STATE OF MICHIGAN Case No.: U-18255 Page: 1 of 48 BEFORE THE MICHIGAN PUBLIC SERVICE COMMISSION In the matter of the Application of ) DTE GAS COMPANY ) for authority to increase its rates, amend ) Case No. U-17999 its rate schedules and rules governing the ) distribution and supply of natural gas, and ) for miscellaneous accounting authority. ) In the matter of the Application of ) DTE ELECTRIC COMPANY ) for authority to increase its rates, amend ) Case No. U-18014 its rate schedules and rules governing the ) distribution and supply of electric energy, and ) for miscellaneous accounting authority. ) Smart Grid - Annual Report The Michigan Public Service Commission (Commission) in its December 9, 2016 order in Case No. U-17999 (DTE Gas s General Rate Case) adopted the Michigan Public Service Commission Staff s (Staff) recommendation that DTE Gas Company file an annual report in response to the 43 smart grid reporting metrics identified on Exhibit S-9.0. Also, the Commission s January 31, 2017 order in Case No. U-18014 (DTE Electric s General Rate Case) agreed with Staff s recommendation regarding the same reporting requirements mentioned above, and contained in Exhibit S-10. In its Order, the Commission directed DTE Electric to provide its first AMI report by July 1, 2017, and subsequent annual reports by February 15 beginning in 2018. Based on the above stated Orders in both DTE Gas and DTE Electric s (DTE Energy) general rate cases, the following is DTE Energy s Smart Grid Annual Report, which provides information on the 43 metrics included in Staff s Exhibit S-9.0 (Case No. U- 17999) and Exhibit S-10 (Case No. U-18014).
Page: 2 of 48 Q1. Number of electric AMI meter failures A. See table below which identifies AMI meter failures from January 1, 2016 through March 31, 2017. Failure Cause Firmware Hardware Environment Misc Pending Salvage Total Invest. OpenWay 2,049 884 458 51 527 3,522 7,491 Single Phase OpenWay Poly 54 44 1 10 139 248 Phase OpenWay Cell 3 58 1 2 5 69 Relay All OpenWay 2,106 986 460 53 537 3,666 7,808 The breakdown of AMI meter failures by category is included in the tables below.
Page: 3 of 48 Number of electric AMI meter failures (Single Phase Breakdown) Single Phase Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17 Feb-17 Mar-17 Grand Known Failure Grouped Failure Category Total Handling Environmental Issue 0 High Voltage Transient Environmental Issue 10 4 1 1 16 Hot Socket Environmental Issue 3 19 1 4 4 31 Sustained Overvoltage Environmental Issue 24 38 14 4 16 96 Water Residues/Corrosion Environmental Issue 56 107 28 8 1 115 315 Core Dump not complete Firmware Defect 9 13 2 4 6 34 Error 3 Firmware Defect 1 10 1 12 Error 4 Firmware Defect 9 4 13 Error 5 Firmware Defect 1 1 Error 7 Firmware Defect 0 Error Code Firmware Defect 1 1 Fatal 2 - Maxima Bad Saved RAM Firmware Defect 4 5 3 5 17 Fatal 2 - Maxima EPF Not Detected Firmware Defect 0 Fatal 5 - Maxima BAT Over Current Firmware Defect 30 29 5 3 5 29 101 Fatal 5 - Maxima EPF not Detected Firmware Defect 133 312 93 10 72 129 749 Fatal 5 - Maxima IPM1 Reset Firmware Defect 29 45 4 1 7 11 97 Fatal 5 - MaximaBadEPFData Firmware Defect 2 6 4 3 3 18 Fatal 7 - Bit Flip / Rollover Issue Firmware Defect 1 1 2 1 5 Fatal 7 - Maxima Fault Firmware Defect 44 120 22 51 14 251 Fatal 7 - Zigbee Stack Lock up Firmware Defect 0 Fatal Error 1 Firmware Defect 2 5 1 2 1 11 Fatal Error 2 Firmware Defect 0 Fatal Error 2 - Brownout Firmware Defect 1 1 Fatal Error 3 Firmware Defect 1 1 1 3 Fatal Error 3 - FWDL Error Firmware Defect 0 Fatal Error 3 - Zigbee DF Read Error Firmware Defect 1 2 3 6 Fatal Error 4 Firmware Defect 0 Fatal Error 4 - Baud Rate Firmware Defect 1 1 Fatal Error 4 - Blurt Misalignment Firmware Defect 11 97 3 1 8 45 165 Fatal Error 4 - UART Over Flow Firmware Defect 43 105 85 39 139 411 Fatal Error 5 Firmware Defect 3 2 1 1 7 Fatal Error 5 - EPF Page R/W Fail Firmware Defect 1 1 2 Fatal Error 7 Firmware Defect 1 1 Fatal Error 7 - Apptimer Overflow Firmware Defect 1 1 1 3 Fatal Error 7 - Blurt Misalignment Firmware Defect 2 2 Fatal Error 7 - Checkstacks Firmware Defect 8 13 3 11 2 37 Fatal Error 7 - Extended Interval Data Firmware Defect 1 2 2 2 1 8 Fatal Error 7 - FW Nested Interrupts Firmware Defect 2 2 Fatal Error 7 - Insert Alarm Error Firmware Defect 1 4 5 Fatal Error 7 - Invalid Blurt Firmware Defect 5 7 4 1 17 Fatal Error 7 RAM bit flip Firmware Defect 2 4 1 7 Fatal Error 7 - RTC Backward Issue Firmware Defect 1 1 Fatal Error 7 - WDT/Powerup_RTC Firmware Defect 2 5 1 2 2 12 Fatal Error No Core Dump Found Firmware Defect 1 18 3 4 26 FW error Firmware Defect 1 3 3 5 12 FW Error - RFLAN Firmware Defect 7 7 Invalid Core Dump Firmware Defect 0 Pre Hydrogen Unknown Coredump Firmware Defect 0 Time Drift Firmware Defect 1 1 Unable to Test Due to Unknown Password Firmware Defect 1 1 2 Base assembly defects Hardware Defect 0 Board Assembly Defects Hardware Defect 1 1 Board to Board Connector not seated Hardware Defect 25 66 20 17 28 156 Broken Plastic Parts Hardware Defect 1 1 Component Outside Specifications Hardware Defect 150 351 48 83 73 705 Corrosion Hardware Defect 0 Damaged component Hardware Defect 2 3 5 Display Assembly/Holder Hardware Defect 1 1 Display Stuck On ITRON - Pre-SR 3.7 Hardware Defect 0 Memory Corruption due to Bit Flip Hardware Defect 1 1 MFG Process Error Hardware Defect 2 3 2 4 11 MFG Process Error (Off) Hardware Defect 1 1 Missing Plastic Post Hardware Defect 0 Switch/Button Failure Hardware Defect 1 1 Wrong name plate Hardware Defect 0 Wrong/Incorrect Name Plate Hardware Defect 1 1 Not Available Miscellaneous 1 1 Not Tested Miscellaneous 1 1 Root Cause could not be Determined Miscellaneous 9 25 7 6 2 49 Pending Further Evaluation Pending Further Evaluation 125 180 65 4 47 106 527 Grand Total 3969
Page: 4 of 48 Number of electric AMI meter failures (Poly Phase Breakdown) Poly Phase Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17 Feb-17 Mar-17 Grand Known Failure Grouped Failure Category Total Handling Environmental Issue 0 Water Residues/Corrosion Environmental Issue 1 1 Core Dump not complete Firmware Defect 1 1 2 Error 2 Firmware Defect 3 2 5 Error 4 Firmware Defect 1 1 Error 6 Firmware Defect 1 1 Error Code Firmware Defect 1 1 Failed Core Gap Inspection Firmware Defect 4 1 5 Fatal 2 - Maxima Bad Saved RAM Firmware Defect 4 4 Fatal 5 - Maxima BAT Over Current Firmware Defect 4 2 1 7 Fatal 5 - Maxima EPF not Detected Firmware Defect 7 2 9 Fatal 5 - Maxima IPM1 Reset Firmware Defect 2 1 3 Fatal 5 - MaximaBadEPFData Firmware Defect 1 1 Fatal 7 - Maxima Fault Firmware Defect 3 2 5 Fatal Error 3 Firmware Defect 1 1 Fatal Error 3 - FWDL Error Firmware Defect 0 Fatal Error 4 Firmware Defect 0 Fatal Error 5 Firmware Defect 0 Fatal Error 7 - Extended Interval Data Firmware Defect 4 1 1 6 Fatal Error 7 - FW Nested Interrupts Firmware Defect 2 2 Fatal Error 7 - WDT/Powerup_RTC Firmware Defect 1 1 Base assembly defects Hardware Defect 0 Board to Board Connector not seated Hardware Defect 17 3 20 Component Outside Specifications Hardware Defect 11 5 6 22 Damaged component Hardware Defect 0 MFG Process Error Hardware Defect 1 1 Outside published Calibration Limits Hardware Defect 1 1 Pending Further Evaluation Pending Further Evaluation 7 1 2 10 Grand Total 109
Page: 5 of 48 Number of electric AMI meter failures (Cell Relay Breakdown) Cell Relay Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17 Feb-17 Mar-17 Grand Known Failure Grouped Failure Category Total Sustained Overvoltage Environmental Issue 1 1 Fatal Error 2 - Brownout Firmware Defect 1 1 2 Fatal Error 2 - ChecksumsEE Firmware Defect 0 Fatal Error 2 - SPIRESRAMSRAM Firmware Defect 0 Fatal Error No Core Dump Found Firmware Defect 0 FW error Firmware Defect 1 1 Blown MOV Hardware Defect 4 1 3 8 Component Outside Specifications Hardware Defect 21 4 16 5 3 49 Damaged component Hardware Defect 1 1 MFG Process Error Hardware Defect 0 Root Cause could not be Determined Miscellaneous 2 2 Salvage Salvage Grand Total 64
Number of electric AMI meter failures (Salvage Breakdown) Case No.: U-18255 Page: 6 of 48 2016 Salvaged Meter Type Code Hardware Failure Firmware Failure Environment Total Count Single Phase FM-2S,HW 2.0 353 120 179 652 Single Phase FM-12S,HW 2.0 4 2 4 10 Single Phase FM-1S,HW 2.0 5 0 3 8 Single Phase FM-2S,HW 2.0 13 3 9 25 Single Phase FM-2S,HW 3.1 1 0 0 1 Single Phase FM-1S,HW 3.0 12 3 1 16 Single Phase FM-2S,HW 3.0 1218 493 673 2384 Single Phase FM-12S,HW 3.0 12 1 5 18 Single Phase FM-2S, Cell Relay HW 2.0 0 3 2 5 Three Phase FM-45S,HW 2.0 7 3 5 15 Three Phase FM-9S,HW 2.0 4 2 1 7 Three Phase FM-16S,HW 2.0 12 1 14 27 Three Phase FM-16S,HW 3.0 22 4 12 38 Three Phase FM-9S,HW 3.0 22 5 9 36 Three Phase FM-45S,HW 3.0 1 1 1 3 Single Phase Total 1618 625 876 3119 Three Phase Total 68 16 42 126 Overall Total 1686 641 918 3245 2017 Jan - May Salvaged Meter Type Code Hardware Failure Firmware Failure Environment Total Count Single Phase FM-1S,HW 2.0 0 1 2 3 Single Phase FM-1S,HW 3.0 3 1 0 4 Single Phase FM-2S,HW 2.0 30 5 15 50 Single Phase FM-2S,HW 3.0 193 44 107 344 Single Phase FM-2S,HW 3.1 0 0 5 5 Single Phase FM-12S,HW 3.0 2 0 0 2 Three Phase FM-9S,HW 3.0 2 0 0 2 Three Phase FM-16S,HW 2.0 1 0 0 1 Three Phase FM-16S,HW 3.0 6 2 1 9 Three Phase FM-45S,HW 3.0 1 0 0 1 Single Phase Total 228 51 129 408 Three Phase Total 10 2 1 13 Overall Total 238 53 130 421
Page: 7 of 48 Q2. Number of gas AMI module failures A. The total number of gas AMI module failures between 2008 and March 31, 2017 is 36. For the purposes of this Smart Grid Annual Report, in Southeast Michigan (SEMI), we have defined defective as modules that are found installed at a customer site and are not responding (i.e. they are not providing reads and will not wake up when swiped with a magnet).
Page: 8 of 48 Q3. Number of AMR module failures A. Currently the number of AMR module failures is not tracked. For future reports, the Company will undertake efforts to define a method in which this metric could be determined.
Page: 9 of 48 Q4. Electric AMI meter read rate A. See table below which identifies the Electric AMI meter read rate from January 1, 2016 through March 31, 2017. 2016 Electric 2017 Electric Jan 99.03% Jan 98.99% Feb 99.36% Feb 99.06% Mar 99.38% Mar 99.01% Apr 99.45% May 99.34% Jun 99.15% Jul 98.82% Aug 98.71% Sept 98.95% Oct 99.15% Nov 99.37% Dec 99.29% 2016 Total 99.17%
Page: 10 of 48 Q5. Gas AMI meter read rate A. See table below which identifies the Gas AMI meter read rate from January 1, 2016 through March 31, 2017. 2016 Gas 2017 Gas Jan 98.51% Jan 99.15% Feb 98.95% Feb 99.23% Mar 98.95% Mar 99.20% Apr 99.08% May 98.95% Jun 98.96% Jul 99.03% Aug 98.88% Sept 98.90% Oct 98.91% Nov 99.02% Dec 99.04% 2016 Total 98.94%
Page: 11 of 48 Q6. AMR meter read rate A. See table below which identifies the AMR meter read rate from January 1, 2016 through March 31, 2017. 2016 Gas 2017 Gas Jan 99.33% Jan 99.68% Feb 99.58% Feb 99.60% Mar 99.68% Mar 99.77% Apr 99.64% May 99.65% Jun 99.60% Jul 99.61% Aug 99.63% Sept 99.68% Oct 99.61% Nov 99.75% Dec 99.65% 2016 Total 99.62%
Q7. Number of meters replaced before the end of their useful life A. See table below which identifies number of meters replaced before the end of their useful life from January 1, 2016 through March 31, 2017. Case No.: U-18255 Page: 12 of 48 Code Description 2016 2017 200 No Display 65 10 202 Defective Meter - Open Potential Coil 1 0 205 Damaged Base 895 126 206 Obsolete 340 0 208 Burnt Terminal Blade 423 39 210 Suspected Tampering w/comments. 66 9 211 Meter Damaged by Fire 208 24 212 Struck by Lightning 3 0 213 Burnt Lightning Arrestors 1 0 216 No Glass Cover 7 2 217 Water Soaked 641 96 223 Overheated Terminal Blade/s 20 3 224 Noisy Meter 60 11 226 Worn Blades (No Plating) 15 20 227 Obsolete 0 25 232 Failed Accuracy 2 1 235 Electronic Display Shows Error Message, Can Not Program 4 5 238 Damaged LCD Display Unable to Read 70 6 241 Worn Bearings 0 1 242 Could Not Place in Test Mode 0 5 243 Missing Name Plate 0 2 245 Corrosion 3 0 246 Mtr Not Intact or Loose Parts 48 10 247 Blade(s) Bent 77 9 249 Smashed Meter 14 1 250 Unable to Refurbish Dirty 3 1 251 Cannot Reset Register 2 0 252 Owned by Customer 0 2 777 Scrap Meter by Itron Vendor 241 18 778 Unable to Fix Fatal Error (Credit) 36 0 Total Sum 3,245 426
Page: 13 of 48 Q8. Percentage of theft reduced due to AMI meters A. DTE Electric and DTE Gas track energy theft occurring in its service territory by number of sites and dollar value. The companies do not specifically track the change in theft resulting from AMI. Changes in levels of theft occurring from time to time is a result of many factors, including the economy, law enforcement engagement, etc. In general, the reduction in theft incidences in 2016 compared to previous years is a result of increase in identifying fraud and name switching quicker than in previous years. The installation of AMI meters gave DTE Energy a fresh start on methods for identifying theft. New AMI meter installations enabled validation of each meter at every single location. AMI technology enables the companies to reduce the timeframe to identify possible theft from months to days. In the near term, the Company is working to leverage the AMI device events combined with meter readings, billing events, and service orders available pertaining to theft and utilize this data to identify theft even more. See below for the table that depicts DTE Energy s theft billing dollars and sites for the last 4 years. Description 2013 2014 2015 2016 Gas - Theft Sites Billed 5,713 4,196 4,094 2,599 Gas - Theft $ Billed $8,618,299 $6,486,815 $4,464,989 $1,972,972 Electric - Theft Sites Billed 2,008 1,850 1,943 1,891 Electric - Theft $ Billed $1,366,554 $1,236,123 $1,243,487 $933,000
Page: 14 of 48 Q9. Number of theft incidences identified through AMI A. In 2016, 3,557 AMI theft incidents were identified through meter events and billing data combined after non-pay disconnect. There were 1,293 possible theft occurrences reported by the Contractor during the installation process from October 2013 to January 2017. The theft occurrences identified during installation are separate from the 3,557 theft incidents identified after non-pay disconnect.
Page: 15 of 48 Q10. Number of OSHA recordable injuries reduced A. Given that DTE Gas and DTE Electric have reduced the number of meter readers as a result of both AMI and AMR, the OSHA rates have likewise decreased. See below the 2016 and 2017 (year to date through March) OSHA rates related to injuries for both contract and DTE Energy meter readers. Meter Reading OSHA Rate Union Contractors 2016 Injuries 0 1.67 YTD March 2017 Injuries 0 0
Page: 16 of 48 Q11. Number of customers requesting to opt out of AMI A. As of March 31, 2017 a total of 8,885 customers have requested to opt out of a transmitting meter since the opt out program was approved in May, 2013.
Page: 17 of 48 Q12. Number of customers actually opting out of AMI A. As of March 31, 2017, the number of customers that currently opted out of AMI is 7,466.
Page: 18 of 48 Q13. Number of customers requesting to opt out of AMR A. There is no AMR Gas Opt Out Program.
Page: 19 of 48 Q14. Number of customers actually opting out of AMR A. Zero. There is no AMR Gas Opt Out Program.
Q15. Number of customers enrolled in dynamic peak pricing (DPP)/time varying rates (TVR) A. Rate D1.8 is DTE Electric s dynamic peak pricing rate. See table below which identifies the customer counts by month. Case No.: U-18255 Page: 20 of 48 Customer 2016 Counts Jan 1,497 Feb 1,502 Mar 1,504 Apr 1,505 May 1,508 Jun 1,500 Jul 1,491 Aug 1,483 Sep 1,483 Oct 1,479 Nov 1,475 Dec 1,472 Customer 2017 Counts Jan 1,472 Feb 1,474 Mar 1,466
Page: 21 of 48 Q16. Estimated load reductions enabled by DPP and TVR A. The table below includes estimated load reductions for the four-hour period on event days occurring in 2016. Estimated Event Date Load Reduction DPP Event 1 7/7/2016 1.60 MWh DPP Event 2 7/22/2016 2.61 MWh DPP Event 3 7/27/2016 2.92 MWh DPP Event 4 8/4/2016 4.31 MWh DPP Event 5 8/5/2016 2.69 MWh DPP Event 6 8/10/2016 4.17 MWh DPP Event 7 8/11/2016 4.03 MWh DPP Event 8 8/19/2016 3.95 MWh
Page: 22 of 48 Q17. Frequency and dates of DPP events called A. The table below includes the list of DPP event dates in 2016. Event Date DPP Event 1 7/7/2016 DPP Event 2 7/22/2016 DPP Event 3 7/27/2016 DPP Event 4 8/4/2016 DPP Event 5 8/5/2016 DPP Event 6 8/10/2016 DPP Event 7 8/11/2016 DPP Event 8 8/19/2016
Q18. Average load reduction per customer during each DPP, and TVR events A. The table below includes the average load reduction per customer during each DPP, and TVR events. Case No.: U-18255 Page: 23 of 48 Event Date Average Load Reduction DPP Event 1 7/7/2016 1.071 kwh DPP Event 2 7/22/2016 1.753 kwh DPP Event 3 7/27/2016 1.961 kwh DPP Event 4 8/4/2016 2.903 kwh DPP Event 5 8/5/2016 1.813 kwh DPP Event 6 8/10/2016 2.812 kwh DPP Event 7 8/11/2016 2.717 kwh DPP Event 8 8/19/2016 2.663 kwh
Q19. Actual load reductions per event due to DPP and TVR events A. The table below includes the actual load reduction per event due to DPP and TVR events. Case No.: U-18255 Page: 24 of 48 Event Date Actual Load Reduction DPP Event 1 7/7/2016 1.60 MWh DPP Event 2 7/22/2016 2.61 MWh DPP Event 3 7/27/2016 2.92 MWh DPP Event 4 8/4/2016 4.31 MWh DPP Event 5 8/5/2016 2.69 MWh DPP Event 6 8/10/2016 4.17 MWh DPP Event 7 8/11/2016 4.03 MWh DPP Event 8 8/19/216 3.95 MWh
Q20. Number of customers enrolled in interruptible load programs A. The table below includes the number of customers enrolled in interruptible load programs during 2016 and 2017 (year to date through March). Case No.: U-18255 Page: 25 of 48 D1.1 - Res D1.1 - Com D5 - Res D5 - Com D3.3 D8 R1.1 R1.2 R10 Jan-16 276,524 903 53,232 908 125 160 18 196 58 Feb-16 276,207 904 53,149 908 126 159 18 195 58 Mar-16 275,889 903 53,039 908 126 158 18 193 58 Apr-16 276,481 903 52,772 892 125 158 17 196 58 May-16 276,597 907 52,481 880 125 161 17 198 58 Jun-16 276,662 908 52,413 883 125 162 17 198 58 Jul-16 276,740 907 52,322 878 125 156 17 198 58 Aug-16 276,816 903 52,233 875 123 154 17 197 57 Sep-16 276,957 906 52,194 871 123 154 17 197 57 Oct-16 276,855 907 52,097 857 123 153 17 196 57 Nov-16 276,737 904 52,054 854 123 154 17 197 57 Dec-16 276,715 909 51,966 852 121 155 17 197 57 Jan-17 276,644 910 51,912 849 120 156 17 197 57 Feb-17 276,575 908 51,776 843 119 156 17 197 57 Mar-17 276,816 909 51,826 832 119 155 17 196 57
Page: 26 of 48 Q21. Estimated peak reductions due to interruptible load programs A. The table below includes the estimated peak reductions due to interruptible load programs during 2016 through March 31, 2017. D1.1 D5 D3.3 D8 R1.1 R1.2 R10 Jan-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Feb-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Mar-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Apr-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW May-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Jun-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Jul-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Aug-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Sep-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Oct-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Nov-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Dec-16 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Jan-17 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Feb-17 142 MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Mar-17 98 MW 5 MW 23 MW 91 MW 7 MW 75 MW 273 MW
Q22. Actual peak reductions due to interruptible load programs Case No.: U-18255 Page: 27 of 48 A. In 2016, DTE Electric had one event associated with rate schedule Rate D1.1 (interruptible air). The peak value during the August 11, 2016 event was 61 MW.
Q23. Frequency, dates, and weather data of interruptible load programs events called A. From January 1, 2016 through March 31, 2017, there has been one interruptible load program event called. See table below which reflects the peak temperature value during the event. Case No.: U-18255 Page: 28 of 48 8/11/2016 Day High Temp 94 Day Low Temp 76 Day Avg Temp 84 Avg Temp During Interruption 94
Q24. Average load reduction per customer during each interruptible load events A. From January 1, 2016 through March 31, 2017, there has been one interruptible load program event called on August 11, 2016. The average load reduction during this event reflects the sum of the three hours that covered that event and it is 0.527 kwh. Case No.: U-18255 Page: 29 of 48
Page: 30 of 48 Q25. Number of AMI net metering customers A. The number of AMI net metering customers as of March 31, 2017 is 1,497.
Q26. Number of customers enrolled in pay as you go programs A. The number of customers enrolled in pay as you go programs at DTE Gas and DTE Electric is zero as currently the Company does not have a Pay as You Go program. Case No.: U-18255 Page: 31 of 48
Q27. Amount of arrearages reduced as a result of pay as you go programs A. The amount of arrearages reduced is zero as DTE Energy currently does not have a Pay as You Go program. Case No.: U-18255 Page: 32 of 48
Q28. Percentage of distribution lines using sensing information to perform volt var controls A. Zero percentage of distribution lines use sensing information to perform volt var controls. Case No.: U-18255 Page: 33 of 48
Q29. Percentage of distribution lines that are monitored (DSCADA) A. 30% of system has SCADA monitoring in the substation. 38% has low cost non-scada monitoring with limited functionality 18% has monitoring on the circuit only and nothing in the substation Case No.: U-18255 Page: 34 of 48
Q30. Percentage of distribution lines that are automated Case No.: U-18255 Page: 35 of 48 A. The number of devices participating in loop schemes is 225 as of March 31, 2017.
Page: 36 of 48 Q31. Percentage of capacitor bank controllers installed A. The percentage of capacitor bank controllers installed is less than 1% with SCADA controls.
Page: 37 of 48 Q32. Percentage of circuits capable of automatic looping A. As per Staff s exhibit S-10 (Case No. U-18014), the question asks to provide the percentage of substations capable of automatic looping. However, per further conversations with Staff, it was agreed upon for the Company to include the percentage of circuits information. The percentage of circuits with loop schemes is 4.1%.
Q33. Customers Experiencing Long Interruption Duration (CELIDx) A. The table below includes the customers experiencing long interruption duration (CELIDx) during 2016 and 2017 (year to date March 31, 2017). Case No.: U-18255 Page: 38 of 48 CELIDx (# of Customers Experiencing Longest Interruption Duration) CELID < 8hrs CELID > 8hrs CELID < 16hrs CELID > 16hrs 2016 1,890,556 266,912 2,046,079 111,389 2017 to March 31, 2017 2016 to March 31, 2017 315,159 29,428 340,596 3,991 2,205,715 296,340 2,386,675 115,380
Q34. Customers Experiencing Multiple Interruptions X (CEMIx) A. The table below includes the customers experiencing multiple interruptions during 2016 and 2017 (year to date March 31, 2017). Case No.: U-18255 Page: 39 of 48 2016 2017 Till March 31, 2017 2016 to March 31, 2017 #Custs #Custs Mins CEMI4 All Weather (Including Storms) 2,157,468 521,571,547 121,020 BlueSky (No Storms) 1,227,991 168,502,671 All Weather (Including Storms 1,224,409 1,902,934,005 5,134 BlueSky (No Storms) 258,409 30,622,209 All Weather (Including Storms 3,381,877 2,424,505,552 126,154 BlueSky (No Storms) 1,486,400 199,124,880
Page: 40 of 48 Q35. System Average Interruption Duration Index (SAIDI) A. The table below includes the system average interruption duration index during 2016 and 2017 (year to date March 31, 2017). 2016 2017 Till March 31, 2017 2016 to March 31, 2017 #Custs #Custs Mins SAIDI All Weather (Including Storms) 2,157,468 521,571,547 238 BlueSky (No Storms) 1,227,991 168,502,671 77 All Weather 866 (Including Storms 1,224,409 1,902,934,005 BlueSky (No Storms) 258,409 30,622,209 14 All Weather 1,105 (Including Storms 3,381,877 2,424,505,552 BlueSky (No Storms) 1,486,400 199,124,880 91
Q36. System Average Interruption Frequency Index (SAIFI) A. The table below includes the system average interruption frequency index during 2016 and 2017 (year to date March 31, 2017). Case No.: U-18255 Page: 41 of 48 2016 2017 Till March 31, 2017 2016 to March 31, 2017 #Custs #Custs Mins SAIFI All Weather 0.986 (Including Storms) 2,157,468 521,571,547 BlueSky (No Storms) 1,227,991 168,502,671 0.561 All Weather 0.557 (Including Storms 1,224,409 1,902,934,005 BlueSky (No Storms) 258,409 30,622,209 0.12 All Weather 2 (Including Storms 3,381,877 2,424,505,552 BlueSky (No Storms) 1,486,400 199,124,880 0.68
Q37. Outage minutes avoided due to AMI meters Case No.: U-18255 Page: 42 of 48 A. DTE Electric recognizes that AMI enhances the overall outage operation and efficiency, however the Company does not currently track the direct impact of outage minutes avoided due to AMI meters. There are other factors to be considered when determining the outage minutes avoided due to AMI meters including, but not limited to, storm, equipment failure rate, wildlife, public damage, etc. Considering the above and per further conversations with Staff, it was agreed upon for the Company to include the trend for BlueSky Customer Average Interruption Duration Index (CAIDI). The table below includes the 2013 to 2016 BlueSky CAIDI trend. Year BlueSky CAIDI 2013 173 2014 177 2015 146 2016 137
Q38. Number of outage minutes avoided due to automated switches A. Not applicable as DTE Electric does not currently track this data. For future reports, the Company will undertake efforts to define a method in which this metric could be determined. Case No.: U-18255 Page: 43 of 48
Q39. Number of customer outages avoided due to automated switches A. Not applicable as DTE Electric does not currently track this data. For future reports, the Company will undertake efforts to define a method in which this metric could be determined. Case No.: U-18255 Page: 44 of 48
Page: 45 of 48 Q40. Meter reader headcount A. For both service territory areas of Southeast Michigan and Grand Rapids Michigan, DTE Energy has one remaining employee meter reader. DTE Energy maintains contract meter readers. See table below. Union Headcount 2016 Union Headcount 2017 Contractor Monthly Headcount 2016 Contractor Monthly Headcount 2017 Jan 2 2 170 99 Feb 2 2 165 89 Mar 2 2 151 85 Apr 2 1 152 82 May 2 143 Jun 2 146 Jul 2 141 Aug 2 137 Sep 2 128 Oct 2 123 Nov 2 115 Dec 2 134
Page: 46 of 48 Q41. Number of estimated bills by month A. The table below represents the number of estimated bills generated by month. Any bill statement with either an Electric or Gas estimated read is counted as one estimated bill. Month # of Estimated Bills Jan-16 68,366 Feb-16 54,431 Mar-16 51,510 Apr-16 43,805 May-16 41,003 Jun-16 46,514 Jul-16 45,172 Aug-16 54,927 Sep-16 47,717 Oct-16 47,135 Nov-16 68,775 Dec-16 57,167 Jan-17 49,213 Feb-17 41,691 Mar-17 48,607 Total 766,033
Q42. Number of customers that have viewed their data from the web portal, and DTE Insight App A. DTE Insight unique customers who downloaded the app, and viewed their data from January 1, 2016 through March 31, 2017 is 74,421. Case No.: U-18255 Page: 47 of 48 The number of customers that viewed data from the web portal, or the DTE Insight App is not available.
Page: 48 of 48 Q43. Number of customers that have downloaded their data A. Not applicable. The ability for customers to download energy usage is not an option on either the DTE Insight App or through the web portal. In addition, DTE Energy currently does not track the number of customers who call customer service requesting a download of their energy data.