Section 1: Introduction

Transcription

1 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Section 1: Introduction Intercounty Electric Cooperative Association, Inc. was organized in 1945 as a memberowned, non-profit cooperative. Intercounty is headquartered in Licking, Missouri, and provides service to customers in Crawford, Dent, Gasconade, Maries, Phelps, Pulaski, Shannon, Texas and Wright Counties. The customer base of Intercounty Electric Cooperative Association served is 23,978 active consumer-members whom actually own the cooperative. The Intercounty service area is divided into three districts, North, South and Central Districts and is run by a board of nine directors which approve the company s mission and internally developed business policy. Cooperative operations are carried out under policies set by the board of directors and each member of the board of directors is a cooperative member that receives their electric service from the cooperative. Statement of Objectives: Intercounty Electric Cooperative Association exists to serve its consumermembers in the best manner possible. The cooperative will...strive to provide the best possible service to all persons who desire it within the cooperative's service area....provide the highest value services at the lowest practical cost, at rates which provide adequate funds to cover all cost of service....do all things essential to good management - providing dependable service, developing a stable financial structure, maintaining a sound organization and training leadership on a long-range basis....promote the wise use of electricity, electrical appliances and equipment in the home, farms and businesses while working to improve the standard of living for all members....constantly strive for even higher standards of electric and other services provided by the cooperative....keep consumer-members informed about their cooperative's operations, plans, problems and progress, while demonstrating that the cooperative is owned and operated by the members....develop the democratic process with consumer-members, encouraging their participation in cooperative affairs....develop understanding and support of cooperative objectives, plans and programs....work to stimulate and support area development programs that will increase and stabilize the economic level of the area....provide leadership and cooperate with community and civic groups in fostering programs that contribute to the area's development. 21-1

2 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] The following maps depict the Intrercounty Electric Cooperative Association, Inc. geographic boundaries that encompass Crawford, Dent, Gasconade, Maries, Phelps, Pulaski, Shannon, Texas and Wright counties (Figure 1) and the service area by quadrangles tiles (Figure 1). Figure 1 Table 1.1 provides the summary of metered customers by Missouri County. Table 1.1 County Meters by Missouri County Number of meters Crawford 351 Dent 5,231 Gasconade 268 Maries 1,054 Phelps 9,849 Pulaski 221 Shannon 685 Texas 10,682 Wright 2,267 TOTALS 30,

3 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 The average daily customer usage for Intercounty is 36 kilowatt-hours (kwh). Annual total usage of Intercounty customers in 2010 was 315,070,920. Population density for the cooperative service area is depicted in the following map (Figure 2) (Map source: U.S. Census 2010). Figure

4 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Section 2: Planning process Through a partnership between the Association of Missouri Electric Cooperatives and the Missouri Association of Councils of Government, the South Central Ozarks Council of Governments was contracted to facilitate a hazard mitigation planning process for Intercounty. The initial meeting was held on January 18, 2011 as part of a regional kickoff meeting for south-central Missouri. This informational meeting provided the basic responsibilities for each agency and allowed for initial discussion concerning the project timelines, data collection and other pertinent topics. Planning meetings were held at the Intercounty office in Licking, Missouri on February 9, 2011 and October 4, Table 1.2 summarizes the attendees and topics of each meeting. Table 1.2 INTERCOUNTY Planning Meeting Synopsis Meeting Date Attendees, Title, Organization Topics of discussion February 9, 2011 Jack Rinne, Mngr. of Operations and Maintenance Brian Nelson, Mngr. of Engineering Monty Smith, SCOCOG Steven Reed, SCOCOG Review of Chapter Project Intercounty business structure Data collection identification Project timelines Customer information October 4, 2011 Dwayne Cartwright, General Manager Leisa Stilley, Communications Director Monty Smith, SCOCOG Johnny Murrell, SCOCOG Critical facilities information Asset inventory by type and location Data collection review Current mitigation strategies Establishment of goals, actions, and objectives Method of prioritization Prioritization of goals, actions, and objectives Public Involvement Intercounty posted their local chapter on the company s website, inviting both cooperative members and the general public to provide comment. Print copies of the chapter were also made available upon request through the local office. Comments from neighboring jurisdictions were also solicited using the standardized Intercounty letter which was mailed to the appropriate contacts, including: Crawford County Commission Dent County Commission Gasconade County Commission Maries County Commission Phelps County Commission Pulaski County Commission Shannon County Commission 21-4

5 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Texas County Commission Wright County Commission Emergency Management Directors Red Cross Chapter. Intercounty provides service to the following critical facilities. Additionally, Intercounty s mitigation plan was included in the public comment period for the combined AMEC plan. Salem Memorial District Hospital Cedar Knoll Home Ferndale Nursing Home Licking Park Manor Licking Residential Care Rosewood Nursing Home Seville Care Center KELE Radio Station KTTR-KZNN KUNQ-KBTC Dent-Phelps R-3 School District Edgar Springs Phelps County R-3 School Green Forest R-8 School District Northwood R-IV School District Oak Hill School District Licking R-8 School District Mountain Grove School District Plato School District Raymondville Schools Success School District Summersville School District Wyman Elementary School Bore-flex Industries Inc. Royal Canin USA Inc. Royal Oak Enterprises Inc. South Central Correctional Facility 21-5

6 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Section 3: Asset inventory Assets and real estate owned by Intercounty include office building, warehouses, garages, outbuilding and vehicles. Intercounty does not own any electric generation or transmission infrastructure. Intercounty owns and maintains 6, miles of distribution lines. Table 1.3 provides information concerning asset valuation. Table 1.3 Asset Total Intercounty Assets Distribution Lines ( ) ( UG) Intercounty Asset Inventory Valuation Summary Total Cost breakdown Replacement Cost $ 326,484,856 Buildings and vehicles - $ 13,925,693 Overhead assets - $ 303,745,261 Underground assets - $8,813,902 $ 301,429,305 Single Phase lines - $ 278,035,232 $ 8,813,902UG UG Single Phase lines - $ 8,489,693 Three Phase lines - $ 23,394,073 UG Three Phase lines - $ 324,209 Supporting Infrastructure Office Buildings $7,891,900 Warehouses $3,485,700 Vehicles $2,548,093 Source: Provided by Intercounty $ 2,315,956 Regulators - $ 399,288 SP Oil-Circuit Reclosures - $1,829,925 Capacitors - $87,418 Ensuring quality distribution to its customers, Intercounty maintains not only distribution lines, but also the supporting infrastructure as well. 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. 21-6

7 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Table 1.4 Intercounty Asset Inventory by Service County Asset Emergency replacement cost Crawford Gasconade Dent Maries Phelps Pulaski Shannon Texas Wright Total number of units or miles: per unit or mile -Meter $0/unit ,231 1,054 9, ,682 2,267 30,608 -Pole $0/unit 1,865 1,449 22,082 4,850 25, ,785 39,931 1, ,651 SP*** Distrb. line/miles TP**** Distrib. line/mile $53,750.40/ mile ($10.18/ft ) $80,731.20/ mile UG ($15.29/ft UG) $28,999/ mile ($0/foot ) $28,999/ mile UG ($0/foot UG) UG 2.97 UG.28 UG , UG UG UG 1, UG UG UG UG UG 2, UG UG UG UG UG 5, UG UG Regulator $4, Oil Circuit $1, Reclosure 29 1,125 Capacitors $672.45/ unit Total $5,863,950 $4,472,642 $66,168,243 $14,563,925 $75,487,082 $2,567,839 $11,971,266 $119,386,771 $3,263,544 $303,745,261 replacement value by County $109,794 $22,605 $1,959,649 $132,399 $3,530,212 $40,366 $237,146 $1,662,118 UG UG UG UG UG UG ** = overhead ***UG = underground ***SP = Single phase ****TP Three phase Information provided by Intercounty $1,119,613 UG $8,813,902 UG AMEC Natural Hazard Mitigation Plan 21-7

8 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Section 4: Identified Hazards and Risk Assessment Methodology Natural hazards in south-central Missouri vary dramatically with regard to intensity, frequency, and the scope of impact. Some hazards, like earthquakes, happen without warning and do not provide any opportunity to prepare for the threat. Other hazards, such as tornadoes, flooding, or severe winter storms, provide a period of warning which allows for public preparation prior to their occurrence. The following natural hazards have been identified as potential threats for the service region of the Intrercounty Electric Cooperative Association, Inc: Tornadoes Severe Thunderstorms/High Winds Severe Winter Weather Earthquakes Wildfire Flood Dam Failure There are certain hazards may be eliminated from consideration in their local plan due to the state s geographic location including tsunamis, hurricanes, coastal storms, volcanic activity, avalanche, and tropical storms. Additionally, a number of hazards may be eliminated specifically for Intercounty because of asset types and geographic location in the state of Missouri. Those hazards eliminated for the Intercounty service region include: Heat Wave Drought Severe land subsidence Although drought can potentially impact south-central Missouri, water availability does not directly impact the delivery of electric service to Intercounty customers. Heat waves may result in additional usage and demand on the system but usually doesn t cause infrastructure damage to cooperative assets. Land subsidence and landslides have also been eliminated the area due to the structure categorization by the USGS. Limestone, carbonate rock, salt beds, and other naturally dissolving rock which are most susceptible to the formation of sinkholes do not form the basis of soil in the Intercounty service region. For the purpose of this risk assessment, the identified hazards for the Intercounty service area have been divided into two categories: historical and non-historical hazards Historical Hazards are those hazards with a measurable previous impact upon the service area that identify the damage costs per event and a chronology of occurrences is available. The associated vulnerability assessments utilize the limited number of events and cost of each event that were provided by Intercounty to establish an average cost per incident. For Intercounty hazards

9 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 with historical data include tornadoes, severe thunderstorms/high wind/hail, severe winter weather, flood and wildfire. Non-historical Hazards are hazards with no previous record of impact upon the local service area. The associated vulnerability assessments for each of these hazards will have an occurrence probability of less than 1% in any, but the extent of damage will vary considerably. For Intercounty, hazards without historical data include earthquakes and dam failure. Probability of Occurrence In determining the potential frequency of occurrences for historical events documented by Intercounty, the number of recorded events for the service area was divided by the number of years of record. This number was then multiplied by 100 to provide a percentage. This formula was used to determine future probability for each hazard. For events that have not occurred, a probability of less than 1% was automatically assigned as the hazard cannot be excluded from the possibility of occurrence. Likewise, when discussing the probable risk of each hazard based upon historical occurrences, the following scale was utilized: Less than 1% chance of an event occurrence in any. 1-10% chance of an event occurrence in any 10-99% chance of an event occurrence in any Near 100% chance of an event occurrence in any The number of occurrences was further refined to focus on damage-causing events. Those occasions which had reported damages were divided by the total number of recorded events to obtain a percentage of total storms which result in infrastructure damage. (Formula: Number of damage-causing events / total number of events = Percentage of occurrences which cause damage.) Potential Extent of Damage Vulnerability Assessment matrices for each hazard are included on the following pages. These worksheets detail loss estimates for each hazard affecting the cooperative s service area. No loss estimates were provided by Intercounty records. 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 o Valued at $315,122,861 Overhead infrastructure assets only o Used for: Severe Thunderstorm / High Wind/ Hail /Severe Winter Weather o Valued at $303,745,

10 Potential Extent of Damage May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] In addition, historical hazards with recorded damages were used to identify an average cost per event. No historical hazards with recorded damages were reported by Intercounty. (Formula: Total cost of damages / total number of events = Average damage cost per event.) When discussing the extent of potential damages for all hazards, the following scale was utilized: Less than 10% potential damages to total cooperative infrastructure 10-25% potential damages to total cooperative infrastructure 25-50% potential damages to total cooperative infrastructure More than 50% potential damages to total cooperative infrastructure The following matrix (Table 1.5) will be utilized to identify the potential damage extent and likelihood of occurrence for each natural hazard type. Table 1.5 Sample Intrercounty Electric Cooperative Association, Inc Infrastructure Vulnerability Assessment Matrix Hazard: Less than 10% of damage to system 10-25% damage of system Probability of Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any Near 100% probability in any 26-50% damage of system More than 50% damage of system In many instances, natural hazard events occur without causing significant damage to the cooperative s infrastructure. No recorded damage estimates were provided by Intercounty. The more significant impact of natural hazard episodes comes in the form of reported customer outages. In addition to system damage, each hazard may be evaluated on the average number of reported or estimated outages per event occurrence. (Formula: Average number of outages reported / Total number of customers = Average percentage of outages reported per event) 21-10

11 Potential Extent of Impact [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Table 1.6 Sample Intrercounty Electric Cooperative Association, Inc Service Interruption Vulnerability Assessment Matrix Hazard: Less than 10% of customers report outages 10-25% of customers report outages 26-50% of customers report outages More than 50% of customers report outages Probability of Damage-causing Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 21-11

12 Potential Extent of Damage May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Section 5: Risk Assessment A) Historical Hazards: Figure 3 Tornadoes According to the National Climate Data Center (NCDC), 69 tornadoes have been documented in within the Intercounty cooperative boundaries from 1954 to The following map (Figure 3) provides a pictorial representation of the recorded tornado touchdown sites and recorded path. (Data for map collected from NOAA.) From , 12 tornadoes were recorded for the Intercounty service area. None of these occurrences caused damage to cooperative assets, resulting in less than 1% probability that any given tornado occurrence will produce damage. Using the previously described methodology, the probability of a tornado event in the Intercounty service area in any is 70.5% (12 events / 17 years = 70.5%) while the probability of a damage-causing tornadic event is less than 1% (0 events / 12 events = 0%). Table 1.7 Probability of Hazard Occurrence Intrercounty Electric Cooperative Infrastructure Vulnerability Assessment Matrix Hazard: Tornado Less than 1% in any 1-10% chance in any given year 10-99% chance in any Near 100% probability in any Less than 10% of damage to system 10-25% damage of system % damage of system More than 50% damage of system No customers have reported outages during any recorded tornado event within the Intercounty service area. When compared with the total number of customers served by Intercounty it can be projected that less than 10% of all customers may report outages

13 Potential Extent of Impact [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 during any given tornado event. Table 1.8 demonstrates the probability of occurrence in conjunction with the potential extent of impact upon local customers. Table 1.8 Intrercounty Electric Cooperative Service Interruption Vulnerability Assessment Matrix Hazard: Tornado Less than 10% of customers report outages 10-25% of customers report outages 26-50% of customers report outages More than 50% of customers report outages Probability of Damage-causing Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any Severe Thunderstorms, High Wind, and Hail According to the National Climate Data Center (NCDC), 158 thunderstorm/high wind/ hail events have been reported within the Intercounty cooperative boundaries from 1991 to date. Intercounty staff identified a single occurrence responsible for causing any damage to cooperative assets. Table 1.9 Event date Thunderstorm/High Wind/Hail Events Damage estimates 05/2009 $1,500,000 Using the previously described methodology, the probability of a thunderstorm/high wind/ hail event in the Intercounty service area in any is near 100% (158 events / 20 years = 790%). To date, only one of these occurrences caused damage to cooperative assets, resulting in less than 1% probability that any given thunderstorm/high wind/ hail occurrence will produce damage (1 / 158 = 0.63%). Based upon these records, the average damage cost per event is $1,500,000 ($1,500, / 1 event = $1,500,000). This averaged amount accounts for less than 1% of Intercounty s total overhead asset valuation ($1,500,000 / $303,745,261 = 0.493%). Table 1.10 demonstrates the probability of occurrence in conjunction with the potential extent of damage for a thunderstorm/high wind/hail event

14 Potential Extent of Impact Potential Extent of Damage May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Table 1.10 Probability of Hazard Occurrence Intrercounty Electric Cooperative Infrastructure Vulnerability Assessment Matrix Hazard: thunderstorms/high wind/hail Less than 10% of damage to system 10-25% damage of system Less than 1% in any 1-10% chance in any given year 10-99% chance in any Near 100% probability in any 26-50% damage of system More than 50% damage of system According to information provided by Intercounty, an average of 11,976 customers reported outages during this recorded severe weather event. When compared with the total number of customers served by Intercounty, it can be projected that less than 50% of all customers may report outages during any given thunderstorm/high wind/ hail event (11,976 / 23,978 = 49.95%). Table 1.11 demonstrates the probability of occurrence in conjunction with the potential extent of impact upon local customers. Table 1.11 Intrercounty Electric Cooperative Service Interruption Vulnerability Assessment Matrix Hazard: thunderstorms/high wind/hail Less than 10% of customers report outages 10-25% of customers report outages 26-50% of customers report outages More than 50% of customers report outages Probability of Damage-causing Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 21-14

15 Potential Extent of Impact Potential Extent of Damage [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Severe Winter Weather According to the National Climate Data Center (NCDC), 13 severe winter weather events have been reported within the cooperative boundaries from 1991 to date. Using the previously described methodology, the probability of a severe winter weather event in the Intercounty service area in any is 65% (13 events / 20 years = 65%). To date, none of these occurrences caused damage to cooperative assets, resulting in less than 1% probability that any given severe winter weather occurrence will produce damage (0 occurrences / 13 events = 0%). Table 1.12 demonstrates the probability of occurrence in conjunction with the potential extent of damage for a severe winter weather event. Table 1.12 Probability of Hazard Occurrence Intrercounty Electric Cooperative Association, Inc Infrastructure Vulnerability Assessment Matrix Hazard: Severe Winter Weather Less than 1% in any 1-10% chance in any given year 10-99% chance in any Near 100% probability in any Less than 10% of damage to system 10-25% damage of system 26-50% damage of system More than 50% damage of system No customers have reported outages due to severe winter weather events since When compared with the total number of customers served by Intercounty, it can be projected that less than 10% of all customers may report outages during any given severe winter weather event. Table 1.13 demonstrates the probability of occurrence in conjunction with the potential extent of impact upon local customers. Table 1.13 Intrercounty Electric Cooperative Association, Inc Service Interruption Vulnerability Assessment Matrix Hazard: Severe Winter Weather Less than 10% of customers report outages 10-25% of customers report outages 26-50% of customers report outages More than 50% of customers report outages Probability of Damage-causing Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 21-15

16 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Wildfire The occurrence of wildfire in the Intercounty service area presents a unique risk assessment. According to the Missouri Department of Conservation, the Intercounty service area which encompasses portions of Crawford, Dent, Gasconade, Maries, Phelps, Pulaski, Shannon, Teas and Wright counties have all experienced wildfires between 2004 and Table 1.14 summarizes the incidences of wildfire within the counties. Based upon this information, the probability of a wildfire event in the Intercounty service area in any is near 100% (1681 events / 4 years = ) However, for the purposes of this assessment, wildfire and its associated impacts cannot be eliminated from the realm of possibility. Table 1.14 Wildfire summary by county Average County # of Wildfires, Annual # of Wildfires Average Annual Acres Burned Acres Burned Crawford Dent Gasconade Maries Phelps Pulaski Shannon Texas Wright Totals Source: Missouri State Hazard Mitigation Plan, 2010 Total Buildings Damaged The potential extent of damage caused by wildfire is difficult to determine. To date, 1681 fires have burned a total of 16,502 acres, for an average of 9.81 acres affected per event. Intercounty sustained no damage related to wildfires in its service area during this time period. Intercounty Cooperative assets are located throughout the service area rather than being located at a single central site. With an average of 9.81 acres per fire in the service area, it is unlikely that infrastructure damage would exceed 10% based upon asset location and improbability of an uncontrollable wildfire. This initial assessment assumes a limited impact upon electric distribution infrastructure of less than 10% (Table 1.15). Further study will be required to create a model for damage assessments related to wildfire

17 Potential Extent of Impact Potential Extent of Damage [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Table 1.15 Probability of Hazard Occurrence Intrercounty Electric Cooperative Association, Inc Infrastructure Vulnerability Assessment Matrix Hazard: Wildfire Less than 1% in any 1-10% chance in any given year 10-99% chance in any Near 100% probability in any Less than 10% of damage to system 10-25% damage of system 26-50% damage of system More than 50% damage of system No customers have reported outages during recorded wildfires between 2004 and When compared with the total number of customers served by Intercounty, it can be projected that less than 1% of all customers may report outages during any given wildfire event. Table 1.16 demonstrates the probability of occurrence in conjunction with the potent extent of impact upon local customers. Table 1.16 Intrercounty Electric Cooperative Association, Inc Service Interruption Vulnerability Assessment Matrix Hazard: Wildfire Less than 10% of customers report outages 10-25% of customers report outages 26-50% of customers report outages More than 50% of customers report outages Probability of Damage-causing Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 21-17

18 Potential Extent of Damage May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Flood Flooding has never had a measurable impact to asset infrastructure within the service area of the Intercounty. According to the National Climate Data Center (NCDC), 129 floods have been reported within the Intercounty boundaries from 1991 to date. The following map (Figure 4) depicts the 100 year floodplain in relation to the cooperative s boundaries. (Map source FEMA) Figure 3 Flood events in the Intercounty service area are based upon heavy rain and annual precipitation but no record of damages or service interruptions have been recorded. To date, none of these occurrences caused damage to cooperative assets, resulting in less than 1% probability that any given flooding occurrence will produce damage. Using the previously described methodology, the probability of a flooding event in the Intercounty service area in any is 100% (129 events / 20 years = 645%) Table 1.17 Probability of Hazard Occurrence Intercounty Electric Cooperative Infrastructure Vulnerability Assessment Matrix Hazard: Flood Less than 1% in any 1-10% chance in any given year 10-99% chance in any > 100% probability in any Less than 10% of damage to system 10-25% damage of system 26-50% damage of system More than 50% damage of system No customers have reported outages during any flooding event within the Intercounty service area. When compared with the total number of customers served by 21-18

19 Potential Extent of Impact [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Intercounty, it can be projected that less than 1% of all customers may report outages during any given flooding event. Table 1.18 Probability of Damage-causing Occurrence Intercounty Electric Cooperative Service Interruption Vulnerability Assessment Matrix Hazard: Flood Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any Less than 10% of customers report outages 10-25% of customers report outages 26-50% of customers report outages More than 50% of customers report outages 21-19

20 Dam Failure May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Dam failures have had no measurable impact upon the Intercounty service area to date. According to Missouri DNR s Dam Safety Division, 72 dams currently exist within the cooperative boundaries: 4 in Crawford County, 26 in Dent County, 5 in Gasconade County, 6 in Maries County, 24 in Phelps County, 7 in Texas County. State regulated dams that are non-agricultural, non-federal dams which exceed 35 feet in height are located in: 3 in Phelps, 4 in Dent, 2 in Gasconade, 1 in Wright, 1 in Crawford and 1 in Texas. The following map (Figure 5) shows the locations of dams located within Intercounty s service area. (Map sources:.dnr.mo.gov/env/wrc.) Figure 4 No dam failure has occurred within or near the cooperative s boundaries. 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 past events in the Intercounty service area. This initial assessment assumes a limited impact upon downstream electric distribution infrastructure of less than 1% for both infrastructure damage and service interruption due to the lack of data and past hazard occurrences. (Tables 1.19 and 1.20)

21 Potential Extent of Impact Potential Extent of Damage [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Table 1.19 Probability of Hazard Occurrence Intercounty Electric Cooperative Infrastructure Vulnerability Assessment Matrix Hazard: Dam Failure Less than 1% in any 1-10% chance in any given year 10-99% chance in any Near 100% probability in any Less than 10% of damage to system 10-25% damage of system 26-50% damage of system More than 50% damage of system As noted above, this assessment assumes a limited impact upon downstream electric distribution infrastructure of less than 1% for any service interruption due to the lack of data and past hazard occurrences. Table 1.20 Intercounty Electric Cooperative Service Interruption Vulnerability Assessment Matrix Hazard: Dam Failure Less than 10% of customers report outages 10-25% of customers report outages 26-50% of customers report outages More than 50% of customers report outages Probability of Damage-causing Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 21-21

22 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] B. Non-historical Hazards Earthquakes Eight earthquake seismic zones are located in the central United States, two of which are located in Missouri. The most active zone is the New Madrid Seismic Zone, which is also the most active seismic area in the United States east of the Rocky Mountains and, according to the U.S. Geological Survey, is by some measures as high a hazard as seismic zones in California. It runs from northern Arkansas through southeast Missouri and western Tennessee and Kentucky to the Illinois side of the Ohio River Valley. Undoubtedly, this fault has the potential to affect the Intercounty service area in its entirety. 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 probability of an earthquake increases with each passing day. In addition to the New Madrid Seismic Zone, other seismic zones that affect Missourians include the Wabash Valley Seismic Zone, the South Central Illinois Seismic Zone, and the Nemaha Uplift. The Wabash and Illinois seismic zones are not as active as the New Madrid Seismic Zone based on microseismic activity, but they are considered capable of producing earthquakes in the range of M 6.0 to 6.8. The Nemaha Uplift is of concern to Missourians because it runs parallel to the Missouri/Kansas border from Lincoln, Nebraska, to Oklahoma City, Oklahoma. Earthquakes from the Nemaha Uplift are not as severe as those associated with the historic New Madrid Seismic Zone. Several earthquakes have affected Missouri in the past The projected earthquake intensity ratings for the cooperative region changes based upon the Modified Mercalli Scale. Given a New Madrid earthquake with a 7.6 magnitude, the region would experience Level VI intensity characteristic and would impact 47 Missouri counties. The Intercounty 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. Though the probability of occurrence is very small, the potential extent of damage could significantly impact both the cooperative and its customers as demonstrated in Table (Missouri State Hazard Mitigation Plan, 2010) 21-22

23 Potential Extent of Impact Potential Extent of Damage [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Table 1.21 Probability of Hazard Occurrence Intrercounty Electric Cooperative Association, Inc Infrastructure Vulnerability Assessment Matrix Hazard: Earthquake Less than 1% in any 1-10% chance in any given year 10-99% chance in any Near 100% probability in any Less than 10% of damage to system 10-25% damage of system 26-50% damage of system More than 50% damage of system Based upon information from CERI, FEMA, and SEMA and using the standardized scale for Missouri REC s, it may be estimated that up to 10%, or 2,398 customers, could report outages related to an earthquake event of 7.6 magnitude. Table 1.22 demonstrates the probability of occurrence in conjunction with the potent extent of impact upon local customers. Table 1.22 Intrercounty Electric Cooperative Association, Inc Service Interruption Vulnerability Assessment Matrix Hazard: Earthquake Less than 10% of customers report outages 10-25% of customers report outages 26-50% of customers report outages More than 50% of customers report outages Probability of Damage-causing Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 21-23

24 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Section 6: Mitigation strategies Previous efforts at mitigation For organizations like Intercounty, 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. Intercounty Electric Cooperative Association, Inc. 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 Intercounty 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, Intercounty will be eligible for funding through FEMA in the following categories: Hazard Mitigation Grant Program Pre-Disaster Mitigation Program 406 Stafford Act Development of goals, objectives, and actions Establishing mitigation goals, objectives, and actions for a business entity requires a slightly different approach than public agencies. Certainly, a number of similarities exist; both entities must consider which hazards most commonly occur and have the greatest potential for causing disruption to members or residents. They must also consider which types of actions will maximize benefits and minimize costs, how mitigation strategies will be implemented, who will enforce implementation, and how the overall plan will be maintained and updated. The Intercounty mitigation planning staff worked to identify goals, actions, and objectives which addressed hazard mitigation issues. The staff first identified ongoing mitigation strategies as well as potential strategies which seek to improve service and limit disruptions resulting from natural hazards. Action items were then analyzed for common characteristics and summarized to create nine objectives. Likewise, these nine objectives were grouped into similar categories and used as the basis for the four overarching goals. Table 1.23 provides a simple synopsis of the goals and objectives before prioritization

25 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 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 committee chose to use a different method to prioritize their mitigation strategy. Table 1.23 Identified Goals 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. INTERCOUNTY goals and objectives Identified Objectives Objective 1: Prevent injury, loss of life, and damage to property. Objective 2: Reduce outage time to critical facilities. Objective 1: 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. Objective 1: Improve assessment of outages and reduce response time. Objective 2: Create or maintain partnerships with outside agencies. Objective 1: Utilize media resources to promote public education. Objective 2: Continue interaction with local schools and civic groups. After identifying ongoing and potential action items, the committee created 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 Intercounty. 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. Tables 1.24, 1.25, and 1.26 provide lists of action items by tier as well as the goals and objectives identified with each

26 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Table 1.24 Prioritized Mitigation Actions for Intrercounty Electric Cooperative Association, Inc Tier 1 Action item: 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 enclosures, conductors, guide wires. Replacement or repair on poles, cross-arms, lines. Raising pad mount transformers in flood prone areas. Upgrade to concrete or steel poles where possible. Use vegetation management to prevent interference with delivery of power. Complete annual inspections of lines and poles. Add alternate source wiring to eliminate or reduce time of outages. Tier 1 Goal/Objective Goal 1 / Objective 1 Goal 2 / Objective 2 Goal 1 / Objective 1 Goal 1 / Objective 2 Goal 2 / Objective 1 Goal 2 / Objective 2 Goal 1 / Objective 1 Goal 2 / Objective 2 Goal 1 / Objective 1 Goal 1 / Objective 2 Goal 1 / Objective 1 Goal 1 / Objective 2 Goal 2 / Objective 2 Timeframe for completion Ongoing effort Dependent upon additional funding. Ongoing effort Completed annually. Ongoing effort; Completed as funding allows. Cost-benefit score Low cost High benefit Score: 9 High cost High benefit Score: 7 Low cost Medium benefit Score: 6 Low cost Medium benefit Score: 6 Medium cost High benefit Score: 4 Convert overhead lines to underground lines or vice versa in troubled areas based on vulnerability. Goal 1 / Objective 1 Goal 1 / Objective 2 Goal 2 / Objective 1 Goal 2 / Objective 2 Ongoing effort; Dependent upon funding. Medium cost High benefit Score:

27 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Table 1.25 Prioritized Mitigation Actions for Intercounty Electric Cooperative Tier 2 Action item: Provide safety and reporting information to the general public through varying methods: local newspaper, presentations and publications Tier 2 Goal/Objective Goal 1 / Objective 1 Goal 4 / Objective 1 Timeframe for completion Ongoing effort Cost-benefit Score Low cost Medium benefit Score: 6 Maintain mutual aid agreements with other rural electric cooperatives. 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. Goal 3 / Objective 2 Ongoing effort. Low cost Low benefit Score: 3 Goal 1 / Objective 1 Goal 1 / Objective 2 Goal 3 / Objective 2 Goal 1 / Objective 1 Goal 3 / Objective 2 Ongoing effort. Ongoing effort. Low cost High benefit Score: 1 Low cost High benefit Score: 1 Table 1.26 Prioritized Mitigation Actions for Intercounty Electric Cooperative Tier 3 Action item: Consider collecting GPS data for all existing infrastructure. Utilize GIS technology to reduce site identification and response time. Consider implementation of automated voice response systems to improve outage reporting. Monitor data developments for hazards where insufficiencies exist. Tier 3 Goal/Objective Goal 2 / Objective 1 Goal 2 / Objective 3 Goal 3 / Objective 1 Goal 1 / Objective 1 Goal 2 / Objective 3 Goal 3 / Objective 1 Goal 1 / Objective 2 Goal 3 / Objective 1 Goal 1 / Objective 1 Goal 2 / Objective 1 Goal 2 / Objective 2 Timeframe for completion Dependent upon additional funding. Dependent upon additional funding. Dependent upon additional funding. Ongoing effort Cost-benefit High cost High benefit Score: 7 Medium cost Medium benefit Score: 5 High cost Medium benefit Score: 4 Medium cost Medium benefit Score: 5 Improve outage information collection by hazard type. Goal 1 / Objective 2 Goal 2 / Objective 3 Goal 3 / Objective 1 Ongoing effort Medium cost Medium benefit Score:

28 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Section 7: 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 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 Intercounty employment level as the organization strives to ensure quality service to their customers. Other Local Planning Mechanisms Some internal planning mechanisms do exist at Intercounty. The Hazard Mitigation Plan can be considered and/or incorporated into regular budgetary planning and cooperative work plan. Beyond the Intercounty plan, few planning mechanisms exist at the local level. The Missouri counties of Crawford, Dent, Gasconade, Maries, Phelps, Pulaski, Shannon, Texas and Wright Counties each have a FEMA-approved Natural Hazard Mitigation Plan or under FEMA review for the required five year updates. 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). Intercounty s plan can be easily incorporated into these local plans and allow for coordination across agencies in the event of an emergency. Plan Maintenance Intercounty will conform to the requirements established by the Association of Missouri Electric Cooperatives (AMEC) for monitoring, evaluating, and updating the plan. Continued Public Involvement Opportunities Intercounty will conform to the requirements established 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, the cooperative s website, and the physical office of Intercounty Electric Cooperative Association, Inc

29 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Chapter Appendix: Documentation of Participation Contents: : Meeting documentation Public Comment letter 21-29

30 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Intercounty Electric Cooperative Hazard Mitigation I. Introductions: II. business structure 21-30

31 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 a. Stakeholders: 23,978 members in co-operative which is owned by the membership. Board of Directors comprised on 9 persons is the governing body. Policy is board approved and internally developed. Procedures are not board ratified. Company profile is available at b. General customer information i. Number of services in place: ii. Residential vs. Nonresidential services: iii. Critical Facilities located within the service area: Need to determine the definition of critical facilities. Hospitals only? Nursing homes? Emergency services? Telecommunications? Looking into this further. c. Annual usage/output: III. Asset inventory (See worksheet) a. General Information on: i. Distribution facility ii. Generation facility iii. Substations iv. Transmission Lines (miles) v. Distribution Lines (miles) vi. Office buildings vii. Warehouses viii. Vehicles b. Information by county i. Meters ii. Poles iii. Lines (Overhead and Underground in miles) iv. Guys/Anchors v. Cross-arms vi. Replacement cost IV. Natural Hazards which can potentially impact EC (worksheet) V. Previous damage estimates based on natural hazards a. 2009/ Thunderstorm/ straight line winds - $1,500,

32 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Association of Missouri Electric Cooperatives Data Collection & Asset Inventory Critical Assets Asset Quantity Name Address (location) Distribution Facility (Cooperative) Generation Facility Substations Transmissions Lines (miles) Distribution Lines(miles) Office Buildings Warehouses - Vehicles Replacement cost average: Will provide later Will provide later 7,891,900 6,033,

33 [INTERCOUNTY ELECTRIC COOPERATIVE] May 18, 2012 Table of Assets Asset Emergency Replacement Cost per unit or mile Crawford Gasconade Dent Maries Phelps Pulaski Shannon Texas Wright Total number of units or miles: -Meter $0/unit ,231 1,054 9, ,682 2,267 30,608 -Pole $/unit 1,865 1,449 22,082 4,850 25, ,785 39,931 1, ,651 SP*** Distribution line/miles $53,750.40/ mile ($10.18/foot ) $80,731.20/ mile UG UG UG 1, UG UG 1, UG UG UG 2, UG UG 5, UG ($15.29/foot UG) TP**** distribution line/mile $28,999/mile ($0/foot ) $28,999/mile UG 1.82 UG 4.56 UG.16 UG 2.64 UG 2 UG UG ($0/foot UG) Transf. $ 1, Guyanchors $277.66/unit -Cross-arms $ Regulators $4, Oil Circuit Reclosures $1, Capacitors $672.45/unit

34 May 18, 2012 [INTERCOUNTY ELECTRIC COOPERATIVE] Updated costs for single phase construction are: overhead (10.18 per ft. or 53, per mile) & underground (15.29 per ft. or 80, per mile). Our three phase construction costs for 2011 were 28, per mile. Emergency replacement costs for the following equipment are: transformers ( ), guys & anchors (277.66), crossarms (246.26), regulators ( ), oil circuit reclosers ( ) & capacitors(672.45). Replacement costs for office buildings are $4,114,000 with the contents replacement costs at $3,777,900. Replacement costs for warehouses are $2,550,000 with the contents to be replaced at $935,700. Our vehicles and mobile equipment is valued at $813,263 and our hydraulic equipment is valued at $1,734,830 for a total of $2,548,066. Our average daily member usage for September 2011 was 36 kwh. Our 2010 average construction costs for single phase overhead lines was $9.33 per foot. Our 2010 average construction costs for single phase underground lines was $15.07 per foot. The total replacement costs for all IECA buildings warehouse and equipment is $17,806, Oil circuit recloser counts per county are as follows: Crawford (13), Dent (209), Gasconade (10), Maries (51), Phelps (357), Pulaski (9), Shannon (29), Texas (441) & Wright (6). We do not have the information at this time for transformers, guys & anchors and crossarms. Listing of Critical Facilities 2011 Intercounty Electric Cooperative Association Service Area Hospitals:Salem Memorial District Hospital Nursing Homes:Cedar Knoll Home Ferndale Nursing Home Licking Park Manor Licking, MO Licking Residential Care Rosewood Nursing Home Seville Care Center Radio Stations: KELE Radio Station KTTR-KZNN 21-34