2016 Power System Reliability Report Prepared by Transmission & Distribution Planning Department Emera Maine May 1, 2017 2016 Power System Reliability Report Table of Contents Section Description Page I. Pre Exclusion Power System Reliability (All Outages In) 1 II. Post Exclusion Power System Reliability 2 III. Primary Outage Cause Category Analysis 3 IV. Detailed Outage Cause Code Analysis 7 V. Vegetation Management Program 11 VI. Distribution Circuit Inspection Program 13 VII. Distribution Facility Age 14 VIII. Reliability Improvement Actions 15 Attachment A – IEEE 2.5 Beta Method Attachment B – Emera Maine and Regional Pre Exclusion SQI Attachment C – Emera Maine and Regional Post Exclusion SQI Attachment D – Outage Impact by Detailed Cause Code 1 I. PRE EXCLUSION POWER SYSTEM RELIABILITY Transmission and Distribution (T&D) Planning personnel use outage data recorded by its PowerOn outage management system to derive pre-exclusion (a.k.a. all outages in) power system quality indices (PSQI) SAIFI, CAIDI and SAIDI on a monthly and annualized basis for the Company’s electrical system network. Prior to the removal of qualifying outage records associated with major event days identified through the application of the Institute of Electrical & Electronic Engineers (IEEE) 2.5 Beta method (which are typically associated with large weather events), the Company’s average annual pre exclusion SAIFI, CAIDI and SAIDI levels for the five year period 2012 through 2016 were determined to be 3.66, 5.39 and 19.71, respectively. Focusing in on the previous calendar year T&D Planners calculated 2016 pre exclusion power system reliability performance levels to be 4.28 (SAIFI), 3.99 (CAIDI) and 17.07 (SAIDI). Attachment B contains a tabular summary of monthly and annual pre exclusion SAIFI, CAIDI and SAIDI performance levels for the Company and its operating regions calculated both on a 5-year average and 2016 calendar year basis. 1 II. POST EXCLUSION POWER SYSTEM RELIABILITY Similar to recent Annual Reliability Improvement Reports, all “post exclusion” SAIFI, CAIDI and SAIDI statistics included within this report were developed using the IEEE 2.5 Beta Method for the purpose of identifying major event days for exclusion from these calculations, as specified by the approved Stipulation for Docket 2006-661. A description of this identification method is included on Attachment A. After the removal of all outage records associated with the aforementioned major event days identified for the period 2012 through 2016 the average annual post exclusion SAIFI, CAIDI and SAIDI were calculated to be 3.75, 2.14 and 5.88, respectively. Focusing in on the previous calendar year T&D Planners calculated 2016 post exclusion power system reliability performance levels to be 3.46 (SAIFI), 2.37 (CAIDI) and 8.22 (SAIDI). Attachment C contains a tabular summary of monthly and annual post exclusion SAIFI, CAIDI and SAIDI performance levels for the Company and its operating regions calculated both on a 5-year average and 2016 calendar year basis. 2 III. PRIMARY OUTAGE CAUSE CATEGORY ANALYSIS Through an analysis of pre and post exclusion outage data sets T&D Planners created performance summary tables that report average annual quantity of outage records, service interruption and hours off by main cause code for the five year period 2012 through 2016 and for calendar year 2016 only on both a pre exclusion (all outages in) and post exclusion (after the removal of major event day data) basis. These tables can be seen on the pages 4 and 5 of this report. Prior to the removal of outage data associated with major event days identified through the application of the IEEE 2.5 Beta Method weather was determined to be the primary and overwhelming driver of pre-exclusion SAIFI, CAIDI and SAIDI both for the 5-year period and calendar year 2016. Specifically, numerous thunder, ice/snow and windstorms that occurred during the five year period analyzed accounted for (on average) 3,209 outages (52%), 313,172 service interruptions (54%) and 2,655,668 aggregate hours of loss service (85%). Secondary drivers of pre exclusion SAIFI, CAIDI and SAIDI include the failure of power system equipment, customer caused accidents and vegetation contacts usually the result of trees and limbs falling from outside of a utility maintained clearance zone onto an energized conductor. During the five year time period analyzed equipment failure events accounted for an average quantity of 90,676 service interruptions and 145,962 hours of service delivery loss annually while customer caused outages (accidents) resulted in 53,668 service interruptions and 121,969 service interruptions. After the removal of outages associated with major event days weather remained the primary cause of post exclusion SAIFI, CAIDI and SAIDI performance levels. However, weather’s magnitude of impact relative to secondary drivers (equipment failure, customer caused accidents and vegetation contact) was reduced because almost all of the outage data associated with major event days was specific to the major identified weather events. 3 3,209 52% 313,172 Hours Off Percent of Total Quantity Percent of Total Percent of Total Outage Code Description Service Interruptions Quantity Outages Quantity Outage Code 5-Year Average Outages by Category Type (Pre Exclusions) 1 Weather 2 Vegetation Contact 624 10% 44,370 8% 79,590 3% 3 Accident by Others 390 6% 53,668 9% 121,969 4% 4 Animal or Bird 434 7% 20,116 3% 42,363 1% 5 Employee Error 17 0% 6,225 1% 2,266 0% 6 Equipment Failure 772 13% 90,676 16% 145,962 5% 7 Non-Specific Cause 52 1% 3,308 1% 2,836 0% 8 No Fault Found 533 9% 27,246 5% 30,909 1% 9 Overload 30 0% 275 0% 369 0% 10 Corrosion 6 0% 88 0% 168 0% 11 Scheduled Outage 78 1% 17,236 3% 26,150 1% 12 Vandalism 0 0% 0 0% 0 0% Annual Totals ==> 6,147 54% 2,655,668 576,381 85% 3,108,250 3,405 Percent of Total 1 Weather 2 Vegetation Contact 657 10% 42,938 6% 74,274 3% 3 Accident by Others 455 7% 64,571 9% 194,478 7% 4 Animal or Bird 544 8% 21,674 3% 36,830 1% 5 Employee Error 22 0% 10,489 2% 2,988 0% 6 Equipment Failure 12% 111,483 16% 191,914 7% 7 Non-Specific Cause 8 No Fault Found 9 828 51% 389,391 Hours Off Quantity Percent of Total Percent of Total Outage Code Description Service Interruptions Quantity Outages Quantity Outage Code 2016 Outages by Category Type (Pre Exclusions) 56% 2,195,301 79% 58 1% 313 0% 280 0% 549 8% 33,960 5% 42,774 2% Overload 37 1% 274 0% 386 0% 10 Corrosion 5 0% 6 0% 18 0% 11 Scheduled Outage 93 1% 20,647 3% 36,345 1% 12 Vandalism 0 0% 0 0% 0 0% Annual Totals ==> 6,653 695,746 4 2,775,587 1 Weather 2 Vegetation Contact 3 1,867 Hours Off Percent of Total Quantity Percent of Total Percent of Total Outage Code Description Service Interruptions Quantity Outages Quantity Outage Code 5-Year Average Outages by Category Type (Post Exclusions) 39% 172,130 40% 476,696 51% 621 13% 44,002 10% 79,118 9% Accident by Others 388 8% 53,498 12% 121,647 13% 4 Animal or Bird 433 9% 20,097 5% 42,275 5% 5 Employee Error 17 0% 6,225 1% 2,266 0% 6 Equipment Failure 767 16% 90,326 21% 145,391 16% 7 Non-Specific Cause 52 1% 3,308 1% 2,835 0% 8 No Fault Found 531 11% 27,217 6% 30,874 3% 9 Overload 30 1% 275 0% 369 0% 10 Corrosion 6 0% 88 0% 168 0% 11 Scheduled Outage 78 2% 17,229 4% 26,140 3% 12 Vandalism 0 0% 0 0% 0 0% Annual Totals ==> 4,790 434,396 927,779 1 Weather 2,342 2 Vegetation Contact 651 12% 3 Accident by Others 451 4 Animal or Bird 5 Employee Error 6 Equipment Failure 7 Non-Specific Cause 8 No Fault Found 9 Overload 10 Corrosion 11 Scheduled Outage 12 Vandalism Percent of Total 46% 758,951 57% 42,407 8% 72,677 5% 8% 63,761 11% 192,915 14% 544 10% 21,674 4% 36,830 3% 22 0% 10,489 2% 2,988 0% 15% 111,447 20% 191,858 14% 822 42% 257,597 Hours Off Quantity Percent of Total Percent of Total Outage Code Description Service Interruptions Quantity Outages Quantity Outage Code 2016 Outages by Category Type (Post Exclusions) 58 1% 313 0% 280 0% 546 10% 33,915 6% 42,706 3% 37 1% 274 0% 386 0% 5 0% 6 0% 18 0% 92 2% 20,617 4% 36,298 3% 0 0% 0 0% 0 0% Annual Totals ==> 5,570 562,500 5 1,335,908 The table inserted below provides a closer look at the impacts of storms on post exclusion SQI levels, specifically SAIFI. Post Exc Weather Serv Int Post Exc SAIFI 100,641 6 35,932 9 136,573 51,537 188,110 2 59,619 32% 128,491 2.26 2013 4 348,794 9 68,351 13 417,145 11,421 428,566 8 268,417 63% 160,149 2.81 2014 3 223,119 3 29,341 6 252,460 123,883 376,343 7 207,902 55% 168,441 2.88 2015 4 107,171 5 33,368 9 140,539 42,911 183,450 1 37,478 20% 145,972 2.34 2016 7 255,021 8 74,428 15 329,449 59,942 389,391 5 131,794 34% 257,597 3.46 Qty Serv Int Qty Serv Int Qty Serv Int % Excluded Serv Int Excluded 3 All Storms Total Weather 2012 Year Major Storms Minor Storms Other Weather IEEE MEDs Weather Caused Service Interruptions Note: Major storms are weather events that impacted 10% or more of all Emera Maine customers served while minor storms impacted 5% or more in either operating region. The above table shows that 2016 had the highest quantity of major storms and the second highest quantity of minor storm events compared to other years analyzed. Summing the effects of storm and non-storm weather events resulted in a 2016 weather impact of 389,391 service interruptions, which is second only to year 2013 during which the December ice storm occurred. 2016’s level of post exclusion service interruptions caused by weather was at least 50% higher than all other years and the overwhelming cause of its high SAIFI level. 6 IV. DETAILED OUTAGE CAUSE CODE ANALYSIS Expanding its outage cause code analysis work T&D Planners created a series of tables that summarize the quantity of outage records, service interruptions and hours of service down-time on a pre and post exclusion basis by Main Cause Code Category and subordinate Detailed Cause Codes for the five year time period of 2012 through 2016 and for calendar year 2016 only. These tables are included in Attachment D of this report. Figures IV.1a and IV.1b seen on the next page reports the Top Ten causes of pre exclusion service interruptions and hours of service interruption experienced by customers for the 5-year period 2012 through 2016 and for calendar year 2016 only. These charts show that the impacts of storms (i.e., wind, thunder and snow/ice storms) upon the power system were the overwhelming cause of outages experienced by customers annually during the 5-year period followed by car/pole accidents caused by customers and the failure of distribution equipment. These charts also show that in calendar year 2016 thunderstorms caused the second highest quantity of service interruptions while windstorms resulted in the greatest amount of lost service interruption time. After the removal of all outage records associated with identified major event days for years 2012 through 2016 T&D Planners created Figures IV.2a and IV.2b, which can be seen on page 9 of this report. These charts report the Top Ten causes of post exclusion service interruptions and hours of service interruption experienced by customers and show that the impacts of storms upon the power system remained the overwhelming annual driver of post exclusion service interruptions and hours of loss power flow experienced by customers during the 5year period 2012 through 2016 and during 2016 alone. Similar to pre exclusion performance statistics, secondary non-storm drivers of post exclusion service interruptions and hours of loss service delivery remained customer caused car/pole collisions and the failure of distribution equipment. 7 Top 10 Causes of Service Interruptions (Pre Exclusion) 250,000 2 200,000 2 [IS-Year Average (2012-2016) OYear 2016 OJ 150,000 .3 100,000 0 50,000 -- . "v ?0 ?669 .50 $0 ??60 3" .51" '3 053? 931(?95 ?3?6 LOQ 59? Koo \0 Figure IV.la ?0 45% 4? Top 10 Causes of Service Interruption Hours (Pre Exclusion) 2,000,000 5 '13- 1,600,000 Average {2012-2016} IYear 2016 1,200,000 .3 3' 5 800,000 U1 In 3 400,000 . Kg," hp b. {a ?0 9?5: 43. Figure V.1b 9 4% Service Interruptions Top 10 Causes of Service Interruptions (Post Exclusion) 150,000 120,000 . El 5-Year Average {2012-2016} 0 Year 2016 90es? ?386 ?35? ??46Figure ?63 c: 43% Hours Service Interruption Top 10 Causes of Service Interruption Hours (Post Exclusion) 600,000 500,000 El 5-Year Average (2012-2016} I Year 2016 400,000 300,000 200,000 - . 100,000 l?b? ?a?o 06? e9 006 {>96 org'45?50 06? ??33 -o 11Figure V.2b Note: Following up on the recommendation of the Liberty Group resulting from the 2016 Management Audit, the Company has added a detailed cause code for “Lightning” within its weather main cause code group and will be training field personnel on its proper use. While the full impact of lightning strikes was always captured by the Company, they will no longer comprise data coded as “thunderstorm”. Instead, beginning with next year’s Annual Reliability Report the detailed cause code of Lightning will appear in Attachment D summarizes and will represent observable impacts to the power system from a physical lightning strike while thunderstorm coded outages will represent impacts caused by associated high winds. 10 V. VEGETATION MANAGEMENT PROGRAM Per the stipulation as a result of Docket 2013-00443, the Company agreed to report the following related to its distribution vegetation management program as part of its Annual Reliability Improvement Report: 1. Data on the numbers of spans trimmed annually and cumulatively along with the six-year cycle trim targets; 2. The annual amounts spent on the program A. Emera Maine’s Distribution Vegetation Management Program Emera Maine has an enhanced, three-tier distribution line clearance program: one-part cycle based, one-part “special consideration”, and onepart performance based. The Cycle based portion consists of vegetation management on the entire overhead distribution system by circuit, from substation to end of line; targeting and trimming all sections which do not meet our current line clearance standards. Our current plan is for a six year cycle. The Special Consideration portion puts those line sections which feed a larger number of customers (currently set at >1000) on a more frequent cycle, currently set at a maximum of three years. The Performance based portion of the plan takes a look at a number of factors in order to target specific line sections to improve their and the system’s performance related to tree-related outage. B. Annualized and Cumulative Number of Miles & Spans Trimmed vs Target The table below reports the 2014 through 2016 quantities of distribution miles and spans trimmed on both an annualized and cumulative basis vs. targets for our distribution vegetation management program.. 11 2014 - 2016 Annualized 2014 - 2016 Cumulative Targeted Miles 1,161 3,483 Targeted Spans 30,649 91,946 Completed Miles 1,212 3,637 Completed Spans 32,005 96,016 Emera Maine has averaged 1,212 miles trimmed for each of the last 3 years. This is ahead of our 1,161 mile target by 51 miles. C. Distribution Vegetation Management Program Spend The annual average spend over the last 3 years is $4,187,253. This is above the stipulated minimum spend level of $4,146,965 by $40,288. Going forward, Emera Maine will continue to maintain an average annual spend greater than $4,146,965. 12 VI. DISTRIBUTION CIRCUIT INSPECTION PROGRAM Per the Stipulation as a result of Docket 2013-00443, the Company agreed to report the following related to its distribution line inspection program as part of its Annual Reliability Report: (3) the results of its Line Inspection Program including number of poles inspected, problems detected and problems resolved In 2016, Emera Maine inspected approximately 1,520 primary distribution miles which equates to approximately 56,900 inspected poles. Below is a summary table of both issues detected and issues resolved as a result of our inspection program in 2016. The variance in quantity of issues detected and resolved is driven by the customary lag between the time issues are detected and then budgeted and planned for construction. “Issued Resolved in 2016” includes primarily issues detected from prior years and “Issues Detected in 2016” are currently in progress of being resolved. Inspection Issue Type Issues Detected in 2016 anchor or guy animal guard clearance conductor crossarm dead end disconnect grounding/bonding hardware other padmount pole rebuild or reconductor slack transformer 120 3007 12 6 193 3 4 1689 55 148 3 524 48 39 75 5926 13 Issues Resolved in 2016 23 5 4 1 27 1 1 38 15 12 0 97 7 5 7 243 VII. DISTRIBUTION FACILITY AGE Per the Stipulation as a result of Docket 2013-00443, the Company agreed to report the following related to its distribution plant age as part of its Annual Reliability Improvement Report: (4) The average age of its major distribution plant categories The table below reflects the 2016 average age of Emera Maine’s distribution plant assets by major FERC category. FERC Category 360 361 362 364 365 366 367 368 369 370 371 373 Primary Assets Land & Land Rights Stonework, Excavation, Roof, & Gravel Station Transformers and Equipment Poles, Towers and Fixtures Overhead Conductors and Devices Underground Conduit Underground Conductor and Devices Line Transformers and Equipment Service Cable and Equipment Meters Fault Locators Street Lighting 14 Average Age (yrs) 19 29 14 16 18 23 17 18 21 11 19 23 VIII. RELIABILITY IMPROVEMENT ACTIONS The Company continues to identify and execute methods to improve the reliability of its electrical power network:  The Company completed all visual inspections planned for 2016 which included all of the circuits missed in previous years (2014/2015) with a goal of being caught up by 2019.  The Company developed a storm impact prediction tool using detailed analysis of archived storm outage data. This tool better enabled operational personnel to stage and position crews for the purpose of improving response for storms that had a potential for significant impact based upon their wind speed/direction, precipitation type/amounts and location of impact.  In early 2017 the Company created two new roles in an effort to further expand its focus on reliability. These roles and notable responsibilities are: Reliability Engineer  Review all major planned (scheduled) maintenance outages looking for ways to reduce or eliminate event impact on customers  Formalize the use of Root Cause Failure Analysis (RCFA) for all significant unplanned outages  Review vegetation management program for potential enhancements or improvements with high reliability impact  Review the benefits of expanded use of drones, thermal imaging (IR), corona or other technologies in inspection and maintenance programs  Establish a cost benefit criteria for both capital and operations projects, based on a cost per avoided customer interruption and/or cost per customer hour of interruption basis  Analyze outage data for the purpose of identifying short & long term outage mitigation projects/programs (such as targeted equipment replacements, wildlife protection, targeted application of “tree wire” and overcurrent protection and system automation) 15 Line Operations Engineer (Hiring in progress)  Lead line operations in the utilization of Systematic Cause Analysis Techniques (SCAT) for both safety incident and maintenance issues  Oversee line and meter infrared scanning program  Promote efficiency improvements throughout line and meter departments  Understanding drivers of SAIFI and CAIDI and determine innovative ways to improve these reliability goals 16 ATTACHMENT A 2.5 Beta Method 2.5 Beta Method A description of 2.5 beta method used for the identification of major event days follows: 1. Collect values of daily for five sequential years ending on the last day of the last complete reporting period. If fewer than five years of historical data are available. use all available historical data. If any day in the data set has a value of zero for SAIDI, do not include that day in the analysis. Compute the natural logarithm (In) of each daily SAIDI value in the data set. Find an (Alpha). the average of the logarithms (also known as the log- average) of the data set. Find [3 (Beta). the standard deviation of the logarithms (also known as the log-standard deviation) of the data set. Compute the major event day threshold. TMED. using the equation: TMED Any day with daily SAIDI greater than the threshold value TMED that occurs during the subsequent reporting period is classified as a major event day. (Note that the calculated Tmed value should in theory give. on average. 2.3 major event days per year. In practice. using the donated utility data. higher numbers of major event days per year. from two to eight. are seen. This is not unexpected since the actual data does not conform precisely to the log-normal distribution.) ATTACHMENT Emera Maine and Regional Pre Exclusion SQI 5-Year Average SAIFI by Region Company (Pre Exclusion) 2016 SAIFI by Region 8. Company (Pre Exclusion) Month Southern Operating Region Northern Operating Region Company suondnuetul eawes esea Jewotsna HIVS suondnuetul aowes suoudnuami aowes a In In Jemotsno HIVS Month Southern Operating Region Northern Operating Region Company suoudnuetm eowes esea Jamman HIVS Jamman suoudnuetull asea eowes HIVS suoudnueam eowes .IBIUOISTIO HIVS January 54.366 1 20.032 0.45 6.910 61 .275 156.018 0.39 January 69.499 123.179 0.56 3.201 35.856 0.09 72.700 159.035 0.46 February 30.923 1 20.033 0.26 4.109 35.967 35.032 156.000 0.22 February 66.087 1 23.232 0.54 6.916 35.841 0.19 73.003 159.073 0.46 March 24.812 1 20.1 33 0.21 3.311 35.947 28.1 23 156.080 0.1 8 March 28.994 1 23.468 0.22 4.833 35.813 0.1 3 31.827 159.281 0.20 April 31.135 1 20.747 0.26 4.708 35.941 35.844 156.688 0.23 April 65.110 1 24.935 0.52 4.393 35.832 0.12 69.503 160.767 0.43 May 18.883 121.783 0.16 7.891 35.973 26.774 157.756 0.1 7 May 25.990 1 26.827 0.20 10.579 35.888 0.29 36.569 162.715 0.22 June 21 .699 1 22.640 0.18 13.587 35.988 0.38 35.286 158.628 0.22 June 20.315 1 28.374 0.16 2.937 35.902 23.252 1 64.276 0.14 July 41 .703 122.842 0.34 20.098 36.002 0.56 61.801 158.845 0.39 July 34.966 1 28.725 0.27 35.443 35.904 0.99 70.409 164.629 0.43 August 25.641 123.096 0.21 12.0 89 36.008 0.34 37.729 159.103 0.24 August 33.910 1 29.235 0.26 5.753 35.920 0.16 39.663 165.155 0.24 September 43.264 123.092 0.35 7.906 36.000 0.22 51.170 159.091 0.32 September 60.051 1 29.384 0.46 15.352 35.912 0.43 75.403 1 65.296 0.46 October 42.981 1 22.473 0.35 5.792 35.958 0.16 48.772 158.431 0.31 October 53.801 1 28.524 0.42 1.925 35.859 0.05 55.726 1 64.383 0.34 November 51.214 121,989 0.42 3.766 35.937 0.10 54.980 157.926 0.35 November 14.415 1 27.698 0.11 2.631 35.841 0.07 1 7.046 1 63.539 0.10 December 89.191 121.826 0.73 10.401 35.937 0.29 99.593 157.762 0.63 December 112.682 1 27.373 0.88 17.963 35.831 0.50 130.645 1 63.204 0.80 Annual 475.813 121 .724 3.91 100.568 35.970 2.80 576.381 157.694 3.66 Annual 583.820 1 26.746 4.61 111.926 35.867 3.12 695.746 1 62.613 4.28 5-Year Average by Iggion 8. Company Month Southern Operating Region Pre Exclusion) 2016 CAIDI by Regi_on 8. Company (Pre Exclusion) Northern Operating Region Company HO s?WI-l ICING HO SMOH ICIIVO no man ICIIVO Month Southern Operating Northem Operating Company Region HO IGIVO suoudnuetuu eowes Region no SJUDH ICIIVO suondnuetuu 110 51mm January eowes 3 315.037 5.79 suondnuetuu eowes to 1 2.674 1.83 suoudnuew] eawes 5 327.71 1 5.35 January suondnuatup 3 engines 3 786.156 11.31 3.201 21.283 6.65 807.439 February 30.923 1 02.0 57 3.30 4.109 8.162 1 .99 35.032 110.219 3.15 February 66.087 313.845 4.75 6.916 22.752 3.29 336.597 March 24.81 2 66.41 5 2.68 3.311 5.1 98 1.57 28.123 71.614 2.55 March 26.994 49.333 1.83 4.833 1 1 .396 2.36 60.729 April 31.135 104.149 3.35 4.708 9.450 2.01 35.844 113.599 3.17 April 65.110 367.315 5.64 4.393 4.006 0.91 371.321 5.34 May 18.883 35.926 1.90 7.891 1 5.448 1.96 26.774 51 .374 1 .92 May 25.990 55.932 2.1 5 1 0.579 1 2.888 1.22 68.819 1 .88 June 21 .699 53.807 2.48 1 3.587 1 6.1 50 1.19 35.286 69.958 1 .98 June 20.315 42.902 2.1 1 2.937 11.840 4.03 54.742 2.35 July 41 .703 254.875 6.11 20.098 41 .898 2.08 61.801 296.773 4.80 July 34.966 52.663 1.51 35.443 28.846 0.81 81.509 1.16 August 25.641 61.251 2.39 1 2.089 1 6.337 1.35 37.729 77.588 2.06 August 33.910 107.954 3.18 5.753 1 3.942 2.42 1 21 .896 3.07 September 43.264 97.568 2.26 7.906 12.206 1.54 51.170 109.774 2.15 September 60.051 32.568 0.54 1 5.352 16.881 1.10 49.449 0.66 October 42.981 88.587 2.06 5.792 1 3.292 2.30 48.772 101.880 2.09 October 53.801 100.071 1.86 1 .925 3.866 2.01 103.937 1.87 November 51.214 827.141 16.15 3.766 8.803 2.34 54.980 835.944 1 5.20 November 1 4.41 5 36.876 2.56 2.631 2.813 1 .07 39.689 2.33 December 89.191 911.361 10.22 10.401 30.457 2.93 99.593 941.818 9.46 December 112.682 607.269 5.39 17.963 72.191 4.02 679.460 5.20 Annual 475.813 2.91 8.1 74 6.13 100.568 190.077 1.89 576.381 3.108.250 5.39 Annual 583.820 2.552.883 4.37 111.926 222.704 1.99 695.746 2.775.587 3.99 5-Year Average SAIDI by Region 8. Company l[Pre Exclusion) 2016 by Region 8. Company (Pre Exclusion) Month Souther=n Operating Region Northern Operating Region Company .IBLLIOISUO no smoi-l esea Jemoasna no asea no 51710? Month Southern Operating Northern Operating Company esea Region 140 SJHOH Region ?0 esea go January 120.032 31 5.037 36.115 1 2.674 156.016 327.711 0 lows 0 January 123.179 766.1 56 U) 636 :9 e529 3 21 .263 CI laws 3 159.035 607.439 February 120.033 1 02.057 36.119 6.162 8 IOIVS a a 156.000 110.219 h. 0 February 123.232 31 3.645 2.55 35.641 22,752 5 159.073 336.597 March 1 20.1 33 66.41 5 0.55 36.100 5.196 156.060 71.614 0.46 March 123.466 49.333 35.613 11.396 6? a 159.261 60.729 April 1 20.747 104.149 0.66 36.076 9.450 0.26 156.666 113.599 0.72 April 124,935 367.31 5 35.632 4.006 0.11 160.767 371.321 May 121.763 35.926 0.30 36.063 15.446 0.43 1 57.756 51 .374 0.33 May 1 26.627 55.932 35.666 12.666 0.36 162.715 66.619 June 122.640 53.607 0.44 36.097 16.150 0.45 156.626 69.956 0.44 June 126.374 42.902 0.33 35.902 11.640 0.33 1 64.276 54.742 July 122.642 254.675 2.07 36.114 41.696 1.16 156.645 296.773 1 .67 July 126.725 52.663 0.41 35.904 26.646 0.60 164.629 61.509 August 123.096 61.251 0.50 36.100 16.337 0.45 159.103 77.566 0.49 August 129.235 1 07.954 0.64 35.920 1 3.942 0.39 165.155 121.696 September 123.092 97.566 0.79 36.094 12.206 0.34 159.091 1 09.774 0.69 September 1 29.364 32.566 0.25 35.912 16.661 0.47 165.296 49.449 October 122.473 66.567 0.72 36.060 1 3.292 0.37 156.431 101.660 0.64 October 1 26.524 100.071 0.76 35.659 3.666 0.11 164.363 1 03.937 November 121.969 627.141 6.76 36.049 6.603 0.24 157.926 635.944 5.29 November 1 27.696 36.676 0.29 35.641 2.613 0.06 1 63.539 39.669 December 121.626 911.361 7.46 36.034 30.457 157.762 941.616 5.97 December 1 27.373 607.269 4.77 35.631 72.1 91 2.01 1 63.204 679.460 Annual 121 .724 2,916,174 23.97 36.067 1 90.077 5.27 1 57.694 3.106.250 19.71 Annual 126.746 2,552,663 20.14 35.667 222.704 6.21 162.613 2.775.567 ATTACHMENT Emera Maine and Regional Post Exclusion SQI 5-Year Average by Region 8. Company Post Exclusion) 2016 SAIFI by Region Company (Post Exclusion) Southern Operating Northern Operating Region Region company 1311101511 1901015? .IaLuoxsng Month esea HIVS 9 suopdnuawu eowes Month Southern Operating Region Northern Operating Region Company JOLIJOIS UM asea HIVS suopdnuewu 9915199 9599. Jammsno IJIVS suondnuewn comes 3 HIVS January 120,032 0.27 3, 0.10 156,018 0.23 January suoudnuewll aowas 3 123,179 0.21 3 9315185 I 1 35,856 0.03 26,305 159,035 0.17 February 26,529 120,033 0.22 4,085 0.11 30,614 156,000 0.20 February 44,118 1 23,232 0.36 6,794 35,841 0.19 50,912 159,073 0.32 March 22,158 120,133 0.18 3,311 35,947 0.09 25,468 156,080 0.16 March 26,994 1 23,468 0.22 4,833 35,813 0.13 31,827 159,291 0.20 April 25,796 120,747 0.21 4,708 35,941 0.13 30,504 156,688 0.19 April 38,41 2 124,935 0.31 4,393 35,832 0.12 42,805 1 60,767 0.27 May 121,783 0.16 7,891 35,973 0.22 26,774 157,756 0.17 May 25,990 126,827 0.20 1 0,579 35,888 0.29 35,559 162,715 0.22 June 21,699 122,640 0.18 13,587 35,988 0.38 35,286 158,628 0.22 June 20,31 5 1 28, 374 0.16 2,937 35,902 0.08 23,252 164,276 0.14 July 122,842 0.24 17,282 36,002 0.48 46.686 158,845 0.29 July 34.966 1 28,725 0.27 35,443 35,904 0.99 70,409 164,629 0.43 August 25,641 123,096 0.21 12,089 36,008 0.34 37,729 159,103 0.24 August 33,910 1 29,235 0.26 5,753 35,920 0.16 39.663 165,155 0.24 September 32,494 123,092 0.26 7,225 36,000 0.20 39,719 159,091 0.25 September 60,051 129,384 0.46 1 5,352 35,912 0.43 75,403 165,296 0.46 October 42,981 122,473 0.35 5,792 35,958 0.16 48,772 158,431 0.31 October 53,801 1 28,524 0.42 1,925 35,859 0.05 55.726 164,383 0.34 November 24,759 121,989 0.20 3.615 35,937 0.10 28,374 157,926 0.18 November 14,415 127,698 0.11 2,631 35,841 0.07 17,945 163,539 0.10 December 37,893 121,826 0.31 10,399 35,937 0.29 48,292 157,762 0.31 December 74,624 127,373 0.59 17,959 35,831 0.50 92,583 163,204 0.57 2.61 2.75 Annual 340,693 121,724 2.80 93,703 35,970 434,396 157,694 Annual 452,887 1 26.746 3.57 109,613 35,867 3.06 552,590 162,613 3.46 5-Year Average CAIDI by Region Company Post Exclusion) 2016 CAIDI by Region 8. Company (Post Exclusion) Month Sout?em Operating Region _Northem Operating Region Company suondnua; aawa ICIIVO ICIIVO HO Month Southern Operating? Region Northern Operating Region Company suoudnuezulr engines 90 ICIIVO 90 ICIIVO suondnuetul eowes HO smoH January .2. 32.457 HO SmOI-il 81 ,506 2.51 1.24 suogdnuezuu eowes 36,177 86,128 2.38 January 25.291 145.292 5.74 1- suoudnuewn :5 aowas - 5 4.19 26,305 149,536 February 26,529 65,479 2.47 1.98 30,614 73,560 2.40 February 44.118 1 30,957 2.97 6.794 22.347 3.29 50,912 153,304 March 22.156 38,095 1 .72 1.57 25,466 43,293 1 .70 March 26.994 49.333 1.83 4.833 11.396 2.36 31 ,827 60,729 April 25.796 60,013 2.33 2.01 30,504 69,463 2.26 April 36.412 146.639 3.82 4.393 4.006 0.91 42,805 150,644 May 16.863 35,926 1 .90 1.96 26,774 51,374 1 .92 May 25.990 55.932 2.15 10.579 12,333 1.22 36,569 68,819 June 21 .699 53, 807 2.48 1.19 35,286 1.96 June 20.315 42.902 2.11 2.937 11.840 4.03 23,252 54,742 July 29,404 52,291 1.76 1.15 46,686 72,202 1.55 July 34.966 52.663 1.51 35,443 26,846 0.81 70,409 81,509 August 25,641 61,251 2.39 1.35 37.729 77.588 2.06 August 33.910 107.954 3.18 5,753 1 3,942 2.42 39,663 121,896 September 32,494 46,003 1.42 1.55 39,719 57,209 1.44 September 60.051 32.568 0.54 15.352 16.861 1.10 75,403 49,449 October 42,981 33,537 2.06 2.30 46.772 101.880 2.09 October 53,801 100,071 1.66 1,925 3,866 2.01 55.726 103.937 November 24,759 61,900 3.31 2.31 28,374 90,263 3.18 November 14,415 36,876 2.56 2,631 2,813 1 .07 17.046 39.669 December 37,393 104,456 2.76 2.92 48.292 134.862 2.79 December 74,624 229,471 3.06 17,959 72,183 4.02 92.583 301 .654 Annual 340,693 769,316 2.26 158.463 1 .69 434.396 927.779 2.14 Annual 452,887 1.130.656 2.50 109,613 205,252 1.87 562,500 1,335,908 5-Year Average SAIDI by Region Company {Post Exclusig)" Southern Operating Region Northern Operating Region Company 1901015? HO SJHOH 3513 Month 3 IOIVS no asea Jamotsna (D In ?0 IGIVE Southern Operating Region Northern Operating Region .r-nu?w-q I: 2016 SAlPl_by_R_eg_ion_& Company (Post Exclusion) . mr- -. . Company Month ?0 140 51001-0 1801035113 3529 :awomsno HO January 120,032 81,506 . 36,115 4,521 0.13 156,018 86,128 0.55 January 123,179 145,292 . 35,856 5 159,035 149,536 no In Iowa 3 3 February 120,033 65,479 . 36,119 8,081 156,000 73,560 0.47 February ID a 123,232 130,957 35,841 159,073 153,304 March 120,133 33,095 ?3 36,100 5,198 0.14 156,080 43,293 0.28 March April 120,747 60,013 0.50 36,078 9,450 0.26 156,688 69,463 0.44 April 123,468 49,333 0.40 35,813 11,396 . 159,231 50,729 383 lows: a, a 124,935 146,639 1.17 35,832 4,006 . 160,767 150,644 0.94 May 121,783 35,926 0.30 36,083 15,448 0.43 157,756 51,374 0.33 May 126,827 55,932 0.44 4 a) 0 12 22,347 0.35,888 12,888 . 162,715 53,319 0.42 June 122,640 53,807 0.44 36,097 16,150 0.45 158,628 69,958 0.44 June 128,374 42,902 0.33 35,902 11,340 1 64,276 54,742 0.33 July 122,842 52,291 0.43 36,114 19,911 0.55 158,845 72,202 0.45 July 128,725 52,663 0.41 35,904 28,846 0.80 164,629 81,509 0.50 August 123,096 61,251 0.50 36,100 16,337 0.45 159,103 77,533 0.49 August 129,235 107,954 0.84 35,920 13,942 0.39 165,155 121,896 0.74 September 123,092 46,003 0.37 36,094 11,206 0.31 159,091 57,209 0.36 September 129,384 32,568 0.25 35,912 16,881 0.47 165,296 49,449 0.30 October 122,473 68,587 0.72 36,060 13,292 0.37 158,431 101,880 0.64 October 1 28,524 100,071 0.78 35,859 3,866 0.11 134,333 1 03,937 0.63 November 121,989 81,900 0.67 36,049 8,362 0.23 157,926 90,263 0.57 November 127,698 36,876 0.29 35,841 2,813 0.08 163,539 39,689 0.24 December 121,826 104,456 0.66 36,034 30,406 0.84 1 57,762 134,862 0.85 December 127,373 229,471 1 .80 35,831 72,183 2.01 163,204 301 .654 1.85 Annual 121,724 769,316 6.32 36,087 158,463 4.39 157,694 927,779 Annual 8.92 35,867 205,252 5.72 162,613 1,335,908 8.22 126,746 1,130,656 ATTACHMENT Outage Impacts by Detailed Cause Code 5-Year Average outage 'mPaCts by Main 8; Detailed Cause Code (Pre Exclusions) Service Codes Hours Off Cause Snow or Ice 8.3% 53.6% ransm Distribution Trim Tree Fall from Outside of ROW Customer Cut Tree Down on Line Buried Cable Construction Work Too Close to Line Fire or Police Faulted Transformer au aulted Error ntenance Error Generation Failure Substation Failure Undersized Generation ui Transmission ment Substation Substation 146 31 172 Trim 79 53 666 Animal or 363 Em Error 266 ui Failure . 90 676 145 962 Cause 2? 246 30 909 88 168 Scheduled 1? 236 26 150 ?Iu! 5-Year Average Outage Impacts by Main 8. Detailed Cause Code (Post Exclusions) Service Codes Hours Off Desori ption ?In Total Inade Distribution Trim Tree Fell from Outside of ROW Customer Cut Tree Down on Line Buried Cable Du Construction Work Too Close to Line Re Fire or Police Transmission Conductor Faulted Switch Faulted Error Desi Error Generation Failure 3 ure lure Failure Transformer Undersized Generation Transmission ment 3 ment Transmission Re Weather . 476 696 Accident Others . 121 647 Em Error Failure 145 Non-S Cause 30 4 Overload . . 163 Scheduled . 26 140 2016 Outage Impacts by Main 8; Detailed Cause Code (Pre Exclusions) Hours Off Main Cause Total Total Thunderstorm Wind FlreiFlood Transmission Trim Tree Fell from Car Pole on Line Buried Cable Fauited Transmission Faulted Bus Error Error Substation Failure Cable Detail in Comments Transformer Transmission Distribution Distribution Customer Weather Others Animal or Failure Found Ove?oad Scheduled 2016 Outage Impacts by Main 8. Detailed Cause Code (Post Exclusions) Service Main Cause Total Total 10 11 Snow or ice Distribution Trim of ROW Trim Car Pole Accident Customer Down on Construction Work Too Close to Llne Transiormer Fauited Construction Error Premise Turned Off Transmission Failure Cable Failure Service or Meter Transformer Undersized Transmission allure Weather Trim Animal or Bird Contact Overload Scheduled