspection plan. See Iowa Administrative Code 199-25.3(2).

Compliance is certified as to each area of the inspection plan pursuant to Iowa Administrative Code 199-25.3(2).

Detailed statement of areas of noncompliance is as follows:

Utility official responsible for above certification or statement

Tim Marienau _____________CEO________________

(Name) (Title)


reliability plan, inspection and maintenance plan, and

Documents