Midland Power Cooperative’s Inspection and Maintenance

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March 24, 2020

Executive Secretary Iowa Utilities Board 1375 E. Court Ave Room 69 Des Moines, IA 50319

Filing Title: Midland Power Cooperative’s Inspection and Maintenance Plan and Reliability Plan

Dear Executive Secretary:

Pursuant to Iowa Administrative Code 199-20.18(8)a, Midland Power Cooperative is filing a revision to its Inspection and Maintenance Plan and Reliability Plan. This filing is being made to comply in full with the reporting requirement of Iowa Administrative Code 199-20.18(8) a. and 199-25.3.

We as the local board of directors take our responsibilities related to reliability as well all other aspects of our local electric cooperative very seriously. We are proud of our efforts and record related to reliability. This record of reliable service has been delivered because we are here to serve our member-consumers with reliable, affordable, safe, and environmentally responsible electricity. We are not here to maximize profits, as we are organized as a not-for-profit organization.

Please feel free to contact our general manager Bill McKim if you have questions 515-386-4111. These concerns will be conveyed to the local board of directors so we can respond appropriately.

Sincerely,

/s/ Bill McKim CEO Midland Power Cooperative

Filed with the Iowa Utilities Board on March 31, 2020, RE-0980

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To: Midland Power Cooperative Board of Directors

Inspection, Maintenance, & Reliability Plan

Adopted May 23rd, 2003

Updated March 6, 2020

Report is for Calendar year 2019


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1.0 Overview of Midland Power Cooperative’s Reliability Plan filed Pursuant to Iowa Administrative Code 199—20.18(8)"a" and 25.3.

Midland Power 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. Midland Power has its main office in Jefferson, Iowa.

Midland Power Cooperative provides distribution electric service to about 12,000 member-consumers in 19 counties in Central Iowa. Boone, Calhoun, Dallas, Franklin, Greene, Grundy, Guthrie, Hamilton, Hardin, Marshall, Polk, Story and Webster, Humboldt, Kossuth, Webster, Wright, Hancock & Pocahontas. Midland Power Cooperative

has about 3 of consumers per mile of distribution line. Midland Power Cooperative has an all requirements power supply contract with Cornbelt and Central Iowa Power Cooperatives. Cornbelt owns and operates the distribution substations in the northern part of our system and Midland Power Cooperative owns and operates the substations in the CIPCO supplied (Southern part of our system. The geographic areas served by both G&T’s are very rural in nature and vary between flat and hilly terrain. The area served also has a significant amount of vegetation including trees especially in the southern part of the system.

Member-consumers are able to contact the cooperative 24 hours a day, 7 days a week through the Cooperative Response Center which is a call center headquartered in Austin Minnesota, and has other call centers around the nation. 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)

Midland Power 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 the above as well as the resources available to achieve results.


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Midland Power Cooperative has made 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.

Midland Power has 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. No material changes were made to the program during 2018.

Midland Power adopted a written program in 2003 for inspection and maintenance of its electric supply lines, and substations (Midland does not own any generating stations) in order to determine the necessity for replacement, maintenance, and repairs that may be needed, as well as for tree trimming and vegetation management. No material changes were made to any of our programs during 2018.

Midland Power 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.

Midland Power 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.

Midland Power 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.

Midland Power 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.

Midland Power 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

Midland Power 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


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power requirement needs under normal operating conditions as well as certain contingency situations.

Midland Power 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 oversee 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 Midland Power Cooperative 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*; and 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.

Midland Power Cooperative is financed in part from the Federal Government through the United States Department of Agriculture, Rural Utilities Service (RUS) and as such is 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 8/14/14) 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


http://www.rd.usda.gov/files/UEP_Bulletin_1724E-150.pdf



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• 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 (91 Pages, Dated 6/2/2000) http://www.rd.usda.gov/files/1728f-806.pdf

• Specifications and Drawings for 12.5/7.2 kV Line Construction, RUS Bulletin1728F-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 6/7/01) 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

• Long Range Plan, RUS Bulletin 1724D-101A (87 Pages, Dated 2/16/17) 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 http://www.rd.usda.gov/publications/regulations-guidelines for more information on various RUS requirements.

2.2 Standards for Operation, Maintenance, and Inspection of the System

Midland Power Cooperative adopted a written program for inspecting and maintaining its electric supply lines and substations 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,




http://www.rd.usda.gov/files/1728f-806.pdf

http://www.rd.usda.gov/files/UEP_Bulletin_1728F-804.pdf


http://www.rd.usda.gov/files/UEP_Bulletin_1730B-

http://www.rd.usda.gov/files/UEP_Bulletin_1730-

http://www.rd.usda.gov/files/UEP_Bulletin_1724D-101A.pdf

http://www.rd.usda.gov/files/UEP_Bulletin_1724D-101B.pdf

http://www.rd.usda.gov/files/UEP_Bulletin_1730A-119.pdf

http://www.rd.usda.gov/publications/regulations-guidelines

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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.

Midland Power Cooperative Inspection and Maintenance plans are summarized in this Reliability Plan and include 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)

Midland Power Cooperative has electric supply lines in the following counties and parts of counties:

Boone, Calhoun, Dallas, Franklin, Greene, Grundy, Guthrie, Hamilton, Hardin, Marshall, Polk, Story and Webster, Humboldt, Kossuth, Webster, Wright, Hancock &

Pocahontas.

All facilities are managed from the 1005 East Lincolnway Jefferson, IA 50129 office, although local line personnel have been assigned specific responsibility for the operation and maintenance of their specific area.

In addition to the above Inspection and Maintenance plans, Midland Power 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 new construction to be certified by a registered


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professional engineer familiar with RUS standards) on a sample basis based on 15 % of the projects and 30% of the dollars.

2.2.1 Vegetation Management – Right of Way Maintenance Program

A licensed vegetation Representative of Midland Power Cooperative complete 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”.

Midland Power 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. Midland Power Cooperative

generally attempt to prune trees and manage vegetation on 20% of the system annually. This allows for a general schedule of having the entire system pruned and managed on an approximate 5 year cycle. (See attached schedule for a more detailed schedule related to vegetation management.) 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. For example, an ice storm in the Midwest can cause tree pruning contractors to be called away to address necessary pruning for safety or immediate reliability issues as a result of an ice storm in a restoration of service effort in another state or another region of Iowa.

Midland Power Cooperative service territory is divided into 4 “lineman service areas” with a line foreman assigned to each area. This foreman is responsible for scheduling of “Hot spot” trimming required for the assigned area. The Director of Operations inspects each area to ensure vegetation management is being scheduled as needed. Outages are also reported by service area and cause so that any trend can be monitored and corrected if necessary.

(Note: All areas need not be inspected at the same frequency if there are differences in the type and proximity of vegetation that make differing inspection frequencies reasonable.)


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2.2.2 Lightning Outage Mitigation Program

Midland Power is engaged in the practice of installing Lightning arresters on every third structure on three phase lines and every fifth structure on single phase lines, while bringing the equipment ground only up as far as the neutral. This reduces the amount of insulator flashovers and hence the amount of recloser operations in the process. This protection philosophy relies on lightning arresters to take over voltages to ground, before the recloser even has a chance to operate.

Midland power also installs an animal guard on each pole mounted transformer whenever one is set maintained. We do not keep statistics on this.

Midland Power 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 Supplier, Major Event, Scheduled, and All Other.

The category "scheduled" refers to interruptions resulting when a distribution transformer, line or owned substation is deliberately taken out of service at a selected time for maintenance or other reasons. The interruptions resulting from either scheduled or unscheduled outages on lines or substations owned by the power supplier, or its’ agent(s) are to be accounted for in the power supplier category. The category "major event" represents service interruptions from conditions that cause many concurrent outages because of snow, ice, or wind loads that exceed design assumptions for the lines. The "all other" category includes outages primarily resulting from emergency conditions due to equipment failure, malfunction, or human error.

Midland Power Cooperative recorded interruptions using the detailed standard codes for interruption analysis recommended by the United States Department of Agriculture, Rural Utilities Service (RUS) Bulletin 161-1, Table 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. Midland Power also has the capability to include the subcategories recommended by RUS for each of these major cause categories.

Midland Power Cooperative maintains 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 storms" and once without.


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We began using the National Information System Cooperative’s outage management program in the fall of 2004, and upgraded to IVUE OMS in July 2010.

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 (affected)

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


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.

Calendar Year 2015

SAIFI SAIDI CAIDI

System-wide (With Major Events)

1.3 134.8 103.6

System-wide (Without Major Events)

1.3 134.8 103.6


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Calendar Year 2016

SAIFI SAIDI CAIDI


1.39 246.5 177.4


1.39 159.44 134.3

Calendar Year 2017

SAIFI SAIDI CAIDI


1.35 162.8 121.03


1.25 135.9 108.28

Calendar Year 2018

SAIFI SAIDI CAIDI


1.23 166.9 135.32


1.23 166.9 135.32

Calendar Year 2019

SAIFI SAIDI CAIDI


1.305 156.674 120.056


1.292 149.492 115.705


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5 year Avg 15-19 SAIFI SAIDI CAIDI


1.315 173.53 131.48


1.292 149.306 119.44

NOTE: Note SAIDI and CAIDI above are expressed in minutes.

2.2.3 Animal Contact Reduction

Midland Power installs bush guards on all transformers in the field on an ongoing basis and after an animal has caused a power outage at that location. As the number of animal caused outages increase, Midland Power Cooperative is installing animal guards on all new services as well as those that have had an outage due to animals in the past. Midland Power Cooperative has not yet adopted an avian protection plan.

2.2.4 Line Inspection and Maintenance Plan Overhead Distribution Line Inspection Schedules, Coverage, Conduct of Inspections, and Instructions to Inspectors

Midland Power Cooperative 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. Midland Power Cooperative does not operate electric lines at or above 34.5 KV.

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. Midland Power Cooperative coordinates these inspections through Star Energy Services out of Alexandria, Minnesota.

All substandard conditions and violations of Iowa Electrical Safety Code requirements are noted and reported to management. As deemed necessary by Midland Power Cooperative prepares job orders and/or staking sheets that are then used to address the deficiencies found in a timely manner. The areas to be inspected are recorded on system maps, set up by substation service areas.


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

At the present time Midland Power Cooperative has approximately 200 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 Midland Power Cooperative’s line department.

In addition to the regular outage records, information is maintained to track faults in underground cable. This records information 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 5 years, Midland Power Cooperative has replaced approximately 18 miles of aging underground cable because of unacceptable numbers of faults.

In addition to the detailed line inspection every 10 years, Midland Power Cooperative’s maintenance crews complete a drive by inspection of the entire 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.

The electrical system operated at 34.5 kV or above shall be visually inspected at least once each year. The inspection shall include, but shall not be limited to, the following items:


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A. Pole condition at and above the ground B. Cross arm, insulators, and pole top hardware C. Conductor condition and sag D. Clearance to structure, grounds, and trees E. Guys, guy anchors and guy guards F. Ground connections G. Locks and seal

More detailed inspection and testing may be conducted as deemed necessary by the cooperative.

It is not the practice of Midland Power 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

Midland Power Cooperative owns and operates 27 distribution substations. Each substation is inspected once a month and a substation report form is completed. The Operations Department then reviews the substation report and maintenance is scheduled as required. The monthly substation inspection includes the following items:

• A visual inspection for each piece of equipment within the substation.

• A visual inspection of the fence/gate condition, signs, gate locks, lights, rock level, vegetation condition, material storage, and SCADA building.

• Power transformer information including temperature and pressure readings.

• Regulator information including counter reading, maximum and minimum drag hand positions, current drag hand position, and current voltage level.

• Recloser counter information.

During substation inspections, the following conditions should be reported:


http://www.iowastrayvoltageguide.com/

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1) Power Transformer(s): a) Signs of any oil leakage b) Chipped or damaged bushings c) Oil level d) Oil temperature, record maximum temperature and reset e) Gas pressure f) Signs of any animal nests

2) Voltage Regulators or tap changers

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

3) Reclosers

a) Signs of oil leakage b) Cracked or damaged bushings c) Record operations counter

4) Air Break Switches

a) Ground missing from handle b) Damaged insulators

5) Disconnect and By Pass switches

a) Insulators damaged

6) Miscellaneous a) Arrester connections need repair b) Arrester is chipped or damaged c) High Side fuses are not intact, and/ or no spares are available d) Buss insulators are cracked or damaged e) Animal nests in buss work f) Equipment grounds are damaged or missing g) Clearances (visual inspection for obvious clearance violations)

7) Yard and Fence

a) Holes under fence b) Fence and barbed wire grounds missing or damaged c) Gate grounds are missing or damaged d) Gates do not lock properly, or were unlocked e) Warning signs—readable or missing from fence (needed on all four

sides & entrance)


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f) Exits and/or driveways are obstructed g) Material not stored within substation or properly fenced h) General appearance of yard is not acceptable i) Fence is rusty, and needs repair or painting

Midland Power’s northern portion is served by 28 additional stations on the northern part of our system. These subs are owned by Cornbelt Power and inspections of these stations are conducted by Cornbelt.

In addition to recording the above information, all regulator and tap changer controls are checked during the monthly inspection to verify they are working properly.

Midland Power Cooperative also conducts preventive substation maintenance program that test the integrity of the insulating oil and allow Midland Power

Cooperative to monitor and trend the results over time. The current schedule calls for tests to be performed on an annual cycle.

2.2.6 Pole Inspection and Treatment Schedules, Coverage, Conduct of Inspections, and Instructions to Inspectors

Midland Power 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. Generally, Midland Power Cooperative tests and treats when a pole reaches 10 years of age. All poles scheduled for rebuild in the current construction work plan are not treated. The inspections are done on an area basis with all Cooperative owned poles, within a given area, being inspected in the designated year. The following table shows the pole treatment history for past years as well as the most current year. The completed table and supporting details are maintained at the cooperative office.


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Year

Poles on System

Poles

Treated

Poles

Rejected

Poles

Replaced

Rejection

Rate

Totals Including Non

Excavated Poles

2007 62,214 2663 76 76 2.85% 2739

2008 62,290 2571 51 51 1.9% 3524

2009 63,200 3110 51 51 1.65% 3660

2010 62,442 3245 53 53 1.60% 4018

2011 62,700 3064 66 66 1.8% 3618

2012 63,084 3090 56 56 1.31% 4269

2013 81,960 4034 71 71 1.40% 5117

2014 81,980 3185 86 86 2.1% 3981

2015 85,152 4083 136 136 2.47% 5485

2016 88,066 2642 36 36 1.0% 3569

2017 88,371 3807 105 105 1.96% 5359

2018 88,390 4646 174 174 1.82% 9546

2019 88,390 4284 101 100 1.17% 8654

There were 101 rejected poles identified in our inspection and treatment program for 2019, and all have been replaced.

Ground line Inspections and treatments are done by outside contractors. Midland Power Cooperative plans to include the treatment database in its future map based electronic record system.

2.2.7 Meter Testing

Midland Power 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 and associated devices 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%


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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. Midland Power 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 Midland Power Cooperative in its meter inspection and testing program, Midland Power 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.

Midland is currently engaged in an RF mesh AMI system, and all meters have been tested at the factory. We will begin statistical sample testing of these meters in 2019 or soon after full deployment of the system is completed. We expect to complete a significant portion of this endeavor in 2018, but it is possible that It could take into 2020 to get this fully completed

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.

2.2.8 Oil Circuit Reclosers and Sectionalizers

Midland Power Cooperative has a maintenance program in which all oil circuit reclosers and sectionalizers on the Cooperative’s system are scheduled for maintenance every four years. The units are disassembled, inspected, repaired as necessary, filled with new oil, cleaned, painted and tested under field conditions to ensure they are operating within their stated operating characteristics. 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 Midland Power Cooperative system and the number serviced for the past five years. The completed table and supporting details are maintained at the cooperative office.


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Total Reclosers

Year &

Sectionalizers Total

Serviced on System

2015 1338 311

2016 1338 360

2017 1338 337

2018 1338 324

2019 1338 314

2.2.9 Infrared Inspection (Optional)

Midland Power Cooperative at its option, completes an infrared inspection of all substations at least every year. Midland Power has an employee that is trained in the FLIR system to do these inspections with the latest inspection occurring in 2018.

In addition to testing the substations, overhead and underground line equipment is checked on an as needed basis as the contractor moves between substations. All major underground equipment cabinets are opened and inspected as part of the 10 year underground inspection program.

2.2.10 Planned Interruptions

Planned interruptions are scheduled at the most convenient time for customers and Midland Power Cooperative representatives. Any interruption scheduled for more than one hour is preceded by adequate notice to those customers who will be affected. This notification is usually done by phone or letter.

2.2.11 Supervisory Control and Data Acquisition (SCADA)

Our SCADA system allows Midland Power Cooperative to monitor voltage and current values by circuit and phase for 40 of our 55 substations. The other stations are on the CIPCO side and although we are extending SCADA to all stations, these other 15 have not been completed as yet. We expect they will be completed in 2020. 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. 7 substations have electronic reclosers installed that allow Midland Power Cooperative to operate the reclosers from the Operations Center in the case of an outage and reduce outage time and improve customer reliability. Midland is also in the process of installing SCADA operated switches at certain points on the system that will allow for automatically switching load if there is a transmission outage to the substation.


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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 Midland 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 the 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. Midland’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. The Engineering and Operations department is 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

Midland 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, Midland will investigate and take actions to rectify the problem as it relates to facilities owned, operated, and maintained by Midland. In addressing harmonics problems, Midland will implement to the extent practicable and in conformance with prudent operation the practices outlined in the above standard.

2.2.14 Power Quality



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Midland has adopted the IEEE Standard 1159-2009, IEEE Recommended Practice for Monitoring Electric Power Quality, or any successor standard. Midland will investigate power quality complaints from its member-consumers and determine if the cause of the problem is on it’s system. When power quality problems arise, we will investigate and take actions to rectify the problem as it relates to facilities owned, operated, and maintained by us. In addressing power quality problems, we 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, Midland receives very few radio interference complaints. Each complaint is investigated using by the Cooperative using detection equipment.

2.2.15 Load Studies and Planning

In order to continue to provide reliable service to Midland’s customers in the future, the Engineering Department develops both short and long-range plans. The current Construction Work Plan was completed in the year 2018 and covers the years 2019 thru 2022.

Star Energy Services prepared the Cooperative’s current long-range plan in 2018. The long-range plan covers the years of 2019-2038.

The latest Sectionalizing Study was completed in 2018.

Milsoft Windmill computer software is used to perform system studies and analyze voltage profiles and amperage loading on each circuit within Midland’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

Midland 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 continuous basis along with the model. We use I pads in the trucks for lineman use in the field and don’t print map books any longer.

2.2.17 Emergency Restoration Plan


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Midland 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 response to 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))

Midland 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.

Midland 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. Midland also has the capability to


Page 23

include the subcategories recommended by RUS for each of these major cause categories.

Midland 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


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


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.

Midland 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 Midland 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. Midland 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


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well. This mission is accomplished through a variety of communications tools and methods.

• Governance—Midland is organized as a cooperative and is governed as such.

The member-consumers govern the organization. Midland has a board of directors comprised of 12 member-consumers. Midland Power Cooperative is organized by having 4 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 Midland Power 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.

• District & Annual Meetings — Every year, Midland Power Cooperative

conducts an annual meeting. During these meetings, Midland Power 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. Midland Power 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 Midland Power 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 Midland Power 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 — Midland Power Cooperative

• Midland Power Cooperative notifies members of planned interruptions of service. Planned interruptions are made at a time that will not cause


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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

Grain Bin Notices — Midland Power Cooperative

• Midland Power 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.

• Day-to-day Contact Call Centers — When a cooperative receives an inquiry about service that requires the provision of information related to reliability Midland Power 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 farmers 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


http://www.iowarec.org/outages

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Federation, and Iowa State Dairy Association. A copy of said publication can be obtained by contacting the Cooperative or through: www.iowastrayvoltageguide.com.



Page 27

Midland Power Cooperative YEARLY WORK SCHEDULE

Year:

January February March

April May June

July August September

October November December


2018 Pad-Mount Inspection

Maintenance Pad-Mount Report

V - Visugl Inspection VI - Visual Interior frispeflion VG - Visual Reject VIX - Visual Int:error Be/eel

Maintenance fssves tad- Wount nlotes Woint. Reformed Work Order No.

1 258273

Transformer ' VI

Needs Leveling

2 2S8257

Transformer , Vi

Needs Leveling

258249 , Transformer , V) , Needs Leveling .

6 258235 ' Transformer

V)

Needs Leveling

6 2g 8268 : Transformer , Vl , Needs Leveling

37 2S9320

Cabinet

8lown Arresto r

69 257568

Transformer , VI ' NeedsLevetng

69 257223

Transformer , VI

Other, See Notes Heat ed secondaries

262807 : Transformer I V1

Needs Leveling

70 257597 ’ Transformer , VX

R usted Through ' Added Bolt

76 2S7571

Transformer ' VI

Needs Leveling

76 257573

Transformer

VI

Oil Leak See picture ,

76 257566

Transformer . VI

Needs Leveling Cover hard to close Added Bolt

257582 , Tra nsformer . UI

Other, See Notes No locking mechanism

2038 had-ffourt Inspection - fnintenorice Ppd-fPJovut Report Prefered fgr t9tidlgnd Power Cooperative

By $ EA R Energy Services LtC


2018 Pole Inspection

Maintenance Poles Report

CA - Carpenter Aerr CPA - Cust. Insp. recommended CNT - Con’t Yreot

OCA - Oelectiv'e Cross Arm OG - Broken/Oefective Guy Vttire OGR - Oe/eetive Ground Rod DGw - Broken/oe(. Ground Wire ott - oe(./Loose /Missing Hardcore Al - Broken/oefective Insulator

DR - Oetoyed Rocket

ECC - Excessive Checkin g/Cracking ER - Enclosed Oecoyed Packet ERA - Enclosed Rocket Above G/I re - frayed Conductor ro - Eire Oomage IN - rence GAR - Garden I-IB - be en Not

HRA - Heart Rot Above G/L ID - Internal Decay iDA - Internal Oetay Above G/L IBM - Install Guy Marker UR - Install Ground Rod

£P - leaning Pole toegreeJ

MDA - Tech. Oomoge Above G(L MGG - Wishing buy Guard

NA - No Access 01 - Other Insects PV - Pavement g8 - Excessive Porfr/storm Boro/ill RGW - Repair Grounding t4/ire RKS - Rocks

Rk - ftemove )/egerotion SR - Stiell Rot sne - snell not above c/r

SRC - Shell Rat Chipped SRS - Shell Rat 5haued ST - fp£it Top 5T8 - $pJit 7'op Bolt 5IN - 5tenciling TIW - ZreesJines in t47ires OR - Vermin/Rrivate Rraperty tJCR - Underground Coble-Riser EA £ - t4/ater WB - Wood forers

I4" PH - Woodpecker Holes WS - Wind Shoke

Wap Role No. Vear Type Ht. Class Insp. Remarks Pole Notes Assemblies Work Order Initials Oate

1 264985 1973 SP P 3F 4

ST8 C1.11, M2-1

1 26*996 1969 SPP 3S •

ST8

. CI.11, M2-1

1 265053 1984 SPP 3S 6

P ' Other ' Neutral insulator bent downward

1 265054 1984 SPP 3S 6

P ' Other ,

Neutral insulator bent down AI.1

1 265056 J984 SPP 35 6

DH

Missi rig nut

1 264862 1984 SPP 35 5

DH

Missing nut on neutral

1

264871

1984

SPP

35

5

'

DH

Missing not on pole top pin bolt A1.1

1 265066 1950 SPC 35 6 , P ST8

1

266314

1950

DFC

35

6

A2.1, M2-1

2028 Pofe Inspection - Ilfa7ntenonce Poles fteport ‘ °°°

Prepared for tviidland t•ower Cooperative By S FAR Ener9y Seruites LLC

V - Visuat Inspection B - Bored 7 - Treated Excavate P - Partial vx - RisvoJ Reiect BD - Bored j'Oebayed ID - erected fxcocote/oecoyed pO - Rgrtial Excguote with Oecoyed S - Sound BE - Bored Reject x - £xrov‹rfed Reject PM - Partial Excavate Reject


Midland Power Cooperative MONTHLY SUBSTATION INSPECTION SCHEDULE

SUBSTATION LOCATION

INSPECTION SCHEDULE AND CURRENT STATUS

2013 2014 2015 2016 2017

JAN JAN JAN JAN JAN

FEB FEB FEB FEB FEB

MAR MAR MAR MAR MAR

APR APR APR APR APR

MAY MAY MAY MAY MAY

JUN JUN JUN JUN JUN

JUL JUL JUL JUL JUL

AUG AUG AUG AUG AUG

SEPT SEPT SEPT SEPT SEPT

OCT OCT OCT OCT OCT

NOV NOV NOV NOV NOV

DEC DEC DEC DEC DEC

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NOTE: If the cooperative inspects all substations each month this schedule is not necessary. Report on “Yearly Work Schedule”.

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


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MONTHLY SUBSTATION INSPECTION

Substation Name:

Power Transformer(s) Position

A Phase

B Phase

C Phase

A Phase

B Phase

C Phase

Regulators

Position Voltage

A Phase

B Phase

C Phase

LTC Position Voltage

A B C

Primary Fuses Fuse Holders (Loaded)

Spare fuses

Fuse sizes

Remarks:

Inspected by:

Gate Locked

Date

Temp “X

” if

OK

Power Trans. Winding Liquid Pressure c

ircuit #

1

circuit #

2

circuit #

3

circuit #

4

circuit #

5

circuit #

6

Power Transformer Breaker

Appearance Appearance

Bushing Clean Bushing Clean

Bushing Good Cond. Bushing Good Cond.

Oil Leaks Oil Leaks

Auxiliary Cooling Cabinet Weather Tight

Bird Nests Door Locked and Working

Buss Work Ground Connections

Buss Connections Oil Level

Arrestors

Door Closed Air Break Switches

Appearance

Voltage REG A Phase

Handle Grounded

Appearance Insulators Good Condition

Bushing Clean Switches Hat Grounded

Bushing Good Cond. Structures Good Cond.

Oil Leaks Structures Grounded

Cabinet Weather Tight Buss Work

Indicating Glass Cover Buss Connections

Ground Connections Arrestors

Oil Level Underground Riser

Voltage REG B Phase

Fences

Appearance Grounded

Bushing Clean Gates Locked and Working

Bushing Good Cond. Wire Tied to Posts

Oil Leaks Warning Signs

Cabinet Weather Tight Free of Weeds

Indicating Glass Cover Child Proof Around Bottom

Ground Connections

Oil Level Yard

Free of Weeds

Voltage REG C Phase

Free of Litter

Appearance Material Stored Neat

Bushing Clean Rock Level

Bushing Good Cond. Lights All Work

Oil Leaks Lightning Rod Grounded

Cabinet Weather Tight Border Neat

Indicating Glass Cover

Ground Connections Station Power Transformer

Oil Level Appearance

Grounded

Oil Leaks


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Midland Power Cooperative

Substation Inspection Form – Page 2

Regulators Counter Operations Max Raise Min. Lower React. Resist. A Phase

B Phase

C Phase

Recloser Counter Readings Circuit #1 Circuit #2 Circuit #3 Circuit #4 Circuit #5 Circuit #6 A Phase

B Phase

C Phase


Page 31

Midland Power Cooperative

DISTRIBUTED GENERATION IDENTIFICATION FORM

Member Name (if known) E911 Address Generation Type

(Wind, Solar, etc.) Date


Page 32

General Information

Annual Report of Year ended Dec. 31, 20

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:

(Insert additional sheet(s) as needed, to indicate various dates/regions of staggered cycles, if desired.)

Lines above 34.5 kV Substations General inspection of distribution (under 34.5 kV) lines Testing of each pole Neutral to soil resistivity tests (Add other categories as needed)

A. B. C. D. E. F.

OPTIONAL – indicate estimated date (month and year) of completion of next cycle of periodic inspection, replacement and repair of electric plant in the following categories to facilitate staff audit of compliance:

(Title) (Name)

Utility official responsible for above certification or statement


Documents

Midland Power Cooperative’s Inspection and Maintenance