Section 1: Introduction

Transcription

1 Section 1: Introduction [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Webster Electric Cooperative (WEC) was established in 1946 to provide electric service to the rural areas of southwest Missouri. A Touchstone Energy Cooperative, Webster Electric Cooperative is a locally owned and governed not-for-profit cooperative based in Marshfield, Missouri. WEC currently serves over 18,000 member-owners in its seven county service territory. To keep up with the changing times and the changing needs of its members, in 2000 Webster Electric Cooperative's Mission Statement evolved to the following: "Webster Electric Cooperative exists to provide reliable electric service at the most economical cost, enrich the life of the community, educate members concerning the benefits of membership, and encourage member participation in the Cooperative." WEC s service boundaries within the state of Missouri include portions of Webster, Greene, Christian, Dallas, Laclede, Wright and Douglas counties in southwest Missouri. The cooperative owns 1,874 miles of overhead service line and 155 miles of underground line within its service area which covers 572 square miles. 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, Webster Electric Cooperative.) The customer base of WEC currently is comprised of 18,750 members. The majority of WEC customers are located in Webster County, Missouri. Webster Electric cooperative provides electric service to the municipalities of Marshfield, Rogersville, Fordland, Niangua, and Diggins in Webster County. In addition to all government owned buildings within its service area, WEC provides electric service to all vulnerable and critical facilities. WEC provides service to facilities in five school districts, 8 Red Cross emergency shelters, 8 child care facilities and 7 medical clinics. Table 1.1 provides the summary of meters by Missouri county. 46-1

2 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Table 1.1 Meters by Missouri County County Number of meters County Number of meters Webster 14,987 Laclede 44 Greene 2,712 Wright 13 Christian 1,898 Douglas 10 Dallas 319 Total 19,983 The average member usage for WEC is 1,200 kilowatt-hours (kwh) per month. Total usage for 2010 was 332,018,348 kwh. Population density for the cooperative service area is depicted in Figure 2 (Map source: U.S. Census 2010). 46-2

3 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Section 2: Planning process Through a partnership between the Association of Missouri Electric Cooperatives and the Missouri Association of Councils of Government, the Southwest Missouri Regional Council of Governments was contracted to facilitate a hazard mitigation planning process for WEC. The initial meeting between the two entities was held on January 18, 2011 as part of a regional kick-off meeting for southwest 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. Two additional planning meetings were held at the WEC offices in Marshfield, Missouri and Ozark Electric headquarters in Mt. Vernon, Missouri August and October, respectively. Table 1.2 summarizes the attendees and topics of each meeting. Meeting minutes are available in the chapter appendix. Table 1.2 WEC Planning Meeting Synopsis Meeting Date Attendees, Title, Organization Topics of discussion August 17, 2011 Tom Houston, General Manager, WEC Dave Faucett, Community Planner, SMCOG WEC business structure Customer information Critical facilities information Asset inventory by type and location Data collection assignments October 10, 2011 Ken Raming, Ozark Electric Billy Hunt, Southwest Electric Brent Gamble, Southwest Electric Garry Lee, Barry Electric Jim Chadd, Barry Electric Tom Houston, Webster Electric Dave Faucett, Community Planner, SMCOG Current mitigation strategies Data collection review Establishment of goals, actions, and objectives Method of prioritization Prioritization of goals, actions, and objectives Public Involvement All public hazard mitigation plans require measures to include public involvement in the planning process. Public involvement in the WEC hazard mitigation plan was encouraged through a variety of methods. WEC 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 AMEC letter which was mailed to the appropriate contacts, including: Webster County Commission, Greene County Commission, Christian County Commission, Dallas County Commission, Laclede County Commission, Wright County Commission, 46-3

4 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Douglas County Commission, Local emergency management directors, School Districts, Municipalities, and The local Red Cross chapter. WEC provides service to 7 medical clinics, 4 residential care facilities, 8 fire districts, 4 ambulance/paramedic stations, 18 public school buildings in 5 school districts and industrial centers within its service area. Additionally, WEC s mitigation plan was included in the public comment period for the combined AMEC plan. 46-4

5 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Section 3: Asset inventory Webster Electric Cooperative has a wide variety of assets by type. Real estate owned by the company includes office buildings, warehouses, garages, and other outbuildings throughout the service area. Twenty vehicles provide access to customers and infrastructure. Table 1.3 provides information concerning total asset valuation. Table 1.3 Webster Electric Asset Inventory Valuation Summary Asset Total Cost breakdown Replacement Cost Total WEC Assets $163,521,300 Buildings and vehicles - $9,755,000 Overhead assets - $139,498,500 Underground assets - $14,267,800 Distribution Lines Supporting Infrastructure OH $76,359,360 UG $9,292,800 OH $63,139,140 UG $4,975,000 OH Single-phase lines - $61,575,360 UG Single-phase lines - $8,025,600 OH Three-phase lines - $14,784,000 UG Three-phase lines - $1,267,200 Office Buildings $5,200,000 Warehouses $1,300,000 Vehicles $3,255,000 Source: Internal Webster Electric Accounting and Insurance records, 2011 Meters - $2,997,450 Poles - $39,187,200 OH Transformers - $7,576,800 UG Transformers - $4,975,000 Guys/Anchors - $8,742,500 Cross-arms - $2,956,500 Regulators - $975,000 SP Oil-Circuit Reclosures - $545,250 3phase Oil-Circuit Reclosures - $116,690 Capacitors - $42,000 Ensuring quality distribution to its customers, Webster 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 county of service, and total infrastructure numbers. 46-5

6 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Table 1.4 Webster Electric Asset Inventory by service county Asset Emergency Replacement Cost per unit or mile Number of units or miles: WEBSTER Number of units or miles: GREENE Number of units or miles: CHRISTIAN Number of units or miles: DALLAS Meter $150/unit 14,987 2,712 1, Pole $800/unit 37,080 6,270 4, SP*** distribution line $36,960/mile OH ($7/foot OH) $52,800/mile UG 1,268 OH** 115 UG*** 210 OH 20 UG 158 OH 14 UG 27 OH 2 UG TP**** distribution line Transformers ($10/foot UG) $73,920/mile OH $105,600/mile UG 147 OH** 1 UG*** 27 OH 2 UG 20 OH 1 UG 3 OH 0 UG $1,200 OH $2,500 UG 2,350 OH 1,506 UG 2,088 OH 255 UG 1,550 OH 189 UG 261 OH 32 UG Guys/anchor $250/unit 28,134 3,601 2, Cross-arms $250 8,952 1,514 1, Regulators $7, Oil Circuit Reclosures $750 SP $7, TP 549 SP 12 TP 93 SP 2 TP 69 SP 2 TP Capacitors $500/unit Total OH OH OH Replacement $103,001,337 $19,181,926 $14,294,516 Value by UG UG UG county $9,942,600 $1,904,700 $1,317, SP 0 TP OH $2,392,180 UG $185,600 Asset Emergency Replacement Cost per unit or mile Number of units or miles: LACLEDE Number of units or miles: WRIGHT Number of units or miles: DOUGLAS Meter $150/unit ,983 Total number of units or miles: Pole $800/unit ,984 SP*** distribution line $36,960/mile OH ($7/foot OH) $52,800/mile UG 1 OH** 0 UG*** 1 OH 0 UG 1 OH 1 UG 1,666 OH 152 UG TP**** distribution line Transformers ($10/foot UG) $73,920/mile OH $105,600/mile UG 3 OH 8 UG 0 OH 0 UG 0 OH 0 UG 200 OH 12 UG $1,200 OH $2,500 UG 36 OH 4 UG 15 OH 2 UG 14 OH 2 UG 6,314 OH 1,990 UG Guys/anchor $250/unit ,970 Cross-arms $ ,825 Regulators $7, Oil Circuit Reclosures $750 SP $7, TP 2 SP 0 TP 1 SP 0 TP 1 SP 0 TP Capacitors $500/unit Total OH OH OH Replacement $425,920 $103,710 $98,910 Value by UG UG UG county $854,800 $5,000 $57, SP 16 TP OH $139,498,500 UG $14,267,800 **OH = overhead ***UG = underground ***SP = Single phase ****TP Three phase Source: Internal Webster Electric Accounting and Maintenance records 46-6

7 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Section 4: Identified Hazards and Risk Assessment Methodology Natural hazards in southwest 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. Regardless, hazard mitigation planning can lessen the negative impact of any natural disaster regardless of onset time. The following natural hazards have been identified as potential threats for the service region of the Webster Electric Cooperative: Tornadoes Severe Thunderstorms, Hail, and High Winds Flood Severe Winter Weather Earthquakes Dam Failure Wildfire Severe land subsidence (Sinkholes) Likewise, a number of 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 WEC because of asset types and geographic location in the state of Missouri. Those hazards eliminated for the WEC service region include: Drought Heat Wave Landslides Levee Failure Although drought can potentially impact southwest Missouri, water availability does not directly impact the delivery of electric service to WEC customers. Similarly, heat wave has been eliminated. Though it may result in additional usage and potentially tax the system, heat waves do not usually cause infrastructure damage to cooperative assets. The results of a heat wave in the WEC service area may be considered cascading events rather than damage caused directly by the hazard itself. Landslides have been eliminated based upon local soil structure categorization by the USGS. Levee Failure has been excluded as well due to the fact that there are no levees in the WEC service area. For the purpose of this risk assessment, the identified hazards for the WEC 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. Damage costs per event and a chronology of occurrences are available. The associated vulnerability assessments utilize the number of events 46-7

8 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] and cost of each event to establish an average cost per incident. For WEC, hazards with historical data include tornadoes, severe thunderstorms/high wind/hail, flood, severe winter weather, and wildfire. 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 WEC, hazards without historical data include earthquakes and dam failure. Probability of Occurrence In determining the potential frequency of occurrences, a simple formula was used. For historical events, 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. Loss estimates were calculated using the asset summary created by internal WEC accounting records. 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 o Valued at $149,253,

9 Potential Extent of Damage [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Overhead infrastructure assets only o Used for: Severe Thunderstorm / High Wind / Hail Flood Severe Winter Weather o Valued at $139,498,500 In addition, historical hazards with recorded damages were used to identify an average cost per event. (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 Regardless of hazard categorization, 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 Probability of Hazard Occurrence Sample Webster Electric Cooperative Infrastructure Vulnerability Assessment Matrix Hazard: 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 In many instances, natural hazard events occur without causing significant damage to the cooperative s infrastructure. The more significant impact of natural hazard episodes comes in the form of reported customer outages. The infrastructure may not be significantly harmed by an ice storm, but may result in prolonged and widespread outages in the cooperative s service area. In considering the potential impact of a hazard, loss of function provides a more concise picture for comparison of events and geographic regions of the state. In addition to system damage, each hazard will 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) 46-9

10 Potential Extent of Impact May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Table 1.6 Sample Webster Electric Cooperative 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 Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 46-10

11 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Section 5: Risk Assessment A) Historical Hazards: Tornadoes In the last 60 years, 30 tornadoes have been reported within the Webster cooperative boundaries. Figure 3 provides a pictorial representation of all recorded tornado touchdown sites and recorded path. (Data for map collected from NOAA.) A data insufficiency exists between historical hazard records and cooperative records concerning damage estimates and outages. For the purpose of this assessment, the years for which records exist for both data sets have been used. From , Webster s service area within the state of Missouri has experienced a total of 14 tornado events. Using the previously described methodology, the probability of a tornado event in the Webster service area in any is near 100% (14 events / 10 years = 140%). Estimated cooperative material damages associated with each of these events were compiled by WEC staff. Five of the fourteen occurrences caused damage to cooperative assets, resulting in a 35.7% probability that any given tornado occurrence will produce damage (5 / 14 = 35.7%). Table 1.7 provides a summary of event dates, EF-scale ratings, damage cost estimates and outages reported. Table 1.7 WEC Tornadic Event Summary Date of event EF Scale rating Damage estimates Outages Reported 11/1/2004 F1 $3, /12/2006 F3 $3,500 2,150 1/7/2008 F3 $7,600 5,500 1/8/2008 F0 $6, /8/2009 F1 $2, Data provided based on internal WEC records which reflect cost from the referenced event year. Based upon the last twenty years of historical event records, the average tornado to affect the cooperative will include an EF1-EF3 rating, causing an average damage cost of $4,620 per event ($23,100/5 events = $4,620). This averaged amount accounts for less than 1% of WEC s total overhead assets and building valuation ($4,620 / $149,253,500 = 46-11

12 Potential Extent of Impact Potential Extent of Damage May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] %). Table 1.8 demonstrates the probability of occurrence in conjunction with the potential extent of damage. Table 1.8 Probability of Hazard Occurrence Webster 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 26-50% damage of system More than 50% damage of system An average of 1,810 customers reported outages during recorded tornadoes since When compared with the total number of customers served by WEC, it can be projected that 9.6% of all customers may report outages during any given tornado event. Table 1.9 demonstrates the probability of occurrence in conjunction with the potent extent of impact upon local customers. Table 1.9 Webster 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 Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 46-12

13 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Severe Thunderstorms, High Wind, and Hail From , Webster s service area within the state of Missouri has experienced a total 78 hail events and 68 thunderstorm/high wind events. Therefore, the probability of a hail event in the Webster service area in any is near to 100% (78 events / 10 years = 780%) while the probability of a thunderstorm/high wind event in any is near to 100% (68 events / 10 years = 680%). Estimated material damages associated with each of these events were compiled by WEC staff. A data insufficiency exists between historical records and cooperative records for hail events. It may be possible that hail events have caused damages to the system and outages; however, the WEC records do contain any damages or outages associated with hail events. For the purpose of the risk assessment for hail events, the probability of damages and outages due to hail are difficult to assess. Based upon historical records, the probability of a hail event occurrence is at least equal to or greater than 100% and it is safe to assume that damages and outages have resulted from the impact of hail. However, it is unlikely that average damage costs resulting from hail would equal 10% or greater of the total overhead value of Webster Electric assets. It would be equally unlikely that average reported outages due to hail from would total 10% or greater of total Webster Electric customers. Table 1.10 provides information for thunderstorm/high wind events. Thirty-one of the sixty-eight occurrences caused damage to cooperative assets, resulting in a 46% probability that any given thunderstorm/high wind occurrence will produce damage. (31 / 68 = 45.58%) Table 1.10 WEC Thunderstorm/High Wind Event Summary Event date Damage estimates Outages reported Event date Damage estimates Outages reported 4/20/2000 $ /24/2007 $ /11/2001 $ /24/2007 $ /14/2001 $ /17/2007 $ /5/2001 $1, /7/2008 $ /8/2002 $ /8/2008 $ /12/2002 $ /6/2008 $ /6/2002 $ /22/2008 $ /19/2002 $ /27/2008 $ /6/2003 $ /9/2009 $1, /2/2003 $5, /13/2009 $ /23/2003 $1, /10/2009 $ /14/2004 $1, /16/2009 $ /13/2005 $ /13/2010 $1, /30/2005 $ /16/2010 $ /13/2005 $ /26/2010 $ /13/2005 $ Data provided based on internal WEC records which reflect cost from the referenced event year

14 Potential Extent of Impact Potential Extent of Damage May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Based upon historical records, the average thunderstorm/high wind event to affect the cooperative will cause an average damage cost of $678 ($21,015 / 31 events = $678). This averaged amount accounts for less than 1% of WEC s overhead asset valuation ($678 / $139,498,500 = %). Table 1.11 demonstrates the probability of occurrence in conjunction with the potential extent of damage for both hail and thunderstorm/high winds events. Table 1.11 Probability of Hazard Occurrence Webster Electric Cooperative Infrastructure Vulnerability Assessment Matrix Hazard: Thunderstorm/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 An average of 200 customers reported outages during recorded thunderstorm/ high wind events since When compared with the total number of customers served by WEC, it can be projected that 1% of all customers may report outages during any given hail, thunderstorm, or high wind event. Table 1.12 demonstrates the probability of occurrence in conjunction with the potent extent of impact upon local customers. Table 1.12 Webster Electric Cooperative Service Interruption Vulnerability Assessment Matrix Hazard: Thunderstorm/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 Hazard Occurrence Less than 1% in any Hail 1-10% chance in any given year 10-99% chance in any Thunderstorm /High Wind > Near 100% probability in any 46-14

15 Potential Extent of Damage [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Flood Riverine and flash flooding is an ongoing potential threat to the existing infrastructure of the Webster Electric Cooperative. Approximately 5% of the Webster Electric service area is located directly within the 100 year floodplain. Flash flooding accounts for the majority of flood events in southwest Missouri and most often occurs in the spring. Rate of precipitation, duration and saturation in low lying areas is the most pernicious threat to cooperative assets due to flooding. Figure 4 below depicts the 100 year floodplain in relation to the cooperative s boundaries. (Map sources: FEMA HAZUS-MH; FEMA National Flood Hazard Layer; Missouri Office of Administration, and Association of Missouri Electric Cooperatives.) From , Webster s service area has experienced 77 flooding events. Therefore, the probability of a flood event in the Webster service area in any is near to 100% (77 events / 17 years = 453%) To date, there have been no instances of flooding which have affected cooperative assets or has resulted in any outages, resulting in a less than 1% probability that any given flood occurrence will produce damage. (0 / 77 = 0%) Table 1.13 Probability of Hazard Occurrence Webster 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 46-15

16 Potential Extent of Impact May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Flood events vary widely based upon numerous factors including, but not limited to, annual precipitation, duration, and ground saturation. As there are no recorded instances of flooding affecting cooperative assets or outage reporting, it is difficult to assess the risk of floods for the WEC service area. However, there must remain the possibility that this hazard will impact WEC assets and customers. For the purpose of this risk assessment damage to cooperative assets are assumed to be less than 1%. Table 1.13 demonstrates the probability of flooding in conjunction with the potential extent of damage. There are no customers-reported outages during recorded flooding events since However, for the purpose of this risk assessment, when compared with the total number of customers served by WEC, it can be projected that less than 1% of all customers may report outages during any given flooding event. Table 1.14 demonstrates the probability of occurrence in conjunction with the potent extent of impact upon local customers. Table 1.14 Webster Electric Cooperative Service Interruption Vulnerability Assessment Matrix Hazard: Flood 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 Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 46-16

17 Potential Extent of Damage Severe Winter Weather [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 From , Webster s service area has experienced a total of twenty-seven severe winter weather events, including significant snowfall and ice storms. Therefore, the probability of a severe winter weather event in the Webster service area in any is near 100% (27 events / 17 years = 158%). WEC does maintain records associated with severe winter weather from Estimated material damages associated with each of these events were compiled by WEC staff. Table 1.15 provides a summary of event dates, types, associated damage estimates, and reported outages. Three of the twentyseven occurrences caused damage to cooperative assets, resulting in an 11.1% probability that any given severe winter weather occurrence will produce damage. (3 / 27 = 11.1%) Table 1.15 WEC Severe Winter Weather Event Summary Event date Event type Damage estimates Outages reported 11/24/1996 Ice storm $350,000 6,000 1/12/2007 Ice storm $1,700,000 14,400 1/3/05 Ice storm $650,000 9,000 Data provided based on internal WEC records which reflect cost from the referenced event year. Based upon these historical records, the average severe winter weather event to affect the cooperative will cause an average damage cost of $900,000 ($2,700,000 / 3 events = $900,000). This averaged amount accounts for less than 1% of WEC s total overhead asset valuation ($900,000 / $139,498,500 = 0.645%). Table 1.16 demonstrates the probability of occurrence in conjunction with the potential extent of damage. Table 1.16 Probability of Hazard Occurrence Webster Electric Cooperative 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 An average of 9,800 customers reported outages during recorded severe winter weather events since When compared with the total number of customers served by WEC, it can be projected that 52% of all customers may report outages during any given severe winter weather event. Table 1.17 demonstrates the probability of occurrence in conjunction with the potent extent of impact upon local customers

18 Potential Extent of Impact May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Table 1.17 Webster Electric Cooperative 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 Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any Wildfire The incidence of wildfire in the WEC service area presents a unique risk assessment. Wildfire events have occurred in each of the seven counties. According to the Missouri Department of Conservation, Webster, Christian, Greene, Dallas, Laclede, Wright, and Douglas counties have experienced wildfires between 2004 and Table 1.18 summarizes the incidences of wildfire within the three counties. It is not realistic to assume these totals apply solely to the WEC service area since it covers only portions of the seven counties of service. Table 1.18 Wildfire summary by county Average County # of Wildfires, Annual # of Wildfires Average Annual Acres Burned Acres Burned Christian Dallas ,055 2,011 0 Douglas , Greene Laclede , ,356 6 Webster , Wright , Totals 1, , , Source: Missouri State Hazard Mitigation Plan, 2010 Total Buildings Damaged In order to calculate the probability of a wildfire event in the Webster Electric service area, the proportion of the coop boundary of the total area in each of the nine counties was used in a linear weighted sum to arrive at the total number of wildfires in the WEC service area from The proportion of WEC service area out of the total square miles in each county were applied as weights to the total number of fires in each county and then summed producing a value of 180 total fires from (45(.079) + 178(.026) + 90(.0009) + 211(.084) + 250(.007) + 203(.748) + 203(.002) = ). This formula begs caution as it is based on the simple assumption that all wildfires are evenly 46-18

19 Potential Extent of Damage [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 distributed throughout each county. Using this value, the probability of wildfire occurrence in any is near 100% (180 events / 4 years = 4,500%). The potential extent of damage caused by wildfire is difficult to determine. Like earthquakes and dam failure, wildfires have had no measurable impact upon the WEC service area. To date, the estimated 180 fires have burned an estimated total of 2,091 acres (319(.079) + 10,055(.026) + 3,114(.0009) + 920(.084) + 6,778(.007) + 2,238(.748) + 1,235(.002) = 2,091), for an average of 11.6 acres affected per event. WEC sustained no damage related to wildfires in its service area during this time period. Cooperative assets are located throughout the service area rather than being located at a single central site. With an average of 11.6 acres per fire in the service area, it is unlikely that infrastructure damage would exceed 5% based upon asset location and unlikeliness of an uncontrollable wildfire. This initial assessment assumes a limited impact upon electric distribution infrastructure of less than 10% (Table 1.19). Further study will be required to create a model for damage assessments related to wildfire. Table 1.19 Probability of Hazard Occurrence Webster Electric Cooperative 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 WEC, it can be projected that less than 1% of all customers may report outages during any given wildfire event. Table 1.20 demonstrates the probability of occurrence in conjunction with the potent extent of impact upon local customers

20 Potential Extent of Impact May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Table 1.20 Webster Electric Cooperative 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 Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any Severe Land Subsidence (Sinkholes) Webster Electric service area is underlain primarily by carbonate rocks containing mainly limestone and some dolomite bedrock. These types of bedrock are extremely sensitive to water dissolution along joints and fractures within the rock. Areas along natural drainage paths tend to be more susceptible to sinkhole formation as well, due to increased water flow into the subsurface. There are 293 known sinkholes within the Webster Electric service area. Figure 5 shows the location of the sinkholes within Webster Electric s service area. (Map sources: Formation of sinkholes can and will affect Webster Electric. However, the impact of past sinkholes is statistically negligible. Since sinkhole formation occurs on a localized scale, property damage is negligible depending on structures immediately within or adjacent to the sinkhole area. However, for the purposes of this assessment, sinkholes and their 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%. Table 1.21 depicts the vulnerability of Webster Electric assets to the hazard of sinkholes based on probability of occurrence and extent 46-20

21 Potential Extent of Impact Potential Extent of Damage [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 of damage. Due to the localized nature of sinkhole impacts it is estimated that less than 1% damage will occur to the system due in the event of sinkhole formation. Table 1.21 Probability of Hazard Occurrence Webster Electric Cooperative Infrastructure Vulnerability Assessment Matrix Hazard: Sinkhole 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 Determining the potential extent of impact in terms of reported outages due to sinkhole formation is difficult to pinpoint; however, is very unlikely such an event would result in more than 10% of customers in the system reporting outages. Table 1.22 depicts the impact measured in reported outages combined with the probability of occurrence. Table 1.22 Webster Electric Cooperative Service Interruption Vulnerability Assessment Matrix Hazard: Sinkhole 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 Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 46-21

22 46-22 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] B. Non-historical Hazards Earthquakes One source of earthquake risk in southwest Missouri is the NeMaha Fault, which runs roughly from Oklahoma City, Oklahoma north to Lincoln, Nebraska. In 1993, the NeMaha fault produced an earthquake measuring a 2.9 magnitude on the Richter Scale. Additional quakes took place February 11, 1995 (3.1 magnitude); July 16, 2004 (3.5 magnitude); March 23, 2003 (3.1 magnitude). More recently, an earthquake of magnitude 3.6 was recorded on December 17, Although a relatively quiet fault system, the NeMaha fault has the potential to produce a damaging earthquake, profoundly impacting the Webster Electric Cooperative. The region is also subject to effects of 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 WEC 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. 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 on the Modified Mercalli Scale. 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 WEC 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 probability of an earthquake increases with each passing day. 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 experiences Level VI intensity characteristic 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 WEC 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 1.23.

23 Potential Extent of Impact Potential Extent of Damage [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Table 1.23 Probability of Hazard Occurrence Webster Electric Cooperative 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, it may be estimated that 1,875 customers could report outages related to an earthquake event. When compared with the total number of customers served by WEC, it can be projected that up to 10% of all customers may report outages during any given seismic event. Table 1.24 demonstrates the probability of occurrence in conjunction with the potent extent of impact upon local customers. Table 1.24 Webster Electric Cooperative 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 Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 46-23

24 Potential Extent of Damage Dam Failure May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Like earthquakes, dam failures have had no measurable impact upon the WEC service area to date. According to Missouri DNR s Dam Safety Division, 16 dams currently exist within the cooperative boundaries: one in Dallas County, two in Greene County, and 13 in Webster County. Of these dams, one in Greene County and two in Webster County 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 Webster s service area. (Map sources: 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. 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%. Table 1.25 Probability of Hazard Occurrence Webster 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 Determining the potential extent of dam failure is currently impossible due to a lack of data concerning inundation zones. Further study concerning existing dams and their impact is required to make a more comprehensive assessment of potential damages. This initial assessment assumes a limited impact upon downstream electric distribution 46-24

25 Potential Extent of Impact [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 infrastructure of less than 10% for both infrastructure damage and service interruption. (Tables 1.25 and 1.26). Table 1.26 Webster 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 Hazard Occurrence Less than 1% in any 1-10% chance in any given year 10-99% chance in any > Near 100% probability in any 46-25

26 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Section 6: Mitigation strategies Previous efforts at mitigation For organizations like WEC, 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 build, 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. Webster 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 WEC 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, WEC 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 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 46-26

27 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 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 WEC mitigation planning committee, with assistance from SMCOG staff, worked to identify goals, actions, and objectives which addressed hazard mitigation issues. The committee 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 eight objectives. Likewise, these eight objectives were grouped into similar categories and used as the basis for the three overarching goals. Table 1.27 provides a simple synopsis of the goals and objectives before prioritization. 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 1.27 Identified Goals Goal 1: Minimize Service disruptions due to natural disasters. Goal 2: Protect the health and safety to community Goal 3:Continue communication with the public and the community Webster Electric Cooperative goals and objectives Identified Objectives Objective 1: Continue maintenance and inspection plans. Objective 2: Research and develop plans for implementation where feasible to ensure minimal service interruptions. Objective 3: Improve vegetation management. Objective 1: Improve safety awareness and what to do in the event of outages due to natural hazards. Objective 2: Identify critical facilities and those that provide shelter in time of need. Objective 3: Coordinate with emergency management. Objective 1: Continue interactions with schools and community groups Objective 2: Provide a central location to provide information to public 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 WEC. Second tier actions create and maintain working relationships to reduce and prevent the impact of power outages. These include improvements to safety and 46-27

28 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] 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 1.28, 1.29, and 1.30 provide lists of action items by tier as well as the goals and objectives identified with each. Table 1.28 Prioritized Mitigation Actions for Webster Electric Cooperative Tier 1 Action item: Research and employ when feasible the use of organic or ecologically neutral herbicides for use in vegetation management programs. Tier 1 Goal/Objective Timeframe for Cost-benefit score completion Goal 1/Objective 3 Ongoing effort Low cost High benefit Score: 9 Maintain looped distribution service and other redundancies to critical facilities and/or communication infrastructure. Install additional poles to support transformers, as mid-span poles, or to shorten spans to no greater than 300 feet. Provide looped distribution service or other redundancies to critical facilities and key communications infrastructure. Goal 1/Objective 2 Ongoing effort Low cost Medium benefit Score: 6 Goal 1/Objective 2 Ongoing effort High cost Medium benefit Score: 4 Goal 1/Objective 2 Ongoing effort High cost Medium benefit Score: 4 Replace damaged poles with higher-rated poles of the same or different material with laminated coatings Enforce existing easements and expand inferior easements through cooperative efforts and eminent domain. Goal 1/Objective 2 Goal 1/Objective 1 Goal 1/Objective 2 Ongoing effort Dependent on additional funding High cost Medium benefit Score: 4 Install vibration dampeners and air foils to prevent galloping of conductor spans during high wind events. Goal 1/Objective 2 Dependent on additional funding Medium cost Low benefit Score: 2 Elevate or bury interstate or major highway crossing spans Goal 1/Objective 2 Dependent on additional funding High cost Low benefit Score:

29 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Table 1.29 Prioritized Mitigation Actions for Webster Electric Cooperative Tier 2 Action item: Research and develop plans for streamlined communications for outage events resulting from natural hazards. Tier 2 Goal/Objective Goal 1/Objective 1 Goal 1/Objective 2 Timeframe for completion Ongoing effort Cost-benefit Score Low cost High benefit Score: 9 Remove large diameter communication lines. Provide safety and reporting information to the general public through company websites, social media, local newspapers, presentations, and publications. Ensure that critical and vulnerable facilities served are provided outreach and education on best practices for generation use, alternate wiring, and transfer switching that are compatible with standard specifications and design and power delivery. Coordinate with local emergency managers to be included in emergency stakeholder groups and exercise participation. Create and keep a contact list available of important community and emergency management personnel. Goal 1/Objective 2 Goal 2/Objective 1 Goal 3/Objective 1 Goal 3/Objective 2 Goal 2/Objective 2 Goal 3/Objective 2 Dependent upon additional funding. Ongoing effort Ongoing effort. Low cost High benefit Score: 9 Low cost High benefit Score: 9 Low cost Medium benefit Score: 6 Goal 2/Objective 3 Completed annually Low cost Medium benefit Score: 6 Goal 2/Objective 3 Completed annually Low cost Medium benefit Score: 6 Table 1.30 Prioritized Mitigation Actions for Webster Electric Cooperative Tier 3 Action item: Collect GPS data and attribute information for functionality and code standards of existing infrastructure. Develop improved data management systems to track property damages and outages due to natural hazards. Tier 3 Goal/Objective Timeframe for Cost-benefit completion Goal 1/Objective 2 Ongoing effort Low cost High benefit Score: 9 Goal 1/Objective 1 Dependent upon Medium cost additional funding High benefit Score: 8 Develop more robust data management systems to monitor and record outages and damages directly related to natural hazards Continue to employ and develop GIS technology and applications to identify system failures and reduce response time for outages. Monitor developments in data availability concerning the impact of dam failure, wildfire and sinkholes upon the WEC service area through local, state, and federal agencies. Goal 1/Objective 1 Goal 1/Objective 2 Goal 1/Objective 1 Goal 1/Objective 2 Ongoing effort Ongoing effort Medium cost High benefit Score: 8 Low cost Medium benefit Score: 6 Goal 1 / Objective 2 Ongoing effort. Low cost Low benefit Score:

30 May 18, 2012 [WEBSTER 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 WEC employment level as the organization strives to ensure quality service to their customers. Other Local Planning Mechanisms Some internal planning mechanisms do exist at WEC. The Hazard Mitigation Plan can be considered and/or incorporated into regular budgetary planning and the four-year work plan. Beyond the WEC plan, few planning mechanisms exist at the local level. The Missouri counties of Webster, Greene, and Christian each 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). WEC s plan can be easily incorporated into these local plans and allow for coordination across agencies in the event of an emergency. WEC is located within the rural portions of many third-class counties which are prohibited from enforcing building codes and zoning by the state of Missouri. However, Greene and Christian counties are first and second class, respectively. These counties have comprehensive plans, planning and zoning commissions, subdivision regulations and building codes. WEC does provide service to all municipalities within its service area. Comprehensive plans and Capital Improvement plans exist for these entities. The Webster Electric Natural Hazard Mitigation Plan can easily be incorporated into future updates of these plans. Plan Maintenance Webster 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 Webster 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 WEC

31 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Webster Electric Chapter Appendix: Documentation of Participation Contents: : Meeting documentation Public Comment letter Press Release and Newspaper List 46-31

32 46-32 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE]

33 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Webster Electric Cooperative Hazard Mitigation Meeting 1 Summary 7/27/2011 I. Introductions: II. Coop information and to do list presented: a. Stakeholders Around 18,750 members in co-operative which is owned by the membership. A Touchstone Energy Cooperative. Board of Directors comprised on 9 persons is the governing body. Policy is board approved and internally developed. Company profile is available at www. swec.coop b. General customer information i. Number of customers served 18,750 ii. Residential vs. Nonresidential customers: Information needed. iii. Critical Facilities located within the service area: Coop serves critical facilities, incorporated communities and industrial centers. c. Average daily and annual usage/output: 1,200 kwh/monthly, 332,018,348 kwh/annual. III. Complete 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 BEC: a. Historical v. non-historic hazards i. Tornado ii. Severe Thunderstorm/High Wind/Hail iii. Severe Winter Storm 46-33

34 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] iv. Flood v. Wildfire vi. Sinkholes vii. Earthquake viii. Dam Failure V. Damage estimates and outage reporting for historical hazard events: Worksheet provided with NOAA/NCDC storm event data for coop boundary. VI. Consider ongoing mitigation and potential mitigation actions a. Date set for next meeting 46-34

35 [WEBSTER ELECTRIC COOPERATIVE] May 18,

36 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE] Webster Electric Cooperative Mitigation meeting summary August 17, 2011 Data collection- Damage and outage estimates returned Current list of mitigation actions: Install additional poles to support transformers, as mid-span poles or to shorten spans to no greater than 300 feet Continuing work towards a program to provide looped distribution service or other redundancies to critical facilities and key communications infrastructure Annual inspections of lines and poles Vegetation management GPS all infrastructure Review existing easement requirements and laws Potential list of mitigation actions: All actions listed above Research and develop plans for streamlined communications for outage events resulting from natural hazards Replace damaged poles with higher-rated poles of the same or different material or laminated coatings Examine Options for burying power lines Elevate or bury interstate or major highway crossings Install vibration dampeners and air foils to prevent galloping of conductor spans during high wind events Implement IVR (integrated voice response?) system to improve outage reporting Continue to employ and develop GIS technology and applications to identify system failures and reduce response time for outages Improve outage management using GIS system Cooperate with local law enforcement and government officials Partner with county emergency management to ensure power for local shelters, fuel stations, and public safety. Maintain mutual agreement with other state cooperatives. Potential list of Goals/Objectives: Goals A) Add resilience and resistance to existing infrastructure from impacts due to natural hazards. B) Minimize electric service disruptions and associated impacts to the public caused by natural hazards. C) Protect the health and safety of the public. D) Improve coordination and relationships with local emergency management personnel

37 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 E) Continue to promote public awareness and education concerning natural hazard impacts. Objectives a) Install containment anchoring structures. b) Increase structure, support and foundation component strength. c) Use strategies to minimize galloping. d) Improve Vegetation Management. e) Reduce restoration time of outages to vulnerable and critical facilities throughout the system. f) Develop and improve lines of communication with emergency management departments and public safety entities within cooperative boundaries. g) Incorporate mitigation strategies into capital improvements and future build out and work plans. h) Continue maintenance and inspection programs to lessen storm damage. i) Determine expected wind, flood, ice loading on systems and plan accordingly j) Continue to aggressively pursue vegetation management within utility rights of way

38 46-38 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE]

39 [WEBSTER ELECTRIC COOPERATIVE] May 18, 2012 Webster Electric Meeting 3 Summary October 10, 2011 Mitigation action cost/benefit scoring: Used methodology developed by lead RPC to score selected actions. Establish Final Goal and objective statements Method of prioritization: Unlike a political or governmental entity, the prioritization process for an electric cooperative requires different considerations when assigning values to specific mitigation actions. Mitigation goals and objectives were identified by representatives of the electric cooperative using a simple criterion as the baseline: reducing the impact of power outages due to natural hazards. Each established goal and objective adheres to this criterion by addressing the most important aspects of impact reduction: protection of the local community and infrastructure. Building from the goals and objectives, three mitigation action groups were identified: the committee assigned mitigation actions to tiers established by the lead RPC. The three additional tiers: Tier 1 Physical infrastructure protection and/or improvement to reduce power outages. Tier 2 Creating and maintaining working relationships to reduce and prevent the impacts associated with power outages during a natural hazard event. Tier 3 Potential projects for other system improvements to reduce response time and prevent impacts associated with power outages. Tier 1 projects are considered to be the most basic mitigation actions, and therefore the highest priority, which directly impact the potential threat of power outages. Without basic electric service, the second and third tier actions cannot be completed. Tier 2 projects focus on disaster planning, both internally and with outside agencies, to reduce the impact of natural hazard events. Tier 3 projects seek to identify and implement new technology and other types of system improvements. The documentation below demonstrates the actions associated with each tier

40 46-40 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE]

41 [WEBSTER ELECTRIC COOPERATIVE] May 18,

42 46-42 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE]

43 [WEBSTER ELECTRIC COOPERATIVE] May 18,

44 46-44 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE]

45 [WEBSTER ELECTRIC COOPERATIVE] May 18,

46 46-46 May 18, 2012 [WEBSTER ELECTRIC COOPERATIVE]