Contents: Macon Electric

Transcription

1 Contents: Macon Electric Section 1: Introduction... 2 Section 2: Asset Inventory... 5 Section 3: Risk Assessment... 8 A. Historical Hazards... 9 Tornadoes... 9 Severe Thunderstorms, High Wind, and Hail Flood and Levee Failure Severe Winter Weather B. Non-historical Hazards Wildfire Earthquakes Dam Failure C. Risk Assessment Summary Section 4: Mitigation Strategies Previous Mitigation Efforts Existing and Potential Resources Review of Goals, Objectives, and Actions Section 5: Plan Implementation and Maintenance Plan Incorporation Local Planning Capabilities Plan Maintenance Continued Public Involvement Opportunities Appendix: A - Adoption Resolution Appendix: B - Documentation of Participation Appendix: C - Surveys Data Survey Goals, Objectives and Actions Survey... 43

2 MACON ELECTRIC COOPERATIVE Section 1: Introduction During May of 1938, the Macon Electric Cooperative (MEC) was formed to meet the electrical needs of customers in north central Missouri. MEC s headquarters are located in Macon, Missouri. Service is provided to customers in nine counties in north central Missouri: Adair, Chariton, Knox, Linn, Macon, Monroe, Randolph, Shelby and Sullivan. A nine member board of directors provides direction for the cooperative and has approved the following mission statement: Our mission is to provide excellent service to our members in the most efficient manner possible. The MEC service territory consists of approximately 2,887 miles of energized line which serves customers in at least a portion of Adair, Chariton, Knox, Linn, Macon, Monroe, Randolph, Shelby and Sullivan counties. Figure 1 depicts the geographic boundaries of the cooperative in relation to USGS local quadrangles within the state of Missouri. (Map sources: Association of Missouri Electric Cooperatives, Macon Electric Cooperative.) Figure 1 MEC Cooperative Boundaries MEC currently has more than 11,247 connected meters and exceeds 9,897 members in the nine-county service area. Residential customers account for 88% of memberships while non-residential customers make up the remaining 12%. Table 1 on the next page shows the Summary of Meters by County in the Macon Electric service area. MEC Page 2

3 Table 1 Summary of Meters by County County Number of Meters Adair 14 Chariton 995 Knox 15 Linn 854 Macon 5,216 Monroe 718 Randolph 1,111 Shelby 2,272 Sullivan 52 Total 11,247 For the 2017 plan update, MEC indicated that their average daily residential customer usage is 37 kilowatt-hours (kwh) and the average annual total usage of MEC residential customers was 13,284 kwh of service which is the same data as in 2010 plan. Population density for the cooperative service area is depicted in Figure 2 (Map source: U.S. Census 2010). Figure 2 Population Density Map

4 Critical Facilities It is important in mitigation planning for the Electric Cooperatives to identify the critical facilities in each area and to be able to prioritize reconnection and back-up power needs. The MEC provides service to critical facilities that include nursing homes, emergency services, telecommunications, schools and storm shelters that were invited to participate in the public comment period. Future Development Macon Electric indicated that they are not aware of any plans for future development in their service area. Table 2 below illustrates the population trend for the counties served by MEC. Table 2 County Population Trend, Planning Process County Year Trend ( ) Adair 24,577 24,977 25,607 2% Chariton 9,202 8,438 7,831-8% Knox 4,482 4,361 4,131-4% Linn 13,885 13,754 12,761-4% Macon 15,345 15,762 15,566 1% Monroe 9,104 9,311 8,840-1% Randolph 24,370 24,663 25,414 2% Shelby 6,942 6,799 6,373-4% Sullivan 6,326 7,219 6,714 3% Source: U.S. Census Data Since the planning process is the same for each of the electric cooperative plans, the details of the planning process are presented in the Statewide Summary section of the plan. Appendices Three appendices are included at the end of the each plan: Appendix A contains the Adoption Resolution; a document signed by the Cooperative s governing official showing that the Board of Directors has adopted the mitigation plan. Appendix B contains the Documentation of Participation; copies of press releases, website postings and other public outreach that was made to request public comment. Appendix C contains the Surveys; the Data Survey that is the source of data for the 2017 plan update; the Goals, Objectives and Actions Survey is the updated review of the mitigation strategies.

5 MACON ELECTRIC COOPERATIVE Section 2: Asset Inventory Macon Electric Cooperative has a wide variety of assets. Real estate owned by the company includes office buildings, warehouses, garages and other outbuildings throughout the service area. Forty-three vehicles provide access to customers and infrastructure. MEC does not own any electric generation or transmission infrastructure. MEC owns and maintains 887 miles of distribution lines. Table 3 provides information concerning total asset valuation. Table 3 MEC Inventory Valuation Summary Asset Total MEC Assets Distribution Lines Total Replacement Cost $135,486,464 $54,320,000 OH $1,780,000 UG Cost Breakdown Buildings and vehicles - $8,606,550 Overhead assets - $123,928,585 Underground assets - $2,951,329 OH Single-phase lines - $40,740,000 UG Single-phase lines - $1,680,000 OH Three-phase lines - $13,580,000 UG Three-phrase lines-$100,000 Supporting Infrastructure $69,608,585 OH $1,171,329 UG Meters - $3,884,383 Poles - $24,512,000 OH Transformers - $11,658,570 UG Transformers - $562,914 Guys/Anchors - $1,623,238 Cross-arms - $ Regulators - $552,080 SP Oil-Circuit Reclosures - $1,090,177 Capacitors - $43,507 Other OH Assets - $25,827,578 Other UG Assets - $608,415 Office Buildings $3,682,250 Warehouses $1,000,000 Vehicles $3,924,300 Source: Internal Macon Accounting and Insurance records, 2016 Ensuring quality distribution to its customers, Macon Electric Cooperative maintains not only distribution lines, but also the supporting infrastructure as well. MEC Page 5

6 MACON ELECTRIC COOPERATIVE Table 4 includes a list of asset types, emergency replacement cost per unit or mile, the asset inventory by Service County, and total infrastructure numbers. Table 4 MEC Asset Inventory by Service County Asset Emergency Replacement Cost per unit or mile No. of units or miles: ADAIR No. of units or miles: CHARITON No. of units or miles: KNOX No. of units or miles: LINN No. of units or miles: MACON Meters ,216 Poles 144 6, ,756 $24,000/mile OH SP*** distribution line ($7.35/foot OH) 6.7 OH OH 9.1 OH OH OH $24,000/mile UG 7.25 UG.2 UG 4 UG UG ($7.35/foot UG) $45,000/mile OH OH TP**** distribution line OH ($11.50/foot OH).1 UG.5 UG Transformers 20 OH 1,010 OH 21 UG 20 OH 2 UG 850 OH 25 UG 5,500 OH 220 UG Guys/anchors $92.60/unit 44 1, ,975 6,200 Cross-arms $ , Regulators $8, Oil Circuit Reclosures $1,500 SP Capacitors $440/unit Total Replacement Value by County $240,108,438 $11,217,321 OH $213,560 UG $321,975 OH $6,429 UG $13,033,127 OH $130,070 UG $54,727,096 OH $1,677,625 UG MEC Page 6

7 Asset No. of units or miles: MONROE MACON ELECTRIC COOPERATIVE No. of units or miles RANDOLPH No. of units or miles SHELBY No. of unites or miles SULLIVAN Total no. of units or miles: Meters 718 1,111 2, ,427 Poles 4,400 9,000 11, ,000 SP*** Distribution Line 185 OH* 4 UG** OH 9.1 UG OH 10.5 UG 8 OH.1 UG OH 89.4 UG TP**** Distribution Line OH 65.5 OH 2 UG 132 OH 1.25 UG 1.25 OH OH 3.85 UG Transformers 775 OH 22 UG 1,200 OH 55 UG 550 OH 60 UG 45 OH 2 UG 11,965 OH 407 UG Guys/anchors 1,345 3,780 2, ,512 Cross-arms ,740 Regulators Oil Circuit Reclosures Capacitors Total Replacement Value by County $9,050,713 OH $125,615 UG $13,200,571 OH $393,400 UG $21,743,607 OH $400,672 UG $394,154 OH $3,957 UG $123,928,585 OH $2,951,329 UG *OH = overhead **UG = underground ***SP = Single phase ****TP Three phase Source: Internal Macon Accounting and Maintenance records MEC Page 7

8 MACON ELECTRIC COOPERATIVE Section 3: Risk Assessment Risk Assessment Methodology The risk assessment methodology used in the following section was utilized for both the statewide aggregation as well as for each individual cooperative chapter. Section 4 of the Statewide Summary details this methodology. Some variation in the availability of data exists between the electric cooperatives as each utilizes a different system of recording the impact of natural disasters. Any differentiation from the process below is explained in the individual cooperative s chapter as necessary. For the purpose of this risk assessment, the identified hazards for the MEC service area have been divided into two categories: historical and non-historical hazards. Based on the data collected for the update, the hazards have been reclassified to reflect the actual data available and those hazards with no data available have been reclassified as non-historical. This does not mean that a non-historical hazard will never cause damage; it just means there have been no impacts prior to this report. The potential still exists, but the probability of the occurrence is numerically near zero. For the analysis in this plan nonhistorical hazard probability is stated as less than one. Historical Hazards are those hazards with a measurable previous impact upon the service area. Damage costs per event and a chronology of occurrences are available. The associated vulnerability assessments utilize the number of events and cost of each event to establish an average cost per incident. For MEC, hazards with historical data include tornadoes, severe thunderstorms/high wind, flood/levee failure and severe winter weather. Non-historical Hazards are hazards with no previous record of impact upon the local service area. As such, the associated vulnerability assessments for each of these hazards will have an occurrence probability of less than 1% in any given year, but the extent of damage will vary considerably. For MEC, hazards without historical data include earthquakes, dam failure and wildfires. Each hazard has a unique impact upon the service area, requiring each hazard to utilize a different valuation amount depending upon the level of impact. Non-historical hazards assume damage to all general assets. For Historical Hazards, assets were divided into two groups based upon historical impact which were utilized in the hazard damage analysis: Overhead infrastructure assets and buildings o Used for: Tornado damage assessments Valued at $128,610,835 Overhead infrastructure assets only o Used for: Severe Thunderstorm / High Wind / Hail Flood Severe Winter Weather Valued at $123,928,585 MEC Page 8

9 MACON ELECTRIC COOPERATIVE A. Historical Hazards Tornadoes Previous Occurrences From , there have been 36 tornadoes reported within the Macon Electric Cooperative boundaries. Figure 3 provides a pictorial representation of all recorded tornado touchdown sites and recorded path. (Data for map collected from National Oceanic and Atmospheric Administration, NOAA.) Figure 3 Tornado Map Probability of Future Occurrence and Vulnerability In a 67 year period, 36 tornadoes yield a probability of 53.7% that a tornado will develop in the MEC service area in any given year. Macon Electric has not provided any records on damages or outages as a result of tornadic activity. According to NOAA s Storm Events Database, Macon County has suffered over $1.8 million in estimated property damages over the twenty-year period, June 1998-June Therefore the possibility MEC Page 9

10 MACON ELECTRIC COOPERATIVE of damage to MEC assets cannot be ruled out. If a one percent loss is projected, this would be $1,286,108 in overhead and building losses for the cooperative. With the most current number of meters reported as 11,247, a one percent outage rate would result in 112 meters experiencing outages. Problem Statement MEC has been fortunate to have such a low number of tornadoes touch down in their service area when numerous more storms have hit the surrounding areas outside of their boundaries. MEC should continue to strengthen their infrastructure using manufactured poles and underground placement of lines. Severe Thunderstorms, High Wind, and Hail Previous Occurrences From , the Counties of Chariton, Macon, Randolph and Shelby in Missouri have experienced a112 days of hail events and 105 days of thunderstorm/high wind events. Probability of Future Occurrence and Vulnerability Therefore, the average annual number of hail events in these counties is 5.6. The average annual number of high wind event days is 5.3 MEC staff reported that there were no material damages associated with a thunderstorm/high wind event resulting in a less than 1% probability that any given thunderstorm/high wind event. Two of the 112 occurrences caused damage to cooperative assets, resulting in a 1.8% probability that any given hail occurrence will produce damage. In any given year the probability of a damaging hail storm is 10%. Table 5 provides a summary of those hail events which caused damage to cooperative infrastructure by date, cost estimate of damage and reported outages. Table 5 MEC Hail Event Summary Event date Damage estimates Outages reported 02/27/11 $250,000 N/A 06/27/11 $500,000 N/A Total $750,000 Data provided based on internal MEC records which reflect cost from the referenced event year. Based upon historical records, thunderstorm hail events will cause an average annual damage of $37,500. This averaged amount accounts for less than 0.1% of Macon s overhead asset valuation of $123,928,585. Although no damages were reported due to high wind events, the probability of these events is similar to that of hail events; therefore it can be projected that losses of less than one percent can be expected from wind storms. Due to a lack of data for customers reporting outages during recorded hail, thunderstorm, and high wind events, the probability of customers reporting outages in any given year was put at less than 1%. MEC Page 10

11 MACON ELECTRIC COOPERATIVE Problem Statement Although there is strong chance of a potentially damaging thunderstorm with high winds in any given year, no damages have been recorded by MEC for this hazard. Continued monitoring of infrastructure is recommended to maintain uninterrupted service to its customers. Flood and Levee Failure Flood and levee failure carries a minimal ongoing potential threat to the existing infrastructure of the Macon Electric Cooperative. In the cooperative service area, approximately 18% of the area is located directly within the 100 year floodplain. The remaining service area is not located within the 100 year floodplain. Figure 4 below depicts the 100 year floodplain in relation to the cooperative s boundaries. (Map sources: FEMA National Flood Layer) Figure 4 Floodplain Map Currently, inundation data for levee failure is lacking due to issues surrounding mapping, appropriate models, and its close association with flooding events. Figure 5 below provides the location of known MEC Page 11

12 MACON ELECTRIC COOPERATIVE state and federal levees within the cooperative s boundaries. (Map sources: MSDIS, National Topic Map ESRI.) Figure 5 Levee Map Previous Occurrences From , the Counties of Chariton, Linn, Macon, Randolph and Shelby reported 125 days of flooding events. These included both flash floods and riverine floods. NOAA estimated $21,000 in property damage from these events. Probability of Future Occurrence and Vulnerability An average annual 6.3 days of flood events occurred during this twenty year period. However MEC did not report any damages or outages due to flood events for the cooperative. If a one percent loss is projected, this would be $1,239,286 in overhead losses for the cooperative. With the most current number of meters reported as 11,247, a one percent outage rate would result in 112 meters experiencing outages. MEC Page 12

13 MACON ELECTRIC COOPERATIVE Problem Statement With numerous flood-prone rivers crossing its area, MEC needs to waterproof assets when possible. Severe Winter Weather Previous Occurrences From , the five counties, where over 97% of MEC s meters are located, experienced a total of 49 days of severe winter weather events, including a blizzard, heavy snowfalls and ice storms. Over $1 million in NOAA estimated property damages occurred as a result of these storms. Probability of Future Occurrence and Vulnerability The probability of a severe winter weather event in the Macon service area in any given year is 100% with an average annual of 2.5 days of events. MEC staff analyzed material damages associated with each of these events and determined no damage or outages occurred due to severe winter weather events, resulting in a less than 1% probability that any given severe winter weather event will result in damage to cooperative assets. No customers reported outages during recorded severe winter weather events. Due to a lack of data for customers reporting outages during recorded severe winter weather events since 1997, the probability of customers reporting outages in any given year was assumed to be less than 1%. Problem Statement Ice storms typically play havoc on electric cooperative s overhead assets. With the historical record showing that numerous ice storms have occurred in the service area, MEC should considerate underground placement of assets when feasible. MEC Page 13

14 MACON ELECTRIC COOPERATIVE B. Non-historical Hazards Wildfire Previous Occurrences The incidence of wildfire in the Macon Electric service area presents a unique risk assessment. Wildfire events have occurred in each of the nine counties. For this hazard Adair, Knox, and Sullivan Counties were not included as less than 1% of MEC meters are located within those counties. The total area of the rest of the counties is included in the table as wildfire data for just within the MEC boundaries was not available. Table 6 summarizes the incidences of wildfire within the six counties. Table 6 Wildfire Summary by County County # of Wildfires, Average Annual # of Wildfires Acres Burned Average Annual Acres Burned Total Buildings Damaged Chariton , Linn , Macon , Monroe , Randolph , Shelby Totals ,150 1, Source: Missouri State Hazard Mitigation Plan, 2013 Probability of Future Occurrence and Vulnerability The probability of a wildfire event in the Macon service area in any given year is 100% with an average annual of 92 wildfires throughout the six-county area. Although MEC does not have records of any significant damage from wildfires, for the purposes of this assessment, wildfire and its associated impacts cannot be eliminated from the realm of possibility. The potential extent of damage caused by wildfire is difficult to determine. With an average annual of 1,350 acres burned in the area, and a total six-county area of 2,041,600 acres, it is unlikely that infrastructure damage would exceed one percent based upon asset location and the unlikeliness of an uncontrollable wildfire. No customers have reported outages during recorded wildfires. When compared with the total number of customers served by Macon Electric Cooperative, it can be projected that less than 1 percent of all customers may report outages during any given wildfire event. Problem Statement Further study will be required to create a model for damage assessments related to wildfire. MEC Page 14

15 MACON ELECTRIC COOPERATIVE Earthquakes Previous Occurrences The closest source of earthquake risk in central Missouri is the New Madrid Fault located in extreme southeast Missouri, which has, according to many experts, the potential to produce the largest earthquakes in North America. Undoubtedly, this fault has the potential to affect the MEC service area in its entirety. In addition, there have been several small, virtually undetectable earth movements in the region in recent history, which may or may not be attributed to the aforementioned fault lines or other, very small faults located nearby. A pair of earthquakes occurred on February 8, 2004 with magnitudes of 2.9 and 2.3. These were centered near Paris in Monroe County near the MEC service area. Probability of Future Occurrence and Vulnerability While the Nemaha fault is geographically closer and geologically active, C.E.R.I. records demonstrate the limited impact of said earthquakes, with no quakes to date exceeding a 5.5 magnitude. Its cascading effects have been largely restricted to more localized regions, but even then the damage caused has been minimal. By contrast, the New Madrid fault has the potential to cause damage throughout the state of Missouri, including the MEC service area. Scientists from the U.S. Geological Survey (USGS) and the Center for Earthquake Research and Information (CERI) at the University of Memphis have estimated the probability of a magnitude 6.0 or greater earthquake from the New Madrid Fault is percent through the year The projected earthquake intensity ratings for the cooperative region changes based upon the Modified Mercalli Scale. Given a New Madrid earthquake with a 6.7 magnitude, the region would experience Level V intensity characteristics. In the event of an earthquake with a 7.6 magnitude, the region would experience Level VI intensity characteristics while an earthquake with an 8.6 magnitude would most likely cause Level VII intensity characteristics. In the event of an earthquake with a 7.6 magnitude, the MEC service area would most likely experience minor building damage as well as damage to the electrical distribution system. This damage, however, would most likely be relatively minimal and localized when compared with the southeast corner of the state. Distribution lines overhead and underground could become disconnected or severed, and transformers could be damaged. Based upon information from CERI, FEMA, and SEMA, it may be estimated that 1,125 customers could report outages related to an earthquake event. When compared with the total number of customers served by MEC, it can be projected that up to 10% of all customers may report outages during any given seismic event. Problem Statement MEC should strive to meet seismic design standards for electrical substation equipment and other overhead assets susceptible to damage from earthquake events. MEC Page 15

16 MACON ELECTRIC COOPERATIVE Dam Failure Like earthquakes, dam failures have had no measurable impact upon the MEC service area to date. According to Missouri DNR s Dam Safety Division, 156 dams currently exist within the cooperative boundaries: 16 in Chariton County, 1 in Knox County, 43 in Linn County, 56 in Macon County, 1 in Monroe County, 13 in Randolph County, 10 in Shelby County, and 1 in Sullivan County. Of these dams, 15 are regulated by the state due to the fact that they are non-agricultural, non-federal dams which exceed 35 feet in height. Figure 6 shows the locations of all known dams located within Macon Electric s service area. (Map source: Figure 6 Dam Network Map Previous Occurrences Twenty-six dam failures have occurred within the state of Missouri over the past 100 years. However, no such event has occurred within or near the cooperative s boundaries. Probability of Future Occurrence and Vulnerability However, for the purposes of this assessment, dam failure and its associated impacts cannot be eliminated from the realm of possibility. In order to allow for a risk assessment, the probability of this event has been included as less than 1%. Determining the potential extent of dam failure is currently impossible due to a lack of data concerning inundation zones. Based on discussions with MEC staff on location of infrastructure relative to dams, this MEC Page 16

17 MACON ELECTRIC COOPERATIVE assessment assumes a limited impact upon downstream electric distribution infrastructure of less than 10% for both infrastructure damage and service interruption. Problem Statement Further study concerning existing dams and the impact of their failure is required to make a more comprehensive assessment of potential damages and mitigation strategies to address this potential hazard. MEC Page 17

18 MACON ELECTRIC COOPERATIVE C. Risk Assessment Summary Most of the historical hazards have had an impact on the electric cooperatives. Table 7 below shows the annual damages associated with each hazard for MEC. The table is ranked by the highest Average Annual Damages which is an indication of the vulnerability to each hazard. Table 7 MEC Hazard Risk Summary Hazard Average Annual Damages Hail $37,500 Dam Failure $0 Earthquakes $0 Flood and Levee Failure $0 Severe Thunderstorms and High Winds $0 Severe Winter Weather $0 Tornadoes $0 Wildfire $0 Each of the hazards of Severe Thunderstorms, Severe Winter Weather and Tornadoes, along with each of the non-historical hazards Wildfire, Earthquakes and Dam Failure has the potential for causing catastrophic damages in any given year. To date there have been zero reported damages to the assets of the Macon Electric Cooperative from these events. Nonetheless, this set of hazards should be considered in mitigation strategies because of the damage potential. MEC Page 18

19 MACON ELECTRIC COOPERATIVE Section 4: Mitigation Strategies Previous Mitigation Efforts For organizations like MEC, mitigation is considered to be part of prudent business operations. In order to ensure the delivery of a quality product and minimize service interruptions, a number of mitigation strategies are continually utilized. Routine maintenance and upgrades to existing equipment are completed as part of daily tasks. Vegetation management is utilized to limit the cascading effects of natural hazards. Safety and reporting information are disseminated to the public through various types of media. Mutual aid agreements and partnerships create relationships which provide for future support in the event of a natural disaster. Additionally, mitigation is considered prior to any expansion of service into special hazard areas. Before any service is built, it is first staked out in coordination with local builders and property owners. This process, completed by the Line Superintendent and contracted engineers, identifies and addresses foreseeable hazards and safety issues before any new service lines area constructed. USDA-RUS specifications regarding operation and safety are utilized in every step of the process. Steps are taken to practically minimize the exposure of equipment to loss due to foreseeable hazards, particularly flooding. Customers who reside in the floodplain are not charged for repairs or losses associated with flooding unless they purposefully destroy or restrict the cooperative from protecting their distribution system assets. Existing and Potential Resources As stated above, mitigation is a key component of good business practices. Macon Electric Cooperative includes mitigation strategies as part of regular work activities to ensure service with minimal interruptions. Funding for these activities is provided through the cooperative s normal budgetary process for maintenance. In order to expand mitigation efforts beyond normal maintenance, it is likely that MEC will need to seek outside funding sources. These may include private, state, or federal programs which provide grant and loan funding. Upon passage of this plan, MEC will be eligible for funding through FEMA in the following categories: Hazard Mitigation Grant Program Flood Mitigation Assistance Program Pre-Disaster Mitigation Program 406 Stafford Act USDA Economic Development Grants Review of Goals, Objectives, and Actions The MEC mitigation staff reviewed the goals, actions, and objectives from the original plan which addressed hazard mitigation issues. They evaluated each action to decide if it was completed, will be continued, or should be deleted. There also was the opportunity to add goals, objectives or new actions. The staff considered which type of actions will maximize benefits and minimizes costs, how mitigation strategies will be implemented, and how the overall plan will be maintained and updated. Table 8 lists the MEC Page 19

20 MACON ELECTRIC COOPERATIVE original goals and objectives as presented in the 2012 plan, and in the last column, as reviewed in the 2017 plan update. Table 8 MEC Goals and Objectives Identified Goals-2012 Goal 1: Protect the health and safety of the community. Goal 2: Reduce future losses due to natural hazard events. Goal 3: Improve emergency management capabilities and enhance local partnerships. Goal 4: Continue to promote public awareness and education. Identified Objectives-2012 : Prevent injury, loss of life, and damage to property. Objective 2: Reduce outage time to critical facilities. : Protect and maintain existing infrastructure. Objective 2: Research and develop plans for future infrastructure improvements, seeking implementation where feasible. Objective 3: Research and develop plans for future communication and data collection improvements where feasible. : Improve assessment of outages and reduce response time. Objective 2: Create or maintain partnerships with outside agencies. : Utilize media resources to promote public education. Objective 2: Continue interaction with local schools and civic groups. Reassessment of the Goal/Objective Accept, as is Accept, as is Accept, as is Accept, as is Accept, as is Accept, as is Accept, as is Accept, as is Accept, as is Traditionally, the STAPLEE (Social, Technical, Administrative, Political, Legal, Environmental, and Economic) method is used to prioritize mitigation actions. These categories, however, do not necessarily align with the private sector in the same way they are applicable to governmental agencies. A number of action items could be included with multiple goals and objectives, for example. As a result, the cooperatives chose to use a different method to prioritize their mitigation strategy. After reviewing ongoing and potential action items, the actions were placed in one of three priority tiers: First tier actions focus on physical infrastructure protection and improvements which ensure continued, quality service and seek to reduce power outages. These types of actions are the highest priority of MEC. MEC Page 20

21 MACON ELECTRIC COOPERATIVE Second tier actions create and maintain working relationships to reduce and prevent the impact of power outages. These include improvements to safety and reporting information, mutual aid agreements, and other efforts which seek to expand and improve both customer service and disaster planning. Third tier actions identify potential projects for other system improvements. These include mapping efforts, technological improvements, and research related to the expansion of mitigation efforts. Actions within each tier may be funded through regular budgetary methods or identified outside sources. The final component of reviewing the proposed and existing mitigation strategies was to perform a costbenefit analysis of all mitigation actions. The analysis was based on past experiences of performing certain actions and the potential number of beneficiaries. The following matrix, Table 9, was used to rate each mitigation action. Cooperative staff was asked in the Goals, Objectives and Actions Survey to review the cost-benefit rating and change if necessary. Table 9 Cost Benefit Matrix COST BENEFIT High Medium Low High Medium Low The following tables represent the completed 2017 review of current and potential mitigation strategies. Each strategy has assigned a cost benefit score assigned by the cooperative staff based on prior experience and professional opinions. Tables 10, Table 11, and Table 12 provide lists of action items by tier (1, 2 and 3 respectively), the goals and objectives identified with each, and the results of the cost-benefit analysis. The tables have been updated through the Goals, Objectives and Actions Survey that was sent to MEC to facilitate the staff update review. The Survey can be found in Appendix C. Staff members reviewed each item on the original tables and determined the current status of the item. The Hazards Addressed by This Action column was not included in the 2012 plan; this information has been added into the 2017 plan update for each Action Item. MEC Page 21

22 MACON ELECTRIC COOPERATIVE Table 10 Prioritized Mitigation Actions for Macon Electric Cooperative Tier 1 Tier 1 Goal/ Objective Goal 1 Goal 2 Goal 1 Goal 2 Goal 1 Goal 2 Goal 2 Objective 2 Action Item Routine maintenance of lines and poles. Perform routine maintenance and utilize upgraded equipment where possible to ensure quality of system. Tasks may include part replacement and/or upgrades. Identified work includes, but is not limited to: Addition of lightning arresters, electronic reclosures, conductors, guidewires to areas where ground is soft or area is subject to high winds. Replacement or repair on poles, crossarms and shorten spans, lines, tighten hardware Use vegetation management to prevent interference with delivery of power. Convert single phase lines to three phase lines. Status Update Continue (Inprogress) Continue (Inprogress) Continue (Inprogress) Continue (Inprogress) Progress on Continued Actions Ongoing annual process We are continuing to upgrade our system. Ongoing annual process Currently in the process following our work plan. Hazards Addressed by This Action Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Completion Date Cost/ Benefit Score Annually 7 Annually 7 Annually 5 Annually 4 MEC Page 22

23 MACON ELECTRIC COOPERATIVE Tier 1 Goal/ Objective Goal 1 Goal 1 Objective 2 Goal 2 Goal 2 Objective 2 Action Item Convert overhead lines to underground lines or vice versa in troubled areas based on vulnerability. Status Update Continue (Inprogress) Progress on Continued Actions Performed on an "as needed" basis Hazards Addressed by This Action Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Completion Date Cost/ Benefit Score Annually 4 Table 11 Prioritized Mitigation Actions for Macon Electric Cooperative Tier 2 Tier 2 Goal/ Objective Goal 1 Goal 1 Objective 2 Goal 3 Objective 2 Goal 1 Goal 3 Objective 2 Goal 3 Objective 2 Action Item Partner with county emergency management agencies to ensure power for local shelters, fuel stations, and public safety. Cooperate with local law enforcement and government officials to reduce the impact of power outages. Maintain mutual aid agreements with other rural electric cooperatives. Status Update Continue (Inprogress) Continue (Inprogress) Continue (Inprogress) Progress on Continued Actions Attend local Emergency Management quarterly meetings. Created a back door number for fast response to power outages with 911. Handled through our statewide headquarters. Hazards Addressed by This Action Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Completion Date Cost/ Benefit Score Annually 6 Annually 9 Annually 7 MEC Page 23

24 MACON ELECTRIC COOPERATIVE Table 12 Prioritized Mitigation Actions for Macon Electric Cooperative Tier 3 Tier 3 Goal/ Objective Goal 2 Objective 2 Goal 3 Goal 3 Goal 1 Goal 2 Action Item Provide satellite phones for emergency response teams Install a SCADA system to provide a better response time for outages Monitor developments in data availability concerning the impact of dam failure and wildfire upon the MEC service area through local, state, and federal agencies Status Update Continue (Inprogress) Continue (Inprogress) Continue (Inprogress) Progress on Continued Actions All lead linemen and staff have company provided cell phones. Currently building the infrastructure. Handled through our Statewide Headquarters. Hazards Addressed by This Action Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Completion Date Cost/ Benefit Score Annually Annually 3 MEC Page 24

25 MACON ELECTRIC COOPERATIVE After review, there were two Actions completed and removed from the Action Items list for the 2017 plan update. The completed Actions are listed in Table 13 below. There were zero Actions deleted. All other actions are continued in the 2017 plan update. There are no additional actions added to the 2017 plan. Table 13 Prioritized Mitigation Completed Actions for Macon Electric Cooperative 2012 Tier Level 3 3 Goal/ Objective Goal 2 / Objective 2 Goal 2/ Objective 2 Goal 2 / Objective 3 Actions Item GPS/GIS the entire infrastructure. Install a new AMR ( Automatic Meter Reading) system with real time OMS (Outage Management System) Status Update Action Completed Action Completed Explanation for Completed/Deleted Action All metering and poles have been GPS'd. Installed new Tannilus system. Hazards Addressed by This Action Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Dam Failure Earthquakes Flooding Land Subsidence Thunderstorms Tornado Wildfire Completion Date 2018 Cost/ Benefit Score 7 7 MEC Page 25

26 MACON ELECTRIC COOPERATIVE Section 5: Plan Implementation and Maintenance Plan Incorporation The goals, objectives, and actions of the previous section identify both ongoing efforts at mitigation and potential methods for expanding efforts. The updated plan has been reviewed and adopted by the Board of Directors as part of the company s operations policy. This mitigation plan necessitates involvement from every MEC employment level as the organization strives to ensure quality service to their customers. Local Planning Capabilities Some internal planning capabilities do exist at Macon. The Hazard Mitigation Plan can be considered and/or incorporated into regular budgetary planning, the four-year work plan for capital improvements, and the maintenance planning policy. Planning capabilities per se for the electric cooperatives are limited. What is important is that the Action Items developed through the mitigation planning process are incorporated into the daily activities of the cooperative. The four year work plans embrace the mitigation efforts that are in the mitigation plan. The electric cooperatives across Missouri are always working to strengthen their systems. This would include installing stronger/larger poles when smaller ones need to be changed out, installing stronger/larger conductors that can carry more weight and decreasing span lengths between poles, installing larger anchors, relocating structures out of flood plains, and installing structures to stop cascading during ice storms. Other capabilities are unique to the electric cooperative s business of providing reliable electricity to their members. Many of the Action Items listed in the plan include tree trimming plans, use of GPS to locate outages, service upgrades to lines and poles, warning systems and use of weather radios, collection of GIS data and utility specific software for locating and rerouting outages to restore power, all contribute to local capabilities. Integration of Macon s planning with local law enforcement, mutual aid agreements, and partnerships with local emergency management resources ensures power to critical facilities during a hazard event. This coordination and cooperation broadens the capabilities of the local cooperative. Beyond the Macon Electric Hazard Mitigation Plan, regional planning capabilities exist at the local level. The Missouri counties of Adair, Chariton, Knox, Linn, Macon, Monroe, Randolph, Shelby and Sullivan have a FEMA-approved Natural Hazard Mitigation Plan in place. County emergency management directors have Local Emergency Operations Plans which seek to mitigate the same hazards for residents. These same counties are also included in the Regional Transportation Plan (RTP) as well as a Comprehensive Economic Development Strategy (CEDS). MEC s plan can be easily incorporated into these local plans and allow for coordination across agencies in the event of an emergency. MEC is located within the rural portions of third-class counties which are prohibited from enforcing building codes and zoning by the state of Missouri. They do not provide service to any municipality within these counties. Comprehensive plans and Capital Improvement plans do not exist inside of the MEC service areas. MEC Page 26

27 MACON ELECTRIC COOPERATIVE Plan Maintenance Macon will follow the requirements coordinated by the Association of Missouri Electric Cooperatives (AMEC) for monitoring, evaluating, and updating the plan. Continued Public Involvement Opportunities Public notice was given in the form a notice in the Rural Missouri, a publication of the Association of Missouri Electric Cooperatives, distributed to all cooperative members. The updated 2017 plans were posted on the website of the Northwest Missouri Regional Council of Governments for public review and comment. Comments were considered and addressed. Once all co-op plans were completed, they were assembled into one plan and submitted to the State Emergency Management Agency and the Federal Emergency Management Agency for review and approval. The documentation for public involvement and comments can be found in Appendix B of each cooperative s section of the plan. Macon will follow the requirements coordinated by the Association of Missouri Electric Cooperatives (AMEC) for continued public involvement. Opportunities for public comment will continue to be offered through various media outlets and the physical office of MEC. MEC Page 27

28 Appendix: A - Adoption Resolution

29 RESOLUTION HAZARD MITIGATION PLAN WHEREAS (Cooperative name) wishes to be more prepared for the occurrence of natural hazards and to offset their impacts where possible; and WHEREAS the (Cooperative name) has participated in the preparation of a multihazard mitigation plan, hereby known as the Multi-jurisdictional Hazard Mitigation Plan for Missouri s Electric Cooperatives, hereafter referred to as the Plan, in accordance with the Disaster Mitigation Act of 2000; and WHEREAS, this living document was updated in 2017 and is intended to serve as a planning mechanism for participating Missouri Rural Electric Cooperatives; and WHEREAS, (Cooperative name) worked to identify hazards, vulnerabilities and potential actions that may lessen the impact of natural hazards upon (Cooperative name) assets in the future; and THEREFORE, BE IT RESOLVED: That (Cooperative name) adopts the Multi- Jurisdictional Hazard Mitigation Plan 2017 Update for Missouri Electric Cooperatives as it pertains and applies to (Cooperative name). CERTIFICATE OF SECRETARY I,, do hereby certify that I am Secretary of (Cooperative name); that the above and foregoing is a true copy of the Resolution adopted by the Board of Directors of said Cooperative relating to the Hazard Mitigation Plan. IN WITNESS WHEREOF, I have hereunto set my hand as Secretary of Cooperative name) And affixed the seal thereof this Day of, 2017 _, Secretary (CORPORATE SEAL)

30 Appendix: B - Documentation of Participation

31 This ad was published in the Rural Missouri, a monthly publication of the Missouri Association of Missouri Electric Cooperatives, giving public notice to all subscribing members of AMEC.

32 Appendix: C - Surveys

33 Data Survey Section 1: Introduction A. Please update the introductory material if necessary. MEC s headquarters are located in Macon, Missouri. Service is provided to customers in nine counties in north central Missouri: Adair, Chariton, Knox, Linn, Macon, Monroe, Randolph, Shelby and Sullivan. The MEC service territory consists of approximately 2,950 miles of energized line which serves customers in at least a portion of Adair, Chariton, Knox, Linn, Macon, Monroe, Randolph, Shelby and Sullivan counties. Please type any changes to the above paragraph in the text box below. No changes 2887 New number provide later in the Survey. B. Please update values below with most recent data for number of customers. The MEC currently has more than 11,500 connected meters and exceeds 8,500 members in the nine county service area. Residential customers account for 88% of memberships (10,000 members) while non-residential customers make up the remaining 12% (1,500 members). Please type any changes to the above paragraph in the text box below. 11,247 meters 8,184 members C. Table 1.1 Please update with your most recent meter inventory Table 1.1 Meters by County 2012 Meters by County 2017 Plan Number of meters County Number of meters Adair Chariton Knox Linn Macon ,216 Monroe Randolph ,111 Shelby ,272 Sullivan 50 52

34 D. Please update values below for average daily customer usage and most recent data for annual total usage. MEC s average daily residential customer usage is 37 kilowatt-hours (kwh). During 2010 the average annual total usage of MEC residential customers was 13,284 kwh of service. Please type any changes in the paragraph above in this text box. No changes Indicated in plan that no change was given for update. Section 2: Planning process A. Does your cooperative provide service to any critical facilities? The MEC provides service to critical facilities that include nursing homes, emergency services, telecommunications, schools and storm shelters that were invited to participate in the public comment period. Please list any critical facilities that are serviced by your cooperative in this text box. No changes Section 3: Asset inventory A. Please update values below for number of vehicles and miles of distribution lines. Forty-three vehicles provide access to customers and infrastructure. MEC does not own any electric generation or transmission infrastructure. 2, miles of distribution lines are owned and maintained by MEC. Please type any changes in the paragraph above in this text box. 2, miles of distribution lines B. Table 1.3. Asset Inventory Valuation Summary Please update valuations with most recent data. Asset Total MEC Assets Total Replacement Cost 2012 Table 1.3 MEC Inventory Valuation Summary Total Replacement Cost breakdown2017 Cost Breakdown 2017 Cost 2017 Buildings and vehicles - $8,606,550* Overhead assets - $131,824, ,486,464* Buildings and vehicles - $8,385,000 Overhead assets -

35 Distribution Lines $80,708,220 OH $2,318,850 UG 54,320,000 OH 1,780,000 UG $120,278,894 Underground assets - $2,910,448 OH Single-phase lines - $54,990,720 UG Single-phase lines - $2,145,600 OH Three-phase lines - $25,717,500 UG Three-phrase lines- $173,250 $123,928,585 * Underground assets - $2,951,329* OH Single-phase lines - $40,740,000 UG Single-phase lines - $1,680,000 OH Three-phase lines - $13,580,000 UG Three-phrase lines- $100,000 Supporting Infrastructure Office Buildings $39,564,674 OH $591,598 UG Added other OH and UG asset categories to balance this table with table 4-see final plan Meters - $1,312,150 Poles - $23,362,000 OH Transformers - $11,319,000 UG Transformers - $546,518 Guys/Anchors - $1,575,959 Cross-arms - $404,905 Regulators - $536,000 SP Oil-Circuit Reclosures - $1,057,500 Capacitors - $42,240 Meters - $3,884,383 Poles - $24,512,000 OH Transformers - $11,658,570 UG Transformers - $562,914 Guys/Anchors - $1,623,238 Cross-arms - $ Regulators - $552,080 SP Oil-Circuit Reclosures - $1,090,177 Capacitors - $43,507 $3,575,000 $3,682,250 *changed to match Table 4 Warehouses $1,000,000 $1,000,000 Vehicles $3,810,000 3,924,300 Source: Internal Macon Accounting and Insurance records, 2011 Please provide any additional information or comments regarding Table 1.3 in this text box.

36 C. Table 1.4 includes a list of asset types, emergency replacement cost per unit or mile, the asset inventory by Service County and total infrastructure numbers. Please update Table 1.4 valuations with most recent data. Table 1.4 MEC Asset Inventory by Service County Asset Emergency Replacement Cost per unit or mile No. of units or miles: ADAIR No. of units or miles: CHARITON No. of units or miles: KNOX No. of units or miles: LINN No. of units or miles: MACON No. of units or miles: MONROE No. of units or miles: RANDOL PH No. of units or miles: SHELBY No. of unites or miles: SULLIV AN Total no. of units or miles: Meter Pole $ , , ,111 2, ,427 $300/unit 134 5, ,485 26,009 4,399 6,117 9, , , ,756 4,400 9,000 11, ,000 SP*** distribution line $24,000/mile OH ($7.35/foot OH) $24,000/mile UG ($7.35/foot UG) 6.7 OH OH 7.25 UG 9.1 OH.2 UG OH 4 UG OH UG 185 OH 4 UG OH 9.1 UG OH 10.5 UG No Changes OH.1 UG OH 89.4 UG TP**** distribution line Transformers $45,000/mile ($11.50/foot OH) $1,029/ OH $1,442/ UG OH.1 UG OH OH.5 UG OH 65.5 OH 2 UG 132 OH 1.25 UG 1.25 OH No Changes OH 20 OH 982 OH 20 UG 1,010 OH 21 UG 13 OH 1 UG 20 OH 2 UG 807 OH 21 UG 850 OH 25 UG 5,108 OH 211 UG 5,500 OH 220 UG 734 OH 18 UG 775 OH 22 UG 1,096 OH 51 UG 1,200 OH 55 UG 2,207 OH 56 UG 550 OH 60 UG 40 OH 1 UG 45 OH 2 UG OH 3.85 UG 11,000 OH 379 UG 11,965 OH 407 UG Guys/anchors $92.60/unit 40 1, ,916 6,017 1,301 3,670 2, ,019 $92.60/unit 44 1, ,975 6,200 1,345 3,780 2, ,512 $ , , ,446 Cross-arms $ , ,740 Regulators $8,

37 $8, Oil Circuit Reclosures Capacitors Total replacement value by county $1,500 SP $1, $440/unit $440/unit $8,787,100 $53,133,103 OH OH $233,027,61 OH $240,108,43 8 $10,890,603 OH $207,340 UG $11,217,321 OH $213,560 UG $312,597 OH $6,242 UG $321,975 OH $6,429 UG $12,653,521 OH $126,282 UG $13,033,127 OH $130,070 UG $1,628,762 UG $54,727,096 OH $1,677,625 UG $121,956 UG $9,050,713 OH $125,615 UG **OH = overhead ***UG = underground ***SP = Single phase ****TP Three phase Source: Internal Macon Accounting and Maintenance records $12,816,088 OH $381,942 UG $13,200,571 OH $393,400 UG $21,110,298 OH $389,002 UG $21,743,607 OH $400,672 UG $382,674 OH $3,842 UG $394,154 OH $3,957 UG $120,319,015 OH $2,865,368 UG $123,928,585 OH $2,951,329 UG Please provide any additional information or comments regarding Table 1.4 in this text box.

38 Section 4: Identified Hazards and Risk Assessment Methodology A. The following natural hazards have been identified as potential threats your service region of the Macon Electric Cooperative: Tornadoes Severe Thunderstorms, Hail, and High Winds Flood and Levee Failure Severe Winter Weather Earthquakes Dam Failure Wildfire B. Please update if the following valuations have changed. (From your updates to Table 1.3) Overhead infrastructure assets and buildings o Valued at $128,663,894 No changes $128,610,835 New number taken from updated Asset Inventory & Valuations Overhead infrastructure assets only o Valued at $120,278,894 No Changes $123,928,585 New number taken from updated Asset Inventory & Valuations C. Do you know of any future development for your cooperative or the areas you serve? Please provide the answer to question C in the box below. No Section 5: Risk Assessment A. Historical Hazards: Tornadoes In the last 54 years, 26 tornadoes have been reported within the Macon Electric Cooperative boundaries. Please type any changes to update the above sentence in the text box below.

39 35 tornadoes Please update Table 1.7 with most recent data. (Please add additional rows as necessary.) Table 1.7 MEC Tornadic Event Summary Date of Event EF Scale Rating Damage Estimates Outages Reported Data provided based on internal MEC records which reflect cost from the referenced event year. Please provide any other information regarding tornado activity since 2010 that has significantly impacted your cooperative s service area. N/A Severe Thunderstorms, High Wind, and Hail From , Macon s service area within the state of Missouri has experienced a total of 158 hail events and 141 thunderstorm/high wind events. Please type any changes to update the above sentence in the text box below. N/A Update hail data to most recent data. (Please add additional rows as necessary.) Table 1.9 MEC Hail Event Summary Event date Damage estimates Outages reported Event date Damage estimates Outages reported 02/27/11 $250,000 N/A 06/27/11 $500,000 N/A Data provided based on internal MEC records which reflect cost from the referenced event year. Please provide any other information regarding severe thunderstorm/hail activity since 2010 that has significantly impacted your cooperative s service area

40 N/A Update thunderstorm data to most recent data. (Please add additional rows as necessary.) Table 1.11 MEC Thunderstorm/High Wind Event Summary Event Date Damage Estimates Outages Reported Data provided based on internal MEC records which reflect cost from the referenced event year. Please provide any other information regarding severe thunderstorm/high wind activity since 2010 that has significantly impacted your cooperative s service area. N/A Flood and Levee Failure From , Macon s service area has experienced 66 flooding events. Please type any changes to update the above sentence in the text box below. N/A Update flood/levee failure event data to most recent data. (Please add additional rows as necessary.) Table 1.14 MEC Flood/Levee Failure Event Summary Damage Outages Event Date Estimates Reported Data provided based on internal MEC records which reflect cost from the referenced event year. Please provide any other information regarding flooding activity since 2010 that has significantly impacted your cooperative s service area.

41 N/A Severe Winter Weather From , Macon s service area has experienced a total of sixty-four severe winter weather events, including significant snowfall and ice storms. Please type any changes to update the above sentence in the text box below. N/A Update severe winter weather event data to most recent data. (Please add additional rows as necessary.) Table 1.17 MEC Severe Winter Weather Event Summary Damage Outages Event Date Event Type Estimates Reported Data provided based on internal MEC records which reflect cost from the referenced event year. Please relate any additional information regarding severe winter weather in the textbox below. N/A B. Non-historical Hazards Earthquakes In 2012, earthquakes were listed as a non-historical hazard because there was no data for your cooperative. If current data is available for any earthquakes in the cooperative s service area please provided data below. (Please add additional rows as necessary.) N/A Event Date New Table MEC Earthquake Event Summary Damage Estimates Outages reported Data provided based on internal MEC records which reflect cost from the referenced event year.

42 Please provide any other information regarding earthquake activity since 2010 that has significantly impacted your cooperative s service area. N/A Dam Failure In 2012 because there was no data for your cooperative, dam failure was listed as a nonhistorical hazard in the 2012 plan. If current data is available for any dam failures in the cooperative s service area please provided data below. (Please add additional rows as necessary.) N/A Event Date New Table MEC Dam Failure Event Summary Damage Estimates Outages Reported Data provided based on internal MEC records which reflect cost from the referenced event year Please provide any other information regarding dam failure activity since 2010 that has significantly impacted your cooperative s service area. N/A Wildfire Updated wildfire events will be provided by the planning commission. If you have any local information about wildfire within your boundaries, please provide below. (Please add additional rows as necessary.) N/A Event Date New Table MEC Wildfire Event Summary Damage Estimates Outages Reported Data provided based on internal MEC records which reflect cost from the referenced event year. Please provide any other information regarding wildfire activity since 2010 that has significantly impacted your cooperative s service area. N/A

43 Goals, Objectives and Actions Survey The original survey is an interactive Excel file that could not be inserted without stabilizing the formatting. All of the data submitted is included in the tables below. Goals, Objectives and Actions Survey-Goals Tab 2012 Tier Level Goal/ Objective Actions from 2012 Plan Status Update Explanation for completed/delet ed action Report progress on continued actions Select Hazard(s) addressed by this action Completion Date COST/ BENEFIT SCORE 1 Goal 1 / Goal 2 / Routine maintenance of lines and poles. Continue (Inprogress) Ongoing annual process annually 7 1 Goal 1 / Goal 2 / Perform routine maintenance and utilize upgraded equipment where possible to ensure quality of system. Tasks may include part replacement and/or upgrades. Identified work includes, but is not limited to: Addition of lightning arresters, electronic reclosures, conductors, guidewires to areas where ground is soft or area is subject to high winds. Replacement or repair on poles, cross-arms and shorten spans, lines, tighten hardware Continue (Inprogress) We are continuing to upgrade our system. annually 7

44 2012 Tier Level Goal/ Objective Actions from 2012 Plan Status Update Explanation for completed/delet ed action Report progress on continued actions Select Hazard(s) addressed by this action Completion Date COST/ BENEFIT SCORE 1 Goal 1 / Goal 2 / Use vegetation management to prevent interference with delivery of power. Continue (Inprogress) Ongoing annual process annually 5 1 Goal 2 / Objective 2 Convert single phase lines to three phase lines. Continue (Inprogress) Currently in the process following our work plan. annually 4 1 Goal 1 / Goal 1 / Objective 2 Goal 2 / Goal 2 / Objective 2 Convert overhead lines to underground lines or vice versa in troubled areas based on vulnerability. Continue (Inprogress) Performed on an "as needed" basis annually 4

45 2012 Tier Level Goal/ Objective Actions from 2012 Plan Status Update Explanation for completed/delet ed action Report progress on continued actions Select Hazard(s) addressed by this action Completion Date COST/ BENEFIT SCORE 2 Goal 1 / Goal 1 / Objective 2 Goal 3 / Objective 2 Partner with county emergency management agencies to ensure power for local shelters, fuel stations, and public safety. Action Complet ed Attend local Emergency Management quarterly meetings. annually 6 2 Goal 1 / Goal 3 / Objective 2 Cooperate with local law enforcement and government officials to reduce the impact of power outages. Action Complet ed Created a back door number for fast response to power outages with 911. annually 9 2 Goal 3 / Objective 2 Maintain mutual aid agreements with other rural electric cooperatives. Action Complet ed Handled through our statewide headquarters. annually 7

46 2012 Tier Level Goal/ Objective Actions from 2012 Plan Status Update Explanation for completed/delet ed action Report progress on continued actions Select Hazard(s) addressed by this action Completion Date COST/ BENEFIT SCORE 3 Goal 2 / Objective 2 GPS/GIS the entire infrastructure. Action Complet ed All metering and poles have been GPS'd. 7 3 Goal 2 / Objective 2 Provide satellite phones for emergency response teams Continue (Inprogress) All lead linemen and staff have company provided cell phones. annually 8 3 Goal 3 / Goal 3 / Install a SCADA system to provide a better response time for outages Continue (Inprogress) Currently building the infrastructure