Smart Grid - Annual Report

Transcription

1 STATE OF MICHIGAN Case No.: U 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 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 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 (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 (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 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 ) and Exhibit S-10 (Case No. U-18014).

2 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, Failure Cause Firmware Hardware Environment Misc Pending Salvage Total Invest. OpenWay 2, ,522 7,491 Single Phase OpenWay Poly Phase OpenWay Cell Relay All OpenWay 2, ,666 7,808 The breakdown of AMI meter failures by category is included in the tables below.

3 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 Hot Socket Environmental Issue Sustained Overvoltage Environmental Issue Water Residues/Corrosion Environmental Issue Core Dump not complete Firmware Defect Error 3 Firmware Defect Error 4 Firmware Defect 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 Fatal 2 - Maxima EPF Not Detected Firmware Defect 0 Fatal 5 - Maxima BAT Over Current Firmware Defect Fatal 5 - Maxima EPF not Detected Firmware Defect Fatal 5 - Maxima IPM1 Reset Firmware Defect Fatal 5 - MaximaBadEPFData Firmware Defect Fatal 7 - Bit Flip / Rollover Issue Firmware Defect Fatal 7 - Maxima Fault Firmware Defect Fatal 7 - Zigbee Stack Lock up Firmware Defect 0 Fatal Error 1 Firmware Defect Fatal Error 2 Firmware Defect 0 Fatal Error 2 - Brownout Firmware Defect 1 1 Fatal Error 3 Firmware Defect Fatal Error 3 - FWDL Error Firmware Defect 0 Fatal Error 3 - Zigbee DF Read Error Firmware Defect Fatal Error 4 Firmware Defect 0 Fatal Error 4 - Baud Rate Firmware Defect 1 1 Fatal Error 4 - Blurt Misalignment Firmware Defect Fatal Error 4 - UART Over Flow Firmware Defect Fatal Error 5 Firmware Defect Fatal Error 5 - EPF Page R/W Fail Firmware Defect Fatal Error 7 Firmware Defect 1 1 Fatal Error 7 - Apptimer Overflow Firmware Defect Fatal Error 7 - Blurt Misalignment Firmware Defect 2 2 Fatal Error 7 - Checkstacks Firmware Defect Fatal Error 7 - Extended Interval Data Firmware Defect Fatal Error 7 - FW Nested Interrupts Firmware Defect 2 2 Fatal Error 7 - Insert Alarm Error Firmware Defect Fatal Error 7 - Invalid Blurt Firmware Defect Fatal Error 7 RAM bit flip Firmware Defect Fatal Error 7 - RTC Backward Issue Firmware Defect 1 1 Fatal Error 7 - WDT/Powerup_RTC Firmware Defect Fatal Error No Core Dump Found Firmware Defect FW error Firmware Defect 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 Base assembly defects Hardware Defect 0 Board Assembly Defects Hardware Defect 1 1 Board to Board Connector not seated Hardware Defect Broken Plastic Parts Hardware Defect 1 1 Component Outside Specifications Hardware Defect Corrosion Hardware Defect 0 Damaged component Hardware Defect 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 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 Pending Further Evaluation Pending Further Evaluation Grand Total 3969

4 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 Error 2 Firmware Defect Error 4 Firmware Defect 1 1 Error 6 Firmware Defect 1 1 Error Code Firmware Defect 1 1 Failed Core Gap Inspection Firmware Defect Fatal 2 - Maxima Bad Saved RAM Firmware Defect 4 4 Fatal 5 - Maxima BAT Over Current Firmware Defect Fatal 5 - Maxima EPF not Detected Firmware Defect Fatal 5 - Maxima IPM1 Reset Firmware Defect Fatal 5 - MaximaBadEPFData Firmware Defect 1 1 Fatal 7 - Maxima Fault Firmware Defect 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 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 Component Outside Specifications Hardware Defect 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 Grand Total 109

5 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 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 Component Outside Specifications Hardware Defect 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

6 Number of electric AMI meter failures (Salvage Breakdown) Case No.: U Page: 6 of Salvaged Meter Type Code Hardware Failure Firmware Failure Environment Total Count Single Phase FM-2S,HW Single Phase FM-12S,HW Single Phase FM-1S,HW Single Phase FM-2S,HW Single Phase FM-2S,HW Single Phase FM-1S,HW Single Phase FM-2S,HW Single Phase FM-12S,HW Single Phase FM-2S, Cell Relay HW Three Phase FM-45S,HW Three Phase FM-9S,HW Three Phase FM-16S,HW Three Phase FM-16S,HW Three Phase FM-9S,HW Three Phase FM-45S,HW Single Phase Total Three Phase Total Overall Total Jan - May Salvaged Meter Type Code Hardware Failure Firmware Failure Environment Total Count Single Phase FM-1S,HW Single Phase FM-1S,HW Single Phase FM-2S,HW Single Phase FM-2S,HW Single Phase FM-2S,HW Single Phase FM-12S,HW Three Phase FM-9S,HW Three Phase FM-16S,HW Three Phase FM-16S,HW Three Phase FM-45S,HW Single Phase Total Three Phase Total Overall Total

7 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).

8 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.

9 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, 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%

10 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, 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%

11 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, 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%

12 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, Case No.: U Page: 12 of 48 Code Description No Display Defective Meter - Open Potential Coil Damaged Base Obsolete Burnt Terminal Blade Suspected Tampering w/comments Meter Damaged by Fire Struck by Lightning Burnt Lightning Arrestors No Glass Cover Water Soaked Overheated Terminal Blade/s Noisy Meter Worn Blades (No Plating) Obsolete Failed Accuracy Electronic Display Shows Error Message, Can Not Program Damaged LCD Display Unable to Read Worn Bearings Could Not Place in Test Mode Missing Name Plate Corrosion Mtr Not Intact or Loose Parts Blade(s) Bent Smashed Meter Unable to Refurbish Dirty Cannot Reset Register Owned by Customer Scrap Meter by Itron Vendor Unable to Fix Fatal Error (Credit) 36 0 Total Sum 3,

13 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 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

14 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 The theft occurrences identified during installation are separate from the 3,557 theft incidents identified after non-pay disconnect.

15 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 YTD March 2017 Injuries 0 0

16 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.

17 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.

18 Page: 18 of 48 Q13. Number of customers requesting to opt out of AMR A. There is no AMR Gas Opt Out Program.

19 Page: 19 of 48 Q14. Number of customers actually opting out of AMR A. Zero. There is no AMR Gas Opt Out Program.

20 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 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

21 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 Estimated Event Date Load Reduction DPP Event 1 7/7/ MWh DPP Event 2 7/22/ MWh DPP Event 3 7/27/ MWh DPP Event 4 8/4/ MWh DPP Event 5 8/5/ MWh DPP Event 6 8/10/ MWh DPP Event 7 8/11/ MWh DPP Event 8 8/19/ MWh

22 Page: 22 of 48 Q17. Frequency and dates of DPP events called A. The table below includes the list of DPP event dates in 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

23 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 Page: 23 of 48 Event Date Average Load Reduction DPP Event 1 7/7/ kwh DPP Event 2 7/22/ kwh DPP Event 3 7/27/ kwh DPP Event 4 8/4/ kwh DPP Event 5 8/5/ kwh DPP Event 6 8/10/ kwh DPP Event 7 8/11/ kwh DPP Event 8 8/19/ kwh

24 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 Page: 24 of 48 Event Date Actual Load Reduction DPP Event 1 7/7/ MWh DPP Event 2 7/22/ MWh DPP Event 3 7/27/ MWh DPP Event 4 8/4/ MWh DPP Event 5 8/5/ MWh DPP Event 6 8/10/ MWh DPP Event 7 8/11/ MWh DPP Event 8 8/19/ MWh

25 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 Page: 25 of 48 D1.1 - Res D1.1 - Com D5 - Res D5 - Com D3.3 D8 R1.1 R1.2 R10 Jan , , Feb , , Mar , , Apr , , May , , Jun , , Jul , , Aug , , Sep , , Oct , , Nov , , Dec , , Jan , , Feb , , Mar , ,

26 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, D1.1 D5 D3.3 D8 R1.1 R1.2 R10 Jan MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Feb MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Mar MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Apr MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW May MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Jun MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Jul MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Aug MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Sep MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Oct MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Nov MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Dec MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Jan MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Feb MW 5 MW 18 MW 139 MW 2 MW 81 MW 260 MW Mar MW 5 MW 23 MW 91 MW 7 MW 75 MW 273 MW

27 Q22. Actual peak reductions due to interruptible load programs Case No.: U 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.

28 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 Page: 28 of 48 8/11/2016 Day High Temp 94 Day Low Temp 76 Day Avg Temp 84 Avg Temp During Interruption 94

29 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, The average load reduction during this event reflects the sum of the three hours that covered that event and it is kwh. Case No.: U Page: 29 of 48

30 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.

31 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 Page: 31 of 48

32 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 Page: 32 of 48

33 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 Page: 33 of 48

34 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 Page: 34 of 48

35 Q30. Percentage of distribution lines that are automated Case No.: U Page: 35 of 48 A. The number of devices participating in loop schemes is 225 as of March 31, 2017.

36 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.

37 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%.

38 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 Page: 38 of 48 CELIDx (# of Customers Experiencing Longest Interruption Duration) CELID < 8hrs CELID > 8hrs CELID < 16hrs CELID > 16hrs ,890, ,912 2,046, , to March 31, to March 31, ,159 29, ,596 3,991 2,205, ,340 2,386, ,380

39 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 Page: 39 of Till March 31, to March 31, 2017 #Custs #Custs Mins CEMI4 All Weather (Including Storms) 2,157, ,571, ,020 BlueSky (No Storms) 1,227, ,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, ,154 BlueSky (No Storms) 1,486, ,124,880

40 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) Till March 31, to March 31, 2017 #Custs #Custs Mins SAIDI All Weather (Including Storms) 2,157, ,571, BlueSky (No Storms) 1,227, ,502, All Weather 866 (Including Storms 1,224,409 1,902,934,005 BlueSky (No Storms) 258,409 30,622, All Weather 1,105 (Including Storms 3,381,877 2,424,505,552 BlueSky (No Storms) 1,486, ,124,880 91

41 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 Page: 41 of Till March 31, to March 31, 2017 #Custs #Custs Mins SAIFI All Weather (Including Storms) 2,157, ,571,547 BlueSky (No Storms) 1,227, ,502, All Weather (Including Storms 1,224,409 1,902,934,005 BlueSky (No Storms) 258,409 30,622, All Weather 2 (Including Storms 3,381,877 2,424,505,552 BlueSky (No Storms) 1,486, ,124,

42 Q37. Outage minutes avoided due to AMI meters Case No.: U 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

43 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 Page: 43 of 48

44 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 Page: 44 of 48

45 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 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2 134

46 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

47 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 Page: 47 of 48 The number of customers that viewed data from the web portal, or the DTE Insight App is not available.

48 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.