ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

ANNUAL ELECTRIC TRANSMISSION AVAILABILITY PERFORMANCE REPORT Prepared by PG&E for INDEPENDENT SYSTEM OPERATOR (CAISO) PERFORMANCE YEAR 2019

2019 Electric Transmission Annual Availability Performance Report 1 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

TABLE OF CONTENTS Page

1. Availability Performance and CAISO Maintenance Standards 3

2. Performance Year 2019 4

3. How Control Charts Are Created 8

4. How Control Charts Are Used to Monitor Performance 9

5. Discussion Why Performance May Be Outside Control Chart Limits 10

6. Discussion on Improving Performance 25

7. Control Charts 32

8. Summary Outage Data 39

9. Original Control Charts from CAISO 52

2019 Electric Transmission Annual Availability Performance Report 2 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 1. AVAILABILITY PERFORMANCE AND CAISO MAINTENANCE STANDARDS 2 This annual report to the California Independent System Operator (CAISO or ISO) is prepared in accordance with Appendix C of the Transmission Control 3 Agreement (TCA) between each Participating Transmission Owner (PTO) such as Pacific Gas and Electric Company (PG&E) and CAISO. Section 4.3 of Appendix C 4 (Updated as of January 13, 2013) entitled CAISO TRANSMISSION MAINTENANCE STANDARDS states: 5 “Each PTO shall submit an annual report to the CAISO . . . describing its Availability Measures performance. This annual report shall be based 6 on Forced Outage records. All Forced Outage records shall be submitted by each PTO to the CAISO and shall include the date, start time, end 7 time affected Transmission Facility, and the probable cause(s) if known.” 8 The Availability Measure Targets are defined in Appendix C as “The Availability performance goals established by the ISO”, which are essentially the control 9 chart limits described and shown later in this report. 10 The purpose of the ISO Maintenance Standards is to promote safe, reliable and cost-effective electric transmission service consistent with the requirements of 11 California Assembly Bill 1890. A fundamental precept behind these standards is that the adequacy and effectiveness of a PTO’s maintenance of its electric 12 transmission system can be gauged by monitoring transmission availability performance. This performance is characterized by calculating three measures 13 (indices) related to “forced” outages (see Section 3 of this report for what constitutes a forced outage) on all CAISO-controlled circuits within a voltage class. A 14 majority, but not all, of PG&E transmission circuits have been assigned as being under CAISO control. Two indices measure the relative frequency of outages – 15 Annual Average Forced Outage Frequency (FREQUENCY) and Annual Proportion (PROPORTION) of Circuits with No For ced Outages. A third index measures the 16 duration of those outages – Annual Average Accumulated Forced Outage Duration (DURATION) for those Circuits with Forced Outages. As with all processes or 17 systems, variations in annual performances as defined by these three indices are inherent and expected. Control charts can be helpful in indicating whether 18 variation is due to common (i.e., random) causes, or to special (i.e., assignable) causes, and whether the electric transmission system is in a state of statistical 19 control. If the system is in a state of control, then maintenance practices are presumed to be adequate and effective. However, if a control chart indicates a 20 system is not in statistical control, then special cause(s) is likely and maintenance practices by the PTO may need review. 21 This report presents the control charts as calculated by CAISO using outage data submitted by PG&E and then jointly reconciled for any discrepancies through 22 performance year 2019. The report also shows results of applying 48 tests to the 12 charts (4 tests per chart) to help determine whether annual performance 23 for each of four voltage classes is improving, degrading, or in a state of statistical control.

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1 2. PERFORMANCE YEAR 2019 2 After reconciliation with CAISO and excluding the outages below described under the header “EXCLUDED OUTAGES”, there were 1,179 unplanned forced 3 outages documented in 2019 with an accumulated facility outage duration (capped, see Section 3 below for definition of capped) equal to 555,327 minutes. 4 These 2019 results were more than the corresponding numbers for 2018, i.e., 996 unplanned outages and 482,215 accumulated minutes. 5 There are 905 circuits that were reported as CAISO-controlled for this report. PG&E has approximately 45 more transmission lines defined as “breaker to 6 breaker” that are not considered CAISO-controlled. The PG&E transmission grid also has numerous “tap lines” that are radial extensions of a main transmission 7 line. These tap lines or “taps” typically serve larger customers taking service at a transmission voltage level (i.e., >50,000 volts). If a tap itself has a fault or 8 interruption, then the resulting unplanned outage is credited to the main transmission line. 9 FIGURE 2-1 is a Pareto chart showing the spread of outages over the 905 circuits in 2019. The chart shows 244 transmission lines (27.0%) accounted for 80% of 10 the unplanned forced outages. Additionally, 453 of the 905 circuits (50.1%) had zero unplanned forced outages in 2019. 11 FIGURE 2-2 is a Pareto chart showing the spread of outage durations over the 905 circuits in 2019. It shows that 12.4% of the lines account for 80% of the 12 facility outage minutes. 13 Section 7 of this report has further discussion of performance year 2019, which ended up overall being an excellent year as measured by the control charts. 14 CAPPED OUTAGES: 15 In 2019 there were 37 outages (9 fewer than last year 2018) that exceeded 4,320 minutes in duration and, for the purpose of calculating line availability, had 16 their duration re-set to or capped at 72 hours and classified as “C” as defined on page 6 of the CAISO Maintenance Procedure No. 2 (Outage Data File Format 17 for the ISO). Of these 37 capped outages in 2019, 16 were in the 69kV class, 15 in the 115kV class, 3 in the 230kV class and 3 in the 500kV class. Of the 46 18 capped outages last year 2018, 21 were in the 69kV class, 15 in the 115kV class, 9 in the 230kV class and 1 in the 500kV voltage class. 19 Causes of the capped outages in 2019 included only 1 due to wildfire (), 6 circuit breaker failures, 6 late notifications (further described later in this 20 report), 4-line equipment failures, 6 substation equipment problems (including relays) and 2 tree failures from outside the right-of-way.

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1 2. PERFORMANCE YEAR 2019 (cont’d) 2 FIGURE 2-1

3 4 FIGURE 2-2

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1 2. PERFORMANCE YEAR 2019 (cont’d) 2 EXCLUDED OUTAGES: 3 Section 4.1.3 of Appendix C of the Transmission Control Agreement between PG&E and CAISO – i.e., “outages which are caused by events outside PG&E’s 4 electric transmission system (e.g., caused by another electric utility system encroaching into our grid, by equipment owned by a transmission-served customer 5 or owned and operated by an independent power producer (IPP), or an emergency request from a California agency such as CAL FIRE) or which can be 6 demonstrated to have been caused by earthquakes” – can be considered “excludable” and not included in calculating transmission line availability results. 7 Transmission Maintenance Procedure No. 5 (Classifying Forced Outages) supplements Appendix C by stating in Section 5.3 that “The ISO and PTOs want to 8 encourage the safe operation of the ISO grid; therefore, it is their intention to encourage safe work practices. The concern of reducing the number of Forced 9 Outages should not affect the safety of personnel or the general public.” Section 5.4 of this maintenance procedure supplements Section 5.3 by providing 10 specific examples in its Table-1 “Examples of Outage Classification for Common Events”. Example 9 in this table states the following: “Late notification on 11 Transmission Line Circuit outage request and the request impacts safety” is considered to be “Not a Forced Outage”. 12 Due to the devastating statewide wildfire season in 2017, PG&E developed Public Safety Power Shutoff (PSPS) protocols as an additional precautionary 13 measure to reduce the risk of wildfire ignition by utility equipment failures. Beginning with the 2019 wildfire season, PG&E expanded its PSPS program to 14 include all electric lines that pass through high fire-threat areas – both distribution and transmission. Because PG&E’s electric grid relies on power lines working 15 together to provide service, any of its more than 5 million customers could have power shut off, and power will remain off until weather conditions that 16 precipitated the call for PSPS execution subside and de-energized facilities are patrolled to ensure they can be safely restored. Because of the public safety 17 aspect of PSPS and per sections 5.3 and 5.4 in Maintenance Procedure No. 5, all PSPS events in 2019 (essentially 12 days of outages) were excluded for the 18 purpose of calculating the control charts for transmission line availability. 19 In 2019 there were 402 unplanned forced outages classified as “X”, i.e., excludable. Of those 402 events, 353 (87.8%) were PSPS events, hence a net of 49 20 excludable events that were not PSPS related. Of these 49 events, 24 were recorded in the 69kV class, 17 in the 115kV class, 5 in the 230kV class and 3 in the 21 500kV class. 22 By means of comparing 2019 to 2018, in 2018 there were 66 outages considered excludable. Of the 66 excludable events in 2018, 25 were recorded in the 23 69kV class, 21 in the 115kV class, 18 in the 230kV class and 2 in the 500kV class. None of these 66 excludable events were PSPS related.

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1 2. PERFORMANCE YEAR 2019 (cont’d) 2 LINES WITH ZERO OUTAGES 3 In 2019 there were 453 transmission circuits that had no unplanned outages. As shown in FIGURE 2-1 these 453 circuits account for just over half (50.1%) of 4 the CAISO controlled circuits. Of these 453 circuits, 111 were in the 69kV class, 210 in the 115kV class, 122 in the 230kV class, and 10 in the 500kV class. 5 By comparison, in 2018 there were 489 transmission circuits that had no unplanned outages, and of these 489 circuits, 133 were in the 69kV class, 215 in the 6 115kV class, 132 in the 230kV class, and 9 in the 500kV class. 7 Outage data – either transmission or distribution – is unusual in statistical analyses in that it always begins at zero. Outage duration equal to zero, frequency of 8 outages equal to zero and time between failures equal to zero. Because it begins at zero, all outage data is highly skewed and zero is often the mode (the most 9 frequently occurring value). 10 FIGURE 2-3 is a histogram showing the characteristics of the 2019 unplanned outage data (905 total circuits and 1,179 unplanned forced outages). It shows 11 that not only both the outage mode and median for 2019 were zero, but also 70% of all CAISO-controlled circuits had fewer outages than the average circuit! 12 FIGURE 2-3

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1 3. HOW CONTROL CHARTS ARE CREATED 2 Control charts are a great way to view performance of a process. Such charts account for random variations in processes, especially those with relatively wide 3 tolerances. They illustrate an expected range of performance based on historical data, as well as discrete measures of recent performance stability, 4 improvement or decline. 5 Quality control and improvement are based on assessment of processes. Without methods to quantitatively show how a process is performing, reasonable 6 decisions cannot be made about whether a process is improving, deteriorating, or performing as expected (stable). 7 The process being measured here is the availability of PG&E’s electric transmission (ET) lines – specifically, lines or circuits operating at 60kV & 70kV (combined 8 for this report and reported as “69kV”), 115kV, 230kV and 500kV – that were transferred to CAISO for its operational control. Availability is a measure of time a 9 circuit can provide service, and only unplanned “forced” outages described below are used for calculating line availability. Planned de-energizing of a 10 transmission circuit with approval from the CAISO (i.e., scheduled-approved outage) is not included. What’s especially critical here is the assumption that the 11 adequacy and effectiveness of maintenance by PG&E on its transmission lines is gauged through an availability performance monitoring system using 3 indices: 12 o Index 1: FREQUENCY = Annual average forced outage frequency for all circuits. 13 o Index 2: DURATION = Annual average accumulated forced outage duration for those circuits with forced outages. 14 o Index 3: PROPORTION = Annual proportion of lines with no forced outages. 15 A forced outage occurs whenever there is an unplanned interruption of the flow of electricity in a transmission line between any terminals under ISO 16 operational control and the outage is not a scheduled one, or one caused by events originating outside the PG&E system, or one caused by an earthquake, or 17 one where safety is compromised (e.g., PSPS). There is “screening” applied to any forced outage with a duration exceeding 72 hours – i.e., that outage duration 18 is capped at 4,320 minutes so as not to skew the results related to Index 2 above and potentially compromise meaningful interpretation of Index 2 results. 19 The control charts included in this report are time ordered plots of each index mentioned above for each of four transmission voltage classes within PG&E. The 20 four classes are 69kV (includes circuits operating at either 60kV or 70kV), 115kV, 230kV and 500kV. A total of 12 charts—3 indices per voltage class and 4 21 voltage classes—are created by CAISO using outage data provided by PG&E to characterize how circuits within a class are doing on a yearly basis. Separation by 22 voltage class was deemed an appropriate technique for grouping transmission facilities of similar importance to the electric transmission grid. Adequacy of 23 PG&E’s availability performance is gauged against its own historical performance and not against other participating utilities.

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1 4. HOW CONTROL CHARTS ARE USED TO MONITOR PERFORMANCE 2 After control charts are updated to include 2019 outage data, four tests are visually applied to each chart to detect performance changes: 3 • Test 1: Control Limit Test—does the data point for the current year fall outside the upper control limit or lower control limit of the chart? 4 • Test 2: Center Line Test—do “v1” consecutive annual data points fall above or “v2” consecutive points fall below the centerline of the chart? 5 • Test 3: Warning Limit Test—do at least 2 out of 3 consecutive annual data points including the most recent performance year fall outside the upper or 6 lower warning limits on the same side of the centerline? 7 • Test 4: Trend Test—do six or more values consecutively increase or consecutively decrease? 8 The first test detects any short-term change in the average performance; tests 2 and 4 are looking for longer-term changes. Test 2 will detect a shift up in 9 averages or a shift to a lower level. Values of v1 and v2 for test 2 are determined from TABLE 4-1 below and the Percentile Value “V” output calculated by 10 statistical software MINITAB. Test 4 shows any trend of continuous increase or decrease in the average values. Test 3 assesses changes in performance during 11 an intermediate (i.e., 3-year) period. The four tests allow PG&E to monitor availability performance by kV class. 12 TABLE 4-1 Values of v1 and v2 for Percentiles of the CL in Specified Ranges Percentile v1 v2 35-39 10 5 40 10 6 41-43 9 6 44-46 8 6 47-48 8 7 49-51 7 7 52-53 7 8 54-56 6 8 57-59 6 9 60 6 10 61-65 5 10 13

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS 2 All systems and processes and their outputs exhibit variability. Control charts help monitor variability and can be used to differentiate common causes of 3 variability from special causes. Common – or chance – causes are numerous small causes of variability that are inherent to a system and operate randomly. 4 Special – or assignable – causes can have relatively large effects on the process and may lead to a state that is out of statistical control—i.e., outside control 5 chart limits. The probability that a point falls above the upper control limit (for most control chart designs, usually an indicator of significant process 6 degradation) or below the lower control limit (an indicator, usually, of significant process improvement) if only common causes are operating is approximately 7 0.00135. It is therefore unlikely to have measures fall beyond the control limits when no special cause is operating. False alarms are possible, but the 8 placement of the control limits at 3 standard deviations (+/-) from the process average is thought to control the number of false alarms adequately in most 9 situations. The simplest rule for detecting presence of a special cause is one or more points that fall beyond upper or lower limits of the chart. The chart can be 10 more sensitive and effective in detecting out of control states if other signals and patterns that are unlikely to occur by c hance alone are considered.[1] Tests 2, 11 3 and 4 described in the previous section of this report are examples of such signals or patterns. 12 Examples of special causes of variability in a manufacturing environment include changes in raw materials, differences in relationships among production 13 equipment, materials, and workers, and changes in manufacturing conditions, which for this discussion could be changes in how planned outages are recorded. 14 For electric overhead transmission—especially facilities in the PG&E service territory designed and operated at 60kV and 70kV—severe storms and other 15 natural disasters such as wildfires can be a special cause. A high number of simultaneous outages during such disasters increases restoration times due to 16 limited or restricted access, resource limitations (e.g., priority to restore customers vs. restoring transmission facilities), and personnel safety concerns (e.g., 17 limited winter daylight hours, limited visibility, insufficient rest periods, and slippery or icy roads). 18 As shown in Section 7 of this report, control charts for performance year 2019 did have data points that fell outside control chart limits, but all such results 19 were indicators of performance improvement. In other words, there were no results that reflected negatively on availability performances nor maintenance 20 practices by PG&E. 21 ------22 [1] Levine, Ramsey, Smidt; Applied Statistics for Engineers and Scientists; copyright 2001 by Prentice Hall, Inc., Chapter 6

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 TABLE 5-1 shows the ten largest outage events in 2019 ranked in descending order by the number of customers as reported to the Californ ia Public Utilities 3 Commission (CPUC). This table helps to correlate the significant transmission outages in 2019 that also affected PG&E’s distribution-served customers. 4 TABLE 5-1 5 Largest 10 Customer Outages in 2019 as Reported to CPUC 6 By Number of Distribution-Served Customers Affected, Descending Order Number of Longest Number of Electric ET Facility Outage Distribution-Served Customer Transmission (ET) Minutes IEEE Major Rank Description Date(s) Customers Affected Outage (hrs) Outages (capped as needed) Event? Strong, damaging winds and asssociated critical fire danger resulted in Extreme-Plus fire 10/26/19 - 1 potential and the most widespread implementation of PSPS 10/27/19 1,258,339 312 175 559,176 Yes A strong offshore wind event developed across northern California resulting in critical fire 10/09/19 - 2 potential and the implementation of PSPS 10/10/19 799,312 89 115 234,290 Yes Pair of potent storms impacted the territory beginning with an "atmospheric river" event, which produced gusty winds, heavy rain and significant low snow in Redding, followed by a colder, dynamic storm that resulted in additional periods of rain and gusty south winds along 02/12/19 - 3 with low snow and isolated thunderstorms 02/17/19 587,843 625 89 65,681 Yes Series of winter storms resulted in periods of strong, gusty south winds, heavy rain, 02/02/19 - Yes 4 thunderstorms and low elevation snowfall 02/05/19 378,432 177 42 13,474 (FEB 2, 4, 5) Potent winter storm impacted the territory with strong south southeast winds, isolated 11/25/19 - Yes 5 thunderstorms and heavy rain and mountain snow 11/27/19 346,907 120 44 29,739 (NOV 26, 27) A powerful Pacific storm delivered gusty south winds, heavy rain and mountain snow to the 01/16/19 - 6 territory 01/17/19 338,546 87 34 13,817 Yes Critical fire weather conditions associated with dry, gusty winds led to Extreme-Plus fire 7 potential and the implementation of PSPS 10/23/19 209,215 384 33 189,441* Yes Pair of robust winter storms produced adverse weather in the form of strong, gusty winds, 01/05/19 - Yes 8 heavy rain and mountain snow 01/06/19 197,290 50 29 4,900 (JAN 06) Strong, high pressure produced triple-digit temperatures away from the coast resulting in 08/14/19 - Yes 9 widespread heat-related outage activity 08/16/19 179,699 40 21 1,070 (AUG 15) Breezy to gusty north-northeast winds produced critical fire weather conditions across the 10/29/19 - Yes 7 10 North leading to the implementation of PSPS 10/30/19 171,644 72 58 83,455 (OCT 29) 8 *Note: Geysers 9-Lakeville 230kV (not a CAISO-controlled line) accounted for 126,053 of the minutes on October 23, the day of the Kincade Fire 9 TABLE 5-1 shows that four of the ten events were due to the implementation of the Public Safety Power Shutoff (PSPS) program. As mentioned earlier in 10 Section 2 of this report under the header “Excuded Events”, all outages due to the implementation of PSPS were excluded for the purpose of calculating 11 transmission line availability. Looking forward to the wildfire season in 2020, PG&E is determined to improve PSPS implementation to minimize impact to its

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 customers. Also, if a transmission line needs to be de-energized for safety, PG&E will continue to work closely with the CAISO to assess the impacts to 3 availability. 4 TABLE 5-1 further shows all ten events met the daily duration threshold as defined in the Institute of Electrical and Electronic Engineers (IEEE) standard 1366 to 5 qualify as a “major event day”. A declared major event day (MED) usually – but not always – coincides with extreme weather than can exceed design criteria of 6 utility facilities (e.g., lightning storm, high wind events or localized flooding due to heavy rains) or impose stress on a facility that may have weakened over 7 time. PG&E declared 31 major event days in 2019, which not only far exceeded the 7 declared major event days in 2018, but also was the highest ever 8 recorded in one year. Ironically, despite this record number of declared major event days in 2019, most of the control charts shown in Section 7 of this report 9 show statistically significant availability performance improvement. However, PG&E will continue to balance this apparent improvement with the fact that not 10 only transmission availability, but also customer reliability, was severely compromised with PSPS implementation in 2019. Significant lessons were learned, and 11 there are several planned improvements and initiatives for the 2020 wildfire season that have a goal of keeping customers better informed and restoring 12 service more quickly if and when PSPS is implemented. 13 OCTOBER 23, 2019 – PSPS DAY and KINCADE FIRE: 14 The 7th worst event in TABLE 5-1 was not only a PSPS day, but also the day of the Kincade Fire ignition. Due to dry, gusty winds and “Extreme-Plus” fire 15 potential in the area, PG&E’s officer-in-charge ordered the de-energizing of 25 transmission circuits, primarily in the northern part of the service territory from 16 2:45 p.m. through 4:32 p.m. Of these 25 circuits, 16 were operating at 60kV, 7 at 115kV and 2 at 230kV. All but three lines are CAISO-controlled. 17 Later that evening at 9:19 p.m. the Geysers 9-Lakeville 230kV – not a CAISO-controlled circuit – relayed and did not test due to its automatics being disabled for 18 wildfire risk mitigation. No distribution-served customers were immediately interrupted as a result of this line being unexpectantly out of service. However, 19 Calpine Calistoga Units 1 & 2, Sonoma, Geysers 13, 18, 20, and NCPA Units 1 & 2 did separate from the PG&E grid. A fire (ultimately named the Kincade Fire) 20 was reported by Geysers operator near Geysers units #9 & #10. As of June 2020, the cause of the Kincade Fire remains under investigation by CAL FIRE and the 21 California Public Utilities Commission. PG&E is cooperating with their investigations and continuing to conduct its investigation about the cause of the fire. 22 Moving forward in 2020, PG&E is continually evaluating its protocols and procedures to promote public safety and to address wildfire risk factors, including its 23 PSPS program and related weather and wind modeling.

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 Update: A CAL FIRE news release announcing origin and cause of the Kincade Fire was issued on July 16, 2020. A screen shot of that news release is shown 3 below and was taken directly from CAL FIRE’s web page: https://www.fire.ca.gov/media/11163/kincadefire_2019_cause.pdf

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 HISTORICAL AVERAGE CIRCUIT OUTAGE FREQUENCY / DURATION (ACOF / ACOD): 3 As stated earlier, charts for performance year 2019 had data points that fell outside control chart limits, but all such points were indicative of statistically 4 significant performance improvement. There was no evidence of any degradation of performance, so it follows that maintenance practices by PG&E can be 5 considered adequate and effective. 6 FIGURE 5-1 reinforces this historical performance improvement. It includes all PG&E transmission circuits (not just those under CAISO control). However, it 7 does not include emergency forced outages (EFOs) – i.e., those outages where PG&E manually de-energized a circuit, typically to address an imminent failure 8 discovered in the field and there was insufficient time to garner a scheduled clearance from CAISO. These “EFO” type outages typically account for 9 approximately 20% of all PG&E unplanned outages. The figure below shows that annual actuals for two metrics – i.e., average circuit outage frequency (ACOF) 10 and average circuit outage duration (ACOD) – are trending downward for the thirteen years 2007 through 2019. The metrics shown in the two graphs above 11 include all voltages and all PG&E transmission lines and serve to reinforce and validate the control charts that follow for accumulated outage frequency and 12 duration. 13 FIGURE 5-1 14 PG&E Historical Performances ACOD and ACOF

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 FIRE 2019 vs PRIOR YEARS: 3 In 2019 there were only 2 capped outages (Geysers 9-Lakeville 230kV (not a CAISO-controlled line) and Eagle Rock-Fulton-Silverado 115kV) with an assigned 4 outage cause of FIRE, and both occurred on October 23 as previously discussed. A total of 23 outages were due to FIRE for the year, and the accumulated 5 (capped) duration of these 23 outages was 13,667 minutes. The accumulated (capped) duration of outages in 2018 assigned FIRE as a cause was 100,416 6 minutes, which was very close to the accumulated (capped) duration in 2017 of 104,746 minutes. These two annual durations wer e over three times greater 7 than the 29,543 facility outage minutes recorded in 2016. By further comparison, 2015 – a noted bad year for fires in California – had 51 outages with an 8 accumulated (capped) duration of 109,698 outage minutes. Hence, 2018, 2017 and 2015 were all comparable to one another in terms of capped accumulated 9 outage duration. Performance year 2016 had far fewer facility outage minutes, as did last year 2019. 10 In 2018 there were 14 capped outages due to fire. In 2017 there were 18 capped outages due to fire compared to 4 capped outages in 2016 and 18 in 2015. 11 A total of 81 outages in 2018 (8% of the 995 total outages) were assigned an outage cause of FIRE. In comparison, a total of 94 outages in 2017 (7% of the 12 1,353 total outages for the year) were caused by fire. These 94 outages were almost three times greater than the number recorded for 2016 (33, or 3% of the 13 995 total outages in 2016). 14 TABLE 5-2 that follows is taken from CAL FIRE’s website ( https://www.fire.ca.gov/stats-events/ ) and is a list of the “Top 20 Most Destructive California 15 Wildfires”. Two of the most destructive wildfires in California history occurred in 2018 and four occurred in October 2017. Although very devastating, the 16 Kincade Fire in 2019 did not make this list. In 2016 the most consequential fires affectiing transmission availability were the Clayton Fire in Sonoma County, the 17 near Monterey and the in Santa Cruz. The most consequential fire outages in 2015 were the Rocky Fire and in the northern 18 part of service territory, the in the central area and the Questa Fire and in the southern area. Eight of these fire events are highlighted in 19 yellow below in TABLE 5-2.

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 TABLE 5-2

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 60kV POLE FAILURE AND CATASTROPHIC BREAKER FAILURE AT COTTONWOOD SUBSTATION, 02/13/19: 3 TABLE 5-1 shows that the 3rd ranked event spanned six days, beginning with an “atmospheric river” type storm. One of the more consequential transmission 4 outages during this storm occurred just outside and in Cottonwood substation. Here are the details: 5 02/13/19, 0217 Cottonwood #1 & #2 60kV lines relayed and did not test; due to Cottonwood CB-12 failure Cottonwood 60kV main bus & 6 Cottonwood-Red Bluff 60kV line de-energized; Coleman-Cottonwood, Cottonwood-Benton #1 & #2 60kV lines open-ended at Cottonwood; 7 sustained outages to California Power Holdings, Red Bluff Pump Plant, Rawson, Gerber, Packaging, Red Bank Meter, Louisiana Pacific, Tyler, 8 Red Bluff, Dairyville, Vina & Los Molinos substations; weather storm, ultimately a declared major event day per IEEE Standard 1366; 0449 9 Cottonwood-Red Bluff manually tested OK restoring Red Bluff; 0453 Coleman-Cottonwood tested OK restoring Coleman Hatchery; 0455 10 Coleman-Red Bluff energized restoring Vina, Los Molinos, Dairyville; 0650 Gerber restored; 0457 Cottonwood-Benton #1 tested OK restoring 11 Anderson & Girvan; pole 000/01A on Cottonwood #1 down & tangled with pole 000/02B on Cottonwood #2; 0650 Gerber restored on 12 Coleman-Red Bluff; Protection reports C-G fault on Cottonwood #1; 02/14/19, 0154 & 0236 Cottonwood #2 & #1, respectively, tested NG 13 after crew repaired pole just outside of Cottonwood; no more customers interrupted; found shared tower 001/010 on its side with 14 transmission wire down; 0840 Tyler & LP restored via alternate source; 02/17/19, 1735 & 1806 Cottonwood #2 & #1, respectively, returned 15 to service after installing temporary poles for tower restoring California Power Holdings, Red Bluff Pump Plant, PAC-TIV, Red Bank Meter Stn 16 & LP; tower 001/010 to be rebuilt & lines moved back at later date; Cottonwood CB-12 to be replaced on emergency basis. 17 Hence, multiple facilities and substations were unexpectedly de-energized due to tower failure just outside Cottonwood substation coupled with the 18 coincident failure of a Cottonwood circuit breaker (CB-12). The impact to customers was significant: 26,098 distribution-served customers and several 19 transmission-served customers experienced sustained interruptions that lasted an average of 305 minutes – total customer outage minutes were 7,954,345. 20 Four days later (02/17/19 at 1735 & 1806), Cottonwood #2 & #1, respectively, were returned to service after installing temporary poles. Failed tower 001/010 21 was ultimately rebuilt & lines moved back to normal positions. Cottonwood CB-12 was also replaced on an emergency basis.

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 2018 OUTAGES BY CAUSE CATEGORY: 3 FIGURE 5-2 shows the number of outages (upper stacked bar chart) and accumulated facility outage minutes (capped) by cause category and voltage class. 4 FIGURE 5-2

5

6

2019 Electric Transmission Annual Availability Performance Report 18 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 2018 OUTAGES BY CAUSE CATEGORY: 3 The upper bar chart in FIGURE 5-2 shows the top three cause codes that contributed to 2019 accumulated outage frequency were LEQP (line equipment 4 problems), UNKN (unknown) and LIGT (lightning). OTHR (other) and WEAT (weather, excluding lightning) were slightly lower contributors than lightning. 5 The lower bar chart, which is aligned with the upper chart in each column for cause code, shows that the top three cause code s that contributed to 6 accumulated outage duration were LEQP, VEGA (vegetation) and LATE (late notification). However, if problems within the substation are consolidated (i.e., CB 7 (circuit breaker), SEQP (substation equipment problems) and PROT (protection, typically failed relays), then they would be the second leading causes for 8 duration. 9 These two bar charts include “momentary” type of events where the line relayed and immediately tested OK and service was restored usually within cycles 10 (i.e., fraction of a second). Hence, although the cause code UNKN had a high number of outages, it had very few associated facility outage minutes, which 11 indicates that many of the outages were momentary type of events. PG&E patrols every such outage where an automatic operation occurs, and many of the 12 momentary outages are ones where a subsequent patrol found no cause or no damage to facilities. Every effort is made to find the cause for an outage that is 13 not a momentary event. It’s noteworthy that even though a patrol may suspect a bird (ANIM) was responsible for a momentary event due to elevated bird 14 activity in the area, a cause code of UNKN is assigned unless proof (i.e., a carcass) is found. Although inclement weather may be present, WEAT (weather) is not 15 assigned unless truly inclement weather (e.g., high winds exceeding design criteria or a declared major event day per IEEE standard 1466) is present. 16 Cause code FIRE was the second highest contributor to facility outage minutes last year in 2018; however, FIGURE 5-2 shows it was not a relatively significant 17 cause for either outage frequency or duration in 2019. 18 Historically, line and substation equipment failures including circuit breakers (i.e., LEQP, SEQP and CB) have been significant contributors to both frequency and 19 duration, and 2019 was no different. However, the number and accumulated duration of these outages due to equipment failure was lower than in prior years. 20 Cause code OTHR primarily includes outages due to external contacts such as Mylar balloons or vandalism, high voltage in the area or an encroachment from a 21 customer-owned or independent power producer (IPP) facility. However, if PG&E can confirm the outage was due to the 3 rd party, it will usually declare it as an 22 excludable event for calculating annual availability. 23 Outages due to vehicle contact (VEH) were only 4.2% of frequency and 4.6% of duration; both these figures are down from previous performance years.

2019 Electric Transmission Annual Availability Performance Report 19 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 LIGHTNING: 3 Lightning has historically been a confirmed cause for about 10% of the unplanned forced outages at PG&E. Confirmation of a lightning induced outage is 4 achieved by correlating outage start time with lightning strike time in the PG&E Lightning Detection Network. If PG&E cannot correlate such data than typically 5 lightning is not assigned as the cause even though lightning may have been reported in the area. As shown in FIGURE 5-2, lightning accounted for 10.6% of the 6 outages, but only 2.4% of the associated accumulated duration. In 2018 PG&E recorded only 3.5% of the total outages as lightning caused. In 2017 lightning 7 caused accounted for 5.8% of the total outages. In 2016 PG&E documented 6.4% of the outages as due to lightning. Finally, 2015 was an unusually high year for 8 lightning with 19% attributable to lightning. 9 Overall, lightning continues as a very small contributor to 2019 control charts results for either accumulated outage frequency or duration, for all voltage 10 classes. 11 LATE NOTIFICATION: 12 Of the 1,179 total transmission unplanned forced outages in 2019, FIGURE 5-2 shows 4.1% were due to either insufficient notice to CAISO from PG&E in 13 obtaining a clearance to perform work on the grid or the approved clearance went beyond the pre -approved end time. These LATE outages accounted for 10.8 14 % of the accumulated outage duration total. 15 In 2018, of the total transmission outages reported, 3.4% were assigned “LATE” as the cause. For accumulated outage duration, LATE accounted for 11.0%. 16 There were more such late notification type events in 2017 – i.e., 13% were assigned a late notification cause. The count for late notification outages in 2016 17 was 16% of all the outages. 18 Timeliness of outage requests and communications between PG&E and CAISO for clearances – although showing improvement over the last three years – 19 could still stand further improvement. It’s recommended that this subject be discussed at a future TMCC (Transmission Maintenance Coordination Committee) 20 meeting between PG&E, CAISO and any other PTOs that may have a similar concern.

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 MONTHLY DRIVERS 2019: 3 FIGURE 5-3 is a monthly tracking of average circuit outage frequency (ACOF) and duration (ACOD) during 2019. The graphs show that the four months (January, 4 February, October and November) were drivers for duration and three months (January, February and May) were drivers for frequency. Significant events in 5 these months are highlighted below. 6 FIGURE 5-3

7 8 Each bar graph of FIGURE 5-3 includes a note about “Six Sigma Days”. Six Sigma refers to a robust outage screening methodology applied separately to 9 frequency and duration. Such screening attempts to account for outlier type of events much like the capped outage process for CAISO reporting. For example, 10 if a day had an outage count that exceeding its six-sigma threshold (>35 outages/day), then data related to ACOF would be excluded for that day. Similarly, if a 11 day had outages that totaled more than the six-sigma threshold for accumulated duration (>14,500 minutes/day), that day would be excluded for ACOD.

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1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 Here were the most significant outages ranked in descending order of duration during January 2019 associated with FIGURE 5-3 (note: CESO=customers 3 experiencing a sustained outage and CMIN=customer outage minutes, where applicable; MED=major event day). 4 1) NEWARK-AMES DIST 115kV, sleeve failure, ET wire down in Bay, 3,864 facility outage minutes, no customers affected. 5 2) SMYRNA-SEMITROPIC-MIDWAY 115kV, sagging conductor, 3,176 facility outage minutes; CESO=2,117; CMIN=154,297. 6 3) FORT ROSS-GUALALA 60kV, tree failure, transmission wire down, 2,989 minutes, CESO=385, CMIN=256,835 (declared MED). 7 4) COLGATE-ALLEGHANY 60kV, conductor fail, transmission wire down, 2,789 minutes; CESO=2,050, CMIN=1,185,260 (MED). 8 5) ELK-GUALALA 60kV, insulator & jumper failures, 1,619 minutes, CESO=1,108, CMIN=12,143. 9 6) VASONA-METCALF 230kV, arcing jumper at tower 003/017, 1,617 minutes, no customers affected (MED). 10 7) LAYTONVILLE-WILLITS 60kV, tree failure, transmission wire down, 1,409 minutes, no customers affected. 11 8) BURNS-LONE STAR #1 & #2 60kV, unknown cause, 1,209 minutes each (MED). 12 9) KONOCTI-MIDDLETOWN & FULTON-CALISTOGA 60kV, tree failure from outside right-of-way, 1,346 minutes total, CESO=8,022; CMIN=1,885,345. 13 Here were the most significant outages in February 2019 associated with FIGURE 5-3, again ranked in descending order by facility outage minutes. 14 1) 02/13/19 saw 45 outages – including the event described earlier in this report at Cottonwood – leading to a six-sigma day for ACOF. 15 2) DIABLO-MESA & MORRO BAY-MESA 230kV, 3rd Party Tree, Tower & transmission wire down, 4,948 total facility outage minutes. 16 3) HUMBOLDT-TRINITY 115kV, Tree Failure, 2,766 minutes, no customers affected. 17 4) IGNACIO-BOLINAS #2 60kV, Forced Out for Safety to facilitate repairs to distribution wire down, 2,628 minutes, no customers affected. 18 5) SNEATH LANE-HALF MOON BAY 60kV, Pole Failures, including transmission wire down, 2,496 minutes. 19 6) MIDDLE FORK #1 60kV, Tree Failure, 2,281 minutes. 20 7) FORT BRAGG-ELK 60kV, Tree Failure, transmission wire down, 2,249 minutes. 21 8) POTTER VALLEY-WILLITS 60kV, Tree Failure, transmission wire down, 2,203 minutes. 22 9) EL DORADO-MISSOURI FLAT #2 115kV, Tree Failure, 2,024 minutes. 23 Here were the most significant outages in March 2019, again ranked in descending order by facility outage minutes. 24 1) IGNACIO-BOLINAS 60kV, Tree failure into Olema substation; 14,599 total facility outage mins; 2,077 customers out an average of 18.5 h ours. 25 2) CARNERAS-TAFT 70kV, Wood poles & transmission wire down during high winds; 1,489 facility outage minutes; 155 customers out for 77 minutes. 26 3) CARIBOU #2 60kV, Conductor failure, transmission wire down; 1,221 facility outage minutes. 27 4) EXCHEQUER-YOSEMITE 70kV, gunshot conductor, transmission wire down; 691 facility outage minutes; 3,127 customers out for 52 minutes. 28 5) STANISLAUS-MANTECA #2 115kV, Conductor failure & transmission wire down; 621 facility outage minutes; no customers affected. 29 6) NICOLAUS-WILKINS SLOUGH 60kV, Conductor failure & transmission wire down at multiple locations; 586 minutes; no customers affected.

2019 Electric Transmission Annual Availability Performance Report 22 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 Finally, here were the most significant outages in November 2019, again ranked in descending order by facility outage minutes. 3 1) KASSON-BANTA #1 60kV, De-energized out from scheduled work to replace Ohio Brass insulators at Kasson SW-33, 4,320 capped minutes; no customers affected. 4 2) DIXON LANDING-MCKEE 115kV, McKee CB-152 failed compressor & closing coil, 4,320 minutes capped, momentary 18,300 customers. 5 3) ARCO-TWISSELMAN 70kV, Late Notification to reconductor, 4,320 facility outage minutes capped. 6 4) TESLA-SALADO-MANTECA 115kV, Breaker failure relay for Manteca CB-144 & 154 failed, 4,320 facility outage minutes capped, no customers affected. 7 5) DESABLA-CENTERVILLE 60kV, Replaced burnt poles 1/22A, 1/22B & 1/22C, 4,320 capped minutes, CESO=1,042, CMIN=119,830. 8 6) GEYSERS #3-CLOVERDALE 115kV, De-energized for protection setups, 4,320 facility outage minutes (capped), no customers affected. 9 7) MAPLE CREEK-HOOPA 60kV, Repaired damaged conductors, 4,320 minutes (capped). 10 8) VACA-TESLA 500kV, Work Procedure Error, 4,320 capped minutes, no customers affected. 11 9) DRUM-HIGGINS 115kV, Tree branch removed between 020/164-165, 4,247 facility outage minutes, no customer affected. 12 All these outages listed above in the four months were primary drivers in the availability performance results for 2019. 13 TRANSMISSION WIRE DOWN EVENTS: 14 PG&E has been tracking “wire down” events since 2011 for both electric transmission & distribution (T&D). Electric transmission (ET) wire down events 15 typically account for between 1% and 2% of all T&D wire down events each year. By definition, a wire down event is counted only once even if there are 16 multiple wires down at the same time and due to the same cause. 17 The three main causes of ET wire down each year remain line equipment failures (33 in 2019, identical to 2017), vegetation (tree) failures from outside the 18 right-of-way (17, half that of 2017 but just over three times that in 2018) and external contacts from vehicles, vandalism or other foreign objects (13 in 2019). 19 TABLE 5-3 provides a historical summary of annual ET wire down event counts and cause. In 2019 there were 77 ET wire down events. The number of 2017 20 wire down events for ET was relatively higher than preceding years as well primarily due in part to the higher number of wildfires as well as the relatively larger 21 number of equipment failures and tree-related outages during January and February due to numerous “atmospheric river” type storms. The rain and 22 windstorms in 2018 were fewer in number and less severe. Performance year 2019 also had numerous major event days (31) as shown in previous Table 5-1 23 for the ten worst events in 2019 affecting distribution-served customers.

2019 Electric Transmission Annual Availability Performance Report 23 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 5. DISCUSSION WHY PERFORMANCE MAY BE OUTSIDE CONTROL CHART LIMITS (cont’d) 2 TABLE 5-3 3 Electric Transmission Wire-Down Events Number of ET Wire Down Events Including MEDs

Cause 2011 2012 2013 2014 2015 2016 2017 2018 2019 Lightning 2 0 1 1 1 2 1 0 1 Aircraft 1 1 3 0 0 1 1 3 0 Foreign Obj 2 1 1 2 5 3 3 2 0 WPE 1 1 2 0 1 0 1 0 3 Other 0 4 1 2 3 1 0 2 10 Vandalism 2 3 2 1 1 3 4 2 4 Disaster 2 8 2 3 5 2 10 7 0 Carpole 5 7 3 8 8 5 8 10 9 Vegetation 14 20 4 7 20 11 35 5 17 Equip Fail 39 32 28 18 21 19 33 13 33 4 TOTAL EVENTS 68 77 47 42 65 47 96 44 77

2019 Electric Transmission Annual Availability Performance Report 24 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 6. DISCUSSION ON IMPROVING PERFORMANCE 2 To help specifically address transmission and substation availability performance, daily outage review conference calls continued during 2019. During these 3 calls representatives from various stakeholder departments review transmission line and substation outage events, address issues related to any equipment 4 taken out of service due to it no longer performing as originally designed, identify potential projects or opportunities to improve customer reliability and/or 5 facility availability, and work with other departments represented at the meetings to discuss already planned projects and see if further efforts could be 6 coordinated to consolidate work and improve service reliability. The daily call also addresses specific customers at risk when taking scheduled clearances to 7 perform maintenance and/or construction to help ensure that the clearance request will not unduly put facilities and customer s at risk. 8 Reliability improvement projects primarily target these areas: 9 1. Quicker manual and/or automatic restoration of facilities by installation of SCADA (Supervisory Control and Data Acquisition) enabled switches. 10 2. Reduction in the number of customers affected due to an outage by the installation of breakers and associated relay devices within substations, in 11 effect “sectionalizing” a single relatively longer transmission circuit into two shorter circuits, thereby lowering the number of customers potentially 12 exposed to an outage. 13 3. Improved operational flexibility by installing new equipment that allows facilities to be taken out of service for maintenance or emergency situations 14 and minimize impact to customers. 15 4. Replacement of existing and less reliable bus configurations with breaker-and-a-half or ring bus configurations; 16 5. Targeted relay replacements, including replacement of electromechanical relays with microprocessor-based ones to help with fault location data; such 17 data is crucial to our patrols in better identifying and documenting outage cause. 18 6. Reducing vegetation caused outages by expanding or trimming beyond defined transmission rights-of-way. 19 7. Targeted mitigation on structures inside substations and those supporting transmission lines to help preclude animal contacts. 20 8. Increased attention to line maintenance and more immediate repair of facilities designated by Operations as critical operating equipment. 21 9. Continued updates to and execution of transmission (overhead and underground) and substation Asset Management Plans (AMPs) to increase 22 availability of electric transmission lines, reduce the risk of wildfire ignitions, and improve service to customers.

2019 Electric Transmission Annual Availability Performance Report 25 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 6. DISCUSSION ON IMPROVING PERFORMANCE (cont’d) 2 Many improvements incorporate specific reliability projects as well as maintenance upgrades that double as reliability improvements. Improvements include 3 construction of new transmission lines or line sections, installing additional transformers, installing new and fixing existing supervisory control and data 4 acquisition (SCADA) equipment (most helpful in restoration), and reconfiguration of the grid to provide greater redundancy and improved operational 5 flexibility. Over the many years since 1998 when PG&E joined the CAISO, expenditures in targeted improvements have contributed to the improved results 6 demonstrated by the most recent set of control charts (see Section 7 of this report). 7 As mentioned previously, daily outage review conference calls with the aim of improving the availability performances of both the electric transmission and 8 distribution system and minimizing service restoration times to customers who are in an outage condition continue. These regularly scheduled calls began in 9 mid-2008. These calls also help determine what can be done to preclude re-occurrence and/or reduce restore times as needed for any future outage events. 10 Specifically, for electric transmission, there is a call every workday morning to address outages or any other availability or reliability related issues that 11 occurred the prior day on the grid. In terms of this report and transmission line availability, a significant amount of effort continues to be spent conducting 12 ground and/or air patrols for each outage or path interruption event, even if it may have only been a momentary event (i.e., line relayed and automatically 13 tested OK). Recently, PG&E has mandated that full line patrols are to be performed during the wildfire season for lines that experience an unplanned outage in 14 a designated “Tier 2” (elevated) or “Tier 3” (extreme) fire hazard area as defined by the CPUC Fire Map. Over time these patrols to better identify specific 15 causes of outages should continue to help in better identifying trends (i.e., decrease the number of outages with an “unknown” cause) so that better decisions 16 can be made as to where to channel our reliability improvement efforts. It should also enable focused corrective actions to occur that otherwise may not have 17 if the cause had not been identified and documented. 18 As needed corrective and/or preventative action items are identified and taken, usually documented a “CAP” (corrective action program) Event Report. A web- 19 based database application, this CAP event reporting process has proven to be very effective at PG&E due in part to action items being tracked and monitored 20 electronically and automatically until completed. CAP event reporting continues as an effective tool in reporting and tracking events. It also helps in responding 21 to data requests from intervenors such as the CPUC (California Public Utilities Commission).

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1 6. DISCUSSION ON IMPROVING PERFORMANCE (cont’d) 2 Drought, wildfires and excessive fuel sources such as vegetation pose significant risks to electric transmission (and distribution) availability. Sources of ignition 3 include PG&E electric transmission, distribution and substation facilities and the terrain they traverse. PG&E’s Vegetation Management Program patrols and 4 monitors every PG&E overhead electric transmission and distribution line each year, with some locations patrolled multiple times. These patrols identify not 5 only trees that pose a risk to electric facilities, but also ground vegetation that may need attention. PG&E prunes or removes approximately 1.4 million trees 6 annually. During the daily outage review calls it is not unusual for adjustments to be made by the Vegetation Management team when specific transmission 7 lines are identified as having more vegetation-related outages. 8 Following Governor Brown's January 2014 Drought State of Emergency Proclamation and the California Public Utilities Commission's Resolution ESRB-4, PG&E 9 has added enhanced measures to address areas particularly affected by drought and bark beetles including: 10 1) Increased foot and aerial patrols along power lines in high fire-risk areas; 11 2) Removed approximately 225,000 dead or dying trees in 2016 and 156,000 dead or dying trees in 2017; these tree removals were in addition to 12 approximately 30,000 trees removed per year prior to the drought; 13 3) Launched daily aerial fire detection patrols during high fire season to improve fire spotting and speed of fire response; 14 4) Since 2014, provided $11.4 million to local Fire Safe Councils (FSCs) for fuel reduction projects in communities; and 15 5) Provided $1.7 million to local FSCs for 28 highly programmable remote-sensing cameras for critical fire lookout towers. 16 After the numerous wildfires in 2017, PG&E began bolstering wildfire prevention and emergency response efforts, putting in place new and enhanced safety 17 measures, and doing more over the long term to “harden” or strengthen our electric transmission, substation and distribution systems to help reduce wildfire 18 risks and keep customers safe. PG&E also meets or exceeds regulatory requirements for pole integrity management, using a comprehensive database to 19 manage multiple patrol and inspection schedules of our more than two million electric transmission and distribution poles. Since December 2018, more than 20 700 contract inspection crews have fanned out across PG&E's service area, focusing on transmission assets in areas designated as Tier 2 and Tier 3. In past 21 inspection efforts, crews would primarily look at lines visually by helicopter or from the ground. Under the new enhanced patrols that started in late 2018, 22 crews are visiting all assets on foot to assess their condition near the ground and climbing towers for close-up looks at components. The Company has been 23 using drones to capture images of cross arms, conductors, switches and other critical transmission components.

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1 6. DISCUSSION ON IMPROVING PERFORMANCE (cont’d) 2 The aim is to enlist all available tools to gather data and information safely and as quickly as possible. By the 1st quarter 2019 about 150 contract drone 3 personnel conducted more than 9,000 drone flights as part of the new enhanced patrols, which has been named the Wildfire Safety Inspection Program 4 (WSIP). Pictures captured via drone are sent to a centralized-review team inside PG&E's San Ramon Valley Conference Center, where they're reviewed by 5 experts who look for potential issues on equipment. The goal is to conduct inspections using drones across the same number of structures and miles done by 6 the ground crews. Between ground patrols and aerial imaging, crews have worked to further reduce risk across PG&E's electric-transmission system. For 7 example: 8 • Crews identified and repaired a broken conductor on the 60-kV Colgate-Alleghany line in Sierra County. 9 • Through drone imagery, crews spotted and later repaired a cracked insulator, which connects a line to a tower, on the 60 -kV Drum-Grass Valley- 10 Weimar line in Placer County. 11 • Crews identified and repaired a pole with a split top on the Spring Gap Tap Line in Tuolumne County. 12 In the end, crews will have inspected more than 5,500 miles of transmission power lines and roughly 50,000 structures. 13 The Wildfire Safety Inspection Program is just one element of PG&E's Community Wildfire Safety Program, an ongoing initiative to harden the company's grid 14 and further reduce the risk of wildfire. Accelerated inspection work is also ramping up to assess all distribution assets in Tier 2 and Tier 3 fire-threat areas. 15 Accelerated inspections of PG&E substations also began in 2019. Other measures in the Community Wildfire Safety Program include installing new weather 16 stations to improve weather forecasting and modeling; enhanced vegetation management; and hardening of the system with stronger poles, covered 17 distribution power lines and targeted undergrounding of distribution lines. 18 PG&E outlined these and other efforts in its 2019 Wildfire Safety Plan, filed with the CPUC in February 2019. As part of its plan, the Company recommended 19 installing 400 new weather stations in 2019 — double the number it installed in 2018 — and expanding its Public Safety Power Shutoff (PSPS) program. PG&E 20 filed its updated 2020-Wildfire-Safety-Plan.pdf (2020 WMP) one year later February 7, 2020. The updates to the 2020 WMP have been posted to the PG&E

21 Wildfire Mitigation Plan website PGE.com/2020WMP (WMP Website).

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1 6. DISCUSSION ON IMPROVING PERFORMANCE (cont’d) 2 As of May 16, 2020, specific progress toward meeting our 2020 Community Wildfire Safety Program goals include these milestone s as summarized by CEO and 3 President Andy Vessey: 4 o System hardening: Installed stronger poles, covered lines and targeted undergrounding across 100 miles as part of a full-year plan for hardening 241 5 line-miles. 6 o Enhanced vegetation management: Inspected, pruned and removed vegetation that poses a higher potential for wildfire risk; completed 890 miles out 7 of a 2020 plan of 1,800 total miles. 8 o More weather stations and cameras: Installed 95 advanced weather stations and 27 more high-definition cameras, with a target of 400 and 200 for 9 the year, respectively. 10 o Sectionalizing devices: Separated the distribution grid into smaller sections for operational flexibility; 248 devices out of 592 targeted for the year have 11 been installed. 12 o Transmission line switches: Installed line switches to redirect power and keep communities energized. 27 switches have been installed, exceeding the 13 23 planned to be ready for the 2020 wildfire season. 14 o Substation temporary generation: Created plans to locate temporary generation at up to 48 substations during a Public Safety Power Shutoff event to 15 allow PG&E to safely energize thousands of customers and shrink the footprint of a PSPS event. 16 Several of the milestones above are specific to PG&E distribution facilities. However, many of these facilities are under builds on structures that carry 17 transmission lines. The working theory is that improvements to all aspects of the PG&E “grid” work synergistically with one another to reduce overall wildfire 18 risk, particularly in the higher fire threat districts. PG&E is committed to keeping our customers and the communities we serve safe, reducing the risk of 19 wildfires and making any Public Safety Power Shutoff events smaller, shorter and smarter than last year. The PG&E website ( www.pge.com/wildfiresafety/ ) 20 provides more details.

2019 Electric Transmission Annual Availability Performance Report 29 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 6. DISCUSSION ON IMPROVING PERFORMANCE (cont’d) 2 One final point: PG&E was one of the original participants back in the mid-1990s in the annual electric transmission reliability benchmark study sponsored by 3 SGS Statistical Services. Annual participation in this study complemented and supplemented the results of this annual report to CAISO for years and allowed 4 PG&E to better benchmark its transmission availability and reliability performances to that of other study participants. Unfortunately, the principals behind the 5 SGS study decided to retire in 2018. However, results and deliverables of the last study that includes outage data through 2017 are still used as a basis for 6 making decisions about which specific transmission circuits would best warrant remedial actions to improve reliability and availability. 7 The SGS study was unique in the industry, and from PG&E’s perspective the best study. Unlike any other study we know of it included updated circuit-by-circuit 8 analyses, including a “worst circuit” ranking. TABLE 6-1 shows the most recent partial listing of the worst performing electric transmission circuits in PG&E 9 system. In this table, the lower the “GAP” score, the worse the circuit in terms of its availability performance. This GAP score is derived by coupling a circuit’s 10 most recent 5-year unplanned outage performance (i.e., its availability based on a weighted score with more recent outages given heavier we ighting relative to 11 older outages) with the circuit’s relative importance to the grid, primarily in supporting uninterrupted service to customers. For example, a circuit ranked high 12 in importance with a relatively low availability score would have a low GAP score and be assigned as a worst performer. Such a circuit could be a prime target 13 for capital funding to improve its performance. On the other hand, a circuit with a relatively low importance factor and yet a high availability could be a 14 candidate for reduced maintenance intervals. Over the years this SGS study has been helpful to PG&E in determining where best to spend its money and most 15 likely one reason our performances as shown in section 7 of this report have shown improvement over the years. 16 In early 2020 PG&E received an invitation from SGS to again participate in its annual study. Unfortunately, due in no small part to ongoing bankruptcy 17 proceedings, funding for renewing our participation was unavailable and the decision was made not to resurrect our participation.

2019 Electric Transmission Annual Availability Performance Report 30 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 6. DISCUSSION ON IMPROVING PERFORMANCE (cont’d) 2 TABLE 6-1 3 Worst Performing Circuits – SGS Electric Transmission Benchmark Study (Based on Automatic Type Outages 2013-2017)

4 5

2019 Electric Transmission Annual Availability Performance Report 31 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 7. CONTROL CHARTS 2 FIGURE 7-1, FIGURE 7-2, FIGURE 7-3 and FIGURE 7-4 that follow are reproductions of the control charts for 2019 as calculated by CAISO using outage data 3 provided by PG&E and checked by CAISO with its records. As described earlier in Section 4 of this report, if a test is triggered (i.e., if one can answer in the 4 affirmative to the test question and conclude the test “failed”), it may indicate presence of a “special” cause(s) of variability (rather than a chance or common 5 cause(s) that is inherent to a system or process), and the failure may be indicative of statistically significant performance improvement (FAIL+) or degradation 6 (FAIL-). Conversely, if a test is not triggered (PASS), that generally means there is stable performance and that the electric transmission system is performing as 7 expected relative to its historical performances, and further, that maintenance practices are most likely adequate and effective. 8 Each figure that follows is divided into quadrants. The two upper quadrants and the lower left quadrant show the 3 control charts per class, one for each 9 performance index. The lower right quadrant provides a summary of the four tests applied to each control chart, and whether a specific test passed or failed. 10 Any test failure suggesting degrading performance is shown in red font – there were no such failures in 2019. A test failure indicating improved performance is 11 shown in green font, and there were several such “failures’ in 2019 suggesting statistically significant improvement. 12 • FIGURE 7-1: 69kV Class (322 median number of active CAISO controlled circuits operating at either 60,000 or 70,000 volts) 13 Annual average forced outage FREQUENCY in 2019 (lower is better) ended up at the lower warning limit=2.16. Annual average accumulated forced 14 outage DURATION in 2019 (lower is better) fell between the lower warning limit and the centerline. Annual PROPORTION of circuits with no forced 15 outages index in 2019 (higher is better) ended up between the upper control and warning limits. The lower right quadrant of Figure 7-1 shows 10 of 16 12 tests applied to the three indices in this voltage class passed. The 2 tests that “failed” did so in a way suggesting performance improvement. Hence 17 PG&E’s maintenance practices are considered adequate and effective in the 69kV class. 18 • FIGURE 7-2: 115kV class (349 median number of active CAISO controlled circuits operated at 115,000 volts) 19 Annual average forced outage FREQUENCY in 2019 (lower is better) was significantly below its lower control limit=1.2. Annual average accumulated 20 forced outage DURATION in 2019 (lower is better) ended up slightly below its lower control limit=1,115 minutes. Annual PROPORTION of circuits with 21 no forced outages index in 2019 (higher is better) was significantly above its control chart upper limit=0.486. The lower right quadrant of Figure 7-2 22 shows 3 of 12 tests applied to the 3 indices passed, and the 9 that “failed” suggested overall performance improvement in both accumulated outage 23 frequency and duration in this voltage class. Hence PG&E’s maintenance practices are considered adequate and effective in the 115kV class. 24

2019 Electric Transmission Annual Availability Performance Report 32 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 7. CONTROL CHARTS (cont’d) 2 • FIGURE 7-3: 230kV class (170 median number of active CAISO controlled circuits operated at 230,000 volts) 3 Annual average forced outage FREQUENCY for 2019 (lower is better) ended up significantly below the lower control limit=0.734. Annual average 4 accumulated forced outage DURATION for 2019 (lower is better) fell below the lower control limit=866 minutes. Annual PROPORTION of circuits for 5 2019 (higher is better) ended up significantly above its upper control limit=0.584. The lower right quadrant of Figure 7-3 shows 4 of 12 tests passed 6 and 8 of 12 failed. However, each test that failed indicated statistically significant improvement for all three indices. Hence, PG&E’s maintenance 7 practices are considered adequate and effective for circuits in the 230kV class. 8 • FIGURE 7-4: 500kV class (20 median number of active CAISO controlled circuits operated at 500,000 volts) 9 All 2019 data points fell between upper and lower control chart limits suggesting stable availability performance in this voltage class. Specifically, annual 10 average forced outage FREQUENCY for 2019 (lower is better) fell between the centerline=0.964 and the lower warning limit=0.485. Annual average 11 accumulated forced outage DURATION for 2019 (lower is better) ended up between its centerline=1,751 minutes and its upper warning limit=3,456 12 minutes. Annual PROPORTION of circuits with no forced outages index in 2019 (higher is better) ended up below the centerline=0.490 and above the 13 lower warning limit=0.249. The lower right quadrant of Figure 7-4 shows all 12 tests applied to the 3 indices passed, which means that PG&E’s 14 maintenance practices are considered adequate and effective for circuits in the 500kV class. 15 Data points for annual actual in the control charts that follow are shown in TABLE 7-1.

2019 Electric Transmission Annual Availability Performance Report 33 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 7. CONTROL CHARTS (cont’d) 2 TABLE 7-1 3 Historical Actuals (Data Points) for Control Charts 69kV 115kV 230kV 500kV Proportion Mean Outage Mean Outage Proportion Mean Outage Mean Outage Proportion Mean Outage Mean Outage Proportion Mean Outage Mean Outage Year No Outages Duration Frequency No Outages Duration Frequency No Outages Duration Frequency No Outages Duration Frequency 2003 0.290 992.8 2.34 0.521 1,073.6 1.21 0.473 826.0 0.98 0.158 1,684.7 2.00 2004 0.287 1,187.6 2.20 0.510 1,143.1 1.21 0.512 1,386.5 0.82 0.500 1,401.5 0.70 2005 0.274 1,311.6 2.40 0.474 1,309.4 1.17 0.633 1,152.7 0.57 0.500 512.5 0.90 2006 0.242 1,718.6 2.84 0.424 1,384.1 1.49 0.465 927.8 0.90 0.500 1,186.0 0.80 2007 0.245 1,494.6 2.39 0.332 1,727.4 1.72 0.305 1,603.9 1.48 0.500 1,587.7 0.75 2008 0.201 2,697.3 3.78 0.231 2,562.8 2.48 0.376 2,443.2 1.55 0.400 3,451.3 1.50 2009 0.248 1,819.4 2.68 0.313 1,778.2 1.66 0.361 1,873.9 1.36 0.400 2,858.5 1.20 2010 0.286 1,619.2 2.62 0.332 1,209.0 1.52 0.520 1,132.5 0.85 0.500 2,221.7 0.70 2011 0.297 1,897.0 2.34 0.454 1,571.1 1.19 0.520 1,446.4 0.91 0.650 1,977.7 0.50 2012 0.375 1,423.2 1.57 0.492 1,630.9 1.09 0.571 1,380.1 0.72 0.500 1,767.1 1.40 2013 0.511 1,042.7 0.95 0.516 1,253.4 0.81 0.570 1,952.0 0.76 0.565 1,895.6 0.78 2014 0.368 531.4 1.47 0.542 497.6 0.83 0.669 428.5 0.49 0.500 1,318.0 1.00 2015 0.267 1,122.3 2.17 0.450 1,182.2 1.25 0.497 1,852.9 0.94 0.571 908.3 0.57 2016 0.326 974.0 1.65 0.540 1,140.9 0.86 0.620 893.7 0.63 0.556 244.5 0.61 2017 0.292 1,446.3 2.48 0.515 1,104.6 1.01 0.649 1,231.6 0.64 0.579 1,338.6 1.21 2018 0.373 1,255.9 1.59 0.553 866.6 0.94 0.674 980.1 0.56 0.444 1,319.3 0.89 4 2019 0.340 1,447.3 2.17 0.566 1,097.5 0.93 0.640 708.4 0.60 0.471 2,222.0 0.88 5

2019 Electric Transmission Annual Availability Performance Report 34 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 7. CONTROL CHARTS (cont’d) 2 FIGURE 7-1: 2019 Control Charts – 69kV Class

AVAILABILITY PERFORMANCE: 69kV CLASS Results of 4 Tests Applied to Each Control Chart Since 2008 FREQUENCY--ANNUAL AVERAGE FORCED OUTAGE FREQUENCY CONTROL CHART Test 1: PASS 2019 performance is within upper & lower control chart limits (UCL & LCL) Test 2: PASS At least 7 consecutive points since 2008 do not fall above the centerline (CL), and at least 7 consecutive points do not fall below the CL (V-Value=0.51) Test 3: PASS 2 of 3 consecutive pts including 2019 don't fall outside UWL/LWL on same side of CL Test 4: PASS >=6 data points since 2008 not consecutively increasing or decreasing DURATION--ANNUAL AVE ACCUMULATED FORCED OUTAGE DURATION CONTROL CHART Test 1: PASS 2019 performance is within upper & lower control chart limits (UCL & LCL) Test 2: FAIL+ 7 consecutive points since 2008 fall below the CL (V-Value=0.51) Test 3: PASS 2 of 3 consecutive pts including 2019 don't fall outside UWL/LWL on same side of CL Test 4: PASS >=6 data points since 2008 not consecutively increasing or decreasing PROPORTION--ANNUAL % OF CIRCUITS WITH NO FORCED OUTAGES CONTROL CHART Test 1: PASS 2019 performance is just below UCL Test 2: PASS At least 7 consecutive points since 2008 do not fall above the CL, and at least 7 consecutive points do not fall below the CL (V-Value=0.50) Test 3: FAIL+ 2 of 3 consecutive pts including 2019 are outside UWL Test 4: PASS >=6 data points since 2008 not consecutively increasing or decreasing

CONCLUSIONS 10 of 12 tests passed; 2 of 12 failed, but each test that failed indicates statistically significant performance improvement. Maintenance remains adequate. 3

2019 Electric Transmission Annual Availability Performance Report 35 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 7. CONTROL CHARTS (cont’d) 2 FIGURE 7-2: 2019 Control Charts – 115kV Class

AVAILABILITY PERFORMANCE: 115kV CLASS Results of 4 Tests Applied to Each Control Chart Since 2008 FREQUENCY -- ANNUAL AVERAGE FORCED OUTAGE FREQUENCY CONTROL CHART Test 1: FAIL+ 2019 performance is below control chart lower control limit (LCL) Test 2: FAIL+ At least 7 consecutive points since 2008 fall below the CL (V-Value=0.51) Test 3: FAIL+ 2 of 3 consecutive pts including 2019 are outside LWL Test 4: PASS >=6 data points since 2008 are not consecutively increasing or decreasing DURATION -- ANNUAL AVE ACCUMULATED FORCED OUTAGE DURATION CONTROL CHART Test 1: FAIL+ 2019 performance is below control chart lower control limit (LCL) Test 2: PASS At least 7 consecutive points since 2008 do not fall above the CL, and at least 8 consecutive points do not fall below the CL (V-Value=0.52) Test 3: FAIL+ 2 of 3 consecutive pts including 2019 are outside LWL Test 4: PASS >=6 data points since 2008 are not consecutively increasing or decreasing PROPORTION -- ANNUAL % OF CIRCUITS WITH NO FORCED OUTAGES CONTROL CHART Test 1: FAIL+ 2019 performance remains above UCL Test 2: FAIL+ At least 7 consecutive pts since 2008 fall above the CL (V-Value=0.50) Test 3: FAIL+ 2 of 3 consecutive pts including 2019 are outside UWL Test 4: FAIL+ >=6 data points since 2008 are consecutively increasing (2009-2014)

CONCLUSION 3 of 12 tests passed; 9 of 12 failed, but each test that failed indicates statistically significant performance improvement. Maintenance remains adequate 3

2019 Electric Transmission Annual Availability Performance Report 36 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 7. CONTROL CHARTS (cont’d) 2 FIGURE 7-3: 2019 Control Charts-230kV Class

AVAILABILITY PERFORMANCE: 230kV CLASS Results of 4 Tests Applied to Each Control Chart Since 2008 FREQUENCY -- ANNUAL AVERAGE FORCED OUTAGE FREQUENCY CONTROL CHART Test 1: FAIL+ 2019 performance remains below LCL Test 2: FAIL+ At least 7 consecutive points since 2008 fall below the CL (V-Value=0.51) Test 3: FAIL+ 2 of 3 consecutive pts including 2019 fall below LWL Test 4: PASS >=6 data points since 2008 are not consecutively increasing or decreasing DURATION -- ANNUAL AVERAGE ACCUMULATED FORCED OUTAGE DURATION CONTROL CHART Test 1: FAIL+ 2019 performance is below LCL Test 2: PASS At least 7 consecutive points since 2008 do not fall above the CL, and at least 7 consecutive points do not fall below the CL (V-Value=0.51) Test 3: FAIL+ 2 of 3 consecutive pts including 2019 fall below LWL Test 4: PASS >=6 data points since 2008 are not consecutively increasing or decreasing PROPORTION -- ANNUAL % OF CIRCUITS WITH NO FORCED OUTAGES CONTROL CHART Test 1: FAIL+ 2019 performance remains above UCL Test 2: FAIL+ At least 7 consecutive points since 2008 fall above the CL (V-Value=0.50) Test 3: FAIL+ 2 of 3 consecutive pts including 2019 fall above UWL Test 4: PASS >=6 data points since 2008 are not consecutively increasing or decreasing

CONCLUSIONS 4 of 12 tests passed; 8 of 12 failed, but each test that failed indicates statistically significant performance improvement. Maintenance remains adequate. 3 4

2019 Electric Transmission Annual Availability Performance Report 37 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 7. CONTROL CHARTS (cont’d) 2 FIGURE 7-4: 2019 Control Charts-500kV Class

AVAILABILITY PERFORMANCE: 500kV CLASS Results of 4 Tests Applied to Each Control Chart Since 2008 FREQUENCY -- ANNUAL AVERAGE FORCED OUTAGE FREQUENCY CONTROL CHART Test 1: PASS 2019 performance is within control chart upper and lower limits Test 2: PASS At least 6 consecutive points since 2008 do not fall above the CL, and at least 8 consecutive points do not fall below the CL (V-Value=0.55) Test 3: PASS 2 of 3 consecutive pts including 2019 don't fall outside UWL/LWL on same side of CL Test 4: PASS >=6 data points since 2008 are not consecutively increasing or decreasing DURATION -- ANNUAL AVERAGE ACCUMULATED FORCED OUTAGE DURATION CONTROL CHART Test 1: PASS 2019 performance is within control chart upper and lower limits Test 2: PASS At least 6 consecutive points since 2008 do not fall above the CL, and at least 8 consecutive points do not fall below the CL (V-Value=0.55) Test 3: PASS 2 of 3 consecutive pts including 2019 don't fall outside UWL/LWL on same side of CL Test 4: PASS >=6 data points since 2008 are not consecutively increasing or decreasing PROPORTION -- ANNUAL % OF CIRCUITS WITH NO FORCED OUTAGES CONTROL CHART Test 1: PASS 2019 performance is within control chart upper and lower limits Test 2: PASS At least 8 consecutive points since 2008 do not fall above the CL, and at least 6 consecutive points do not fall below the CL (V-Value=0.45) Test 3: PASS 2 of 3 consecutive pts including 2019 don't fall outside UWL/LWL on same side of CL Test 4: PASS >=6 data points since 2008 are not consecutively increasing or decreasing CONCLUSIONS 12 of 12 tests passed. Maintenance remains adequate. 3

2019 Electric Transmission Annual Availability Performance Report 38 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA 2 2019 summary outage data for each of the ISO-controlled circuits in each voltage class are shown in the tables below.

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 69 BRIDGEVILLE-GARBERVILLE 13 4734 69 TRINITY-MAPLE CREEK 13 11958 69 ESSEX JCT-ORICK 11 3149 69 DELTA-MOUNTAIN GATE JCT 10 5344 69 HAT CREEK #1-WESTWOOD 10 782 69 KILARC-CEDAR CREEK 10 4266 69 MAPLE CREEK-HOOPA 10 9382 69 BURNS-LONE STAR #1 9 6002 69 COTTONWOOD-BENTON #1 9 2414 69 FORT ROSS-GUALALA 9 4185 69 IGNACIO-BOLINAS #2 9 7174 69 MIDDLE FORK #1 9 7502 69 SNEATH LANE - HALF MOON BAY 9 11719 69 BURNS-LONE STAR #2 8 5164 69 CARIBOU #2 8 6909 69 COLEMAN-RED BLUFF 8 606 69 CORTINA #2 8 1540 69 DEL MONTE-VIEJO 8 3692 69 IGNACIO-ALTO-SAUSALITO #1 8 3775 69 KILARC-DESCHUTES 8 580 69 MONTA VISTA-BURNS 8 5100 69 WEST POINT-VALLEY SPRINGS 8 2400 69 CARIBOU-PLUMAS JCT 7 3620 69 FRENCH MEADOWS-MIDDLE FORK 7 5396 69 GARBERVILLE-LAYTONVILLE 7 2218 69 KESWICK-TRINITY 7 8795 69 SOLEDAD #1 7 2677 69 CASCADE-BENTON-DESCHUTES 6 2328 69 COLGATE-ALLEGHANY 6 9434 69 DIXON-VACA #2 6 4187 69 HAMILTON BRANCH-CHESTER 6 2231 69 MERCED FALLS-EXCHEQUER 6 1321 69 SPAULDING-SUMMIT 6 6 69 TAFT-CUYAMA #1 6 587 69 BORDEN-COPPERMINE 5 1402 69 CLAY-MARTELL 5 2151 69 CORCORAN-ANGIOLA 5 5 3 69 CORCORAN-GUERNSEY 5 5

2019 Electric Transmission Annual Availability Performance Report 39 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 39 69 CORTINA #3 5 527 77 69 COLEMAN-COTTONWOOD 3 410 40 69 CROW CREEK SW STA-NEWMAN 5 1095 78 69 COLUSA JCT #1 3 3 41 69 DRUM-GRASS VALLEY-WEIMAR 5 1365 79 69 CONTRA COSTA-BALFOUR 3 2060 42 69 EXCHEQUER-INDIAN FLAT 5 957 80 69 COPPERMINE-TIVY VALLEY 3 5939 43 69 FORT BRAGG-ELK 5 5166 81 69 COTTONWOOD #2 3 4330 44 69 GOLD HILL #1 5 1486 82 69 COTTONWOOD-BENTON #2 3 727 45 69 IGNACIO-ALTO-SAUSALITO #2 5 4346 83 69 COTTONWOOD-RED BLUFF 3 436 46 69 LAURELES-OTTER 5 3475 84 69 DEL MONTE-FORT ORD #1 3 20 47 69 LAYTONVILLE-WILLITS 5 1880 85 69 DEL MONTE-FORT ORD #2 3 222 48 69 PIT #1-HAT CREEK #2-BURNEY 5 487 86 69 FULTON-HOPLAND 3 671 49 69 RIO DELL JCT-BRIDGEVILLE 5 5368 87 69 HUMBOLDT BAY-RIO DELL JCT 3 1712 50 69 WASCO-FAMOSO 5 875 88 69 KESWICK-CASCADE 3 2349 51 69 WILLOW PASS-CONTRA COSTA 5 5 89 69 KONOCTI - MIDDLETOWN 3 140 52 69 CARIBOU-WESTWOOD 4 788 90 69 LOS BANOS-LIVINGSTON JCT-CANAL 3 685 53 69 CHRISTIE-WILLOW PASS 4 4 91 69 MONTE RIO-FORT ROSS 3 456 54 69 CLEAR LAKE-KONOCTI 4 127 92 69 NEWARK-VALLECITOS 3 188 55 69 CORTINA #4 4 609 93 69 ORO LOMA-MENDOTA 3 8 56 69 DEL MONTE-MONTEREY 4 121 94 69 SALINAS-FIRESTONE #2 3 2858 57 69 ELK-GUALALA 4 1622 95 69 STAGG #1 3 87 58 69 FULTON-CALISTOGA 4 5530 96 69 STOCKTON A-WEBER #2 3 339 59 69 GLENN #1 4 1036 97 69 TEJON-LEBEC 3 2187 60 69 GLENN #2 4 132 98 69 VACA-PLAINFIELD 3 1752 61 69 HUMBOLDT-MAPLE CREEK 4 151 99 69 VALLEY SPRINGS #1 3 303 62 69 IGNACIO-ALTO 4 21 100 69 VOLTA-DESCHUTES 3 805 63 69 IGNACIO-BOLINAS #1 4 1027 101 69 VOLTA-SOUTH 3 273 64 69 MANTECA #1 4 452 102 69 WEIMAR #1 3 866 65 69 MONTA VISTA-LOS ALTOS 4 1166 103 69 WHEELER RIDGE-WEEDPATCH 3 439 66 69 NICOLAUS-WILKINS SLOUGH 4 1705 104 69 ALMENDRA JCT-NICOLAUS 2 730 67 69 ORO LOMA-CANAL #1 4 1315 105 69 ARCO-CARNERAS 2 5 68 69 PHILO JCT-ELK 4 1333 106 69 ARCO-CHOLAME 2 600 69 69 SALADO-NEWMAN #2 4 190 107 69 ARCO-TWISSELMAN 2 4838 70 69 VIEJO-MONTEREY 4 2642 108 69 BAIR-COOLEY LANDING #2 2 12 71 69 WEBER-MORMON JCT 4 450 109 69 CARIBOU-TABLE MOUNTAIN 2 399 72 69 WISHON-COPPERMINE 4 547 110 69 CARNERAS-TAFT 2 1490 73 69 WISHON-SAN JOAQUIN #3 4 917 111 69 CARUTHERS-LEMOORE NAS-CAMDEN 2 2 74 69 ARCO-TULARE LAKE 3 3 112 69 CAYUCOS-CAMBRIA 2 31 75 69 ATASCADERO-CAYUCOS 3 1173 113 69 CENTERVILLE-TABLE MTN-OROVILLE 2 1662 2 76 69 COBURN-OIL FIELDS #2 3 739 114 69 COLEMAN-SOUTH 2 126

2019 Electric Transmission Annual Availability Performance Report 40 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 115 69 COLGATE-CHALLENGE 2 2 153 69 VALLEY SPRINGS #2 2 672 116 69 COLGATE-PALERMO 2 189 154 69 VALLEY SPRINGS-MARTELL #1 2 2 117 69 COLGATE-SMARTVILLE #2 2 9 155 69 WEBER-FRENCH CAMP #2 2 817 118 69 COPUS-OLD RIVER 2 472 156 69 ATASCADERO-SAN LUIS OBISPO 1 26 119 69 CORTINA #1 2 682 157 69 COALINGA #1-COALINGA #2 1 1 120 69 COTTONWOOD #1 2 4321 158 69 COBURN-BASIC ENERGY 1 226 121 69 CRESCENT SW STA-SCHINDLER 2 61 159 69 CONTRA COSTA-PITTSBURG 1 94 122 69 DESABLA-CENTERVILLE 2 5079 160 69 COOLEY LANDING-LOS ALTOS 1 1 123 69 ESSEX JCT-ARCATA-FAIRHAVEN 2 3036 161 69 CRESCENT SW STA-STROUD 1 1 124 69 GATES-COALINGA #2 2 2 162 69 DINUBA-OROSI 1 50 125 69 GUERNSEY-HENRIETTA 2 668 163 69 DIXON-VACA #1 1 1093 126 69 HERDLYN-BALFOUR 2 543 164 69 FAIRHAVEN #1 1 1 127 69 HILLSDALE JCT-HALF MOON BAY 2 1262 165 69 GLENN #3 1 1 128 69 HUMBOLDT BAY-HUMBOLDT #1 2 3522 166 69 GLENN #4 1 415 129 69 KASSON-BANTA #1 2 4463 167 69 GLENN #5 1 522 130 69 KASSON-LOUISE 2 114 168 69 GREEN VALLEY-WATSONVILLE 1 31 131 69 KING CITY-COBURN #2 2 948 169 69 HAT CREEK #1-PIT #1 1 51 132 69 KONOCTI - EAGLE ROCK 2 51 170 69 HELM-CRESCENT SW STA 1 1 133 69 LAS POSITAS-VASCO 2 398 171 69 HELM-KERMAN 1 1 134 69 LIVINGSTON-LIVINGSTON JCT 2 2 172 69 HELM-STROUD 1 1 135 69 MENDOCINO-PHILO JCT-HOPLAND 2 560 173 69 HUMBOLDT #1 1 4 136 69 MENDOTA-SAN JOAQUIN-HELM 2 2 174 69 HUMBOLDT BAY-EUREKA 1 257 137 69 MOUNTAIN GATE JCT-CASCADE 2 3893 175 69 JEFFERSON #1 1 707 138 69 NEWARK-LIVERMORE 2 251 176 69 JEFFERSON-STANFORD 1 2026 139 69 NICOLAUS-PLAINFIELD 2 1001 177 69 KASSON #1 1 413 140 69 PEACHTON-PEASE 2 538 178 69 KASSON-CARBONA 1 58 141 69 POTTER VALLEY-WILLITS 2 2204 179 69 KEARNEY-BOWLES 1 400 142 69 RADUM-VALLECITOS 2 15 180 69 KERN CANYON-MAGUNDEN-WEEDPATCH 1 1 143 69 REEDLEY-OROSI 2 530 181 69 KERN-MAGUNDEN 1 1 144 69 SALADO-CROW CREEK SW STA 2 200 182 69 KING CITY-COBURN #1 1 1031 145 69 SALINAS-LAURELES 2 401 183 69 LAKEVILLE #1 1 249 146 69 SCHINDLER-COALINGA #2 2 1648 184 69 LAKEVILLE-PETALUMA "C" 1 286 147 69 SMARTVILLE-CAMP FAR WEST 2 4720 185 69 LAYTONVILLE-COVELO 1 186 148 69 SOLEDAD #4 2 244 186 69 LOCKEFORD-LODI #2 1 1 149 69 STOCKTON A #1 2 5136 187 69 LOCKEFORD-LODI #3 1 371 150 69 STOCKTON A-WEBER #1 2 339 188 69 LOS BANOS-O'NEILL PGP 1 11 151 69 TAFT-ELK HILLS 2 34 189 69 MANTECA-LOUISE 1 1 2 152 69 TEMPLETON-ATASCADERO 2 265 190 69 MARICOPA-COPUS 1 261

2019 Electric Transmission Annual Availability Performance Report 41 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 191 69 MENDOCINO-WILLITS 1 332 229 69 CHRISTIE-FRANKLIN #1 0 0 192 69 MENDOCINO-WILLITS-FORT BRAGG 1 121 230 69 CHRISTIE-FRANKLIN #2 0 0 193 69 MERCED-MERCED FALLS 1 502 231 69 CLEAR LAKE-HOPLAND 0 0 194 69 MONTA VISTA-LOS GATOS 1 1 232 69 COALINGA #1-SAN MIGUEL 0 0 195 69 MONTE RIO-FULTON 1 592 233 69 COBURN-OIL FIELDS #1 0 0 196 69 NICOLAUS-MARYSVILLE 1 1 234 69 COLGATE PH-COLGATE SW STA 0 0 197 69 PALERMO-OROVILLE #1 1 687 235 69 COLGATE-GRASS VALLEY 0 0 198 69 PASO ROBLES-TEMPLETON 1 251 236 69 COLGATE-SMARTVILLE #1 0 0 199 69 PIT #1-MCARTHUR 1 51 237 69 CONTRA COSTA-DU PONT 0 0 200 69 PLACER-DEL MAR 1 9 238 69 COOLEY LANDING-STANFORD 0 0 201 69 SALINAS-FIRESTONE #1 1 1 239 69 DEL MAR-ATLANTIC #1 0 0 202 69 SALINAS-FORT ORD #1 1 1 240 69 DEL MAR-ATLANTIC #2 0 0 203 69 SAN LUIS OBISPO-CAYUCOS 1 25 241 69 DRUM-SPAULDING 0 0 204 69 SAN MATEO-HILLSDALE JCT 1 1186 242 69 EUREKA-STA "A" 0 0 205 69 SMARTVILLE-NICOLAUS #1 1 593 243 69 EVERGREEN-ALMADEN 0 0 206 69 SNEATH LANE-PACIFICA 1 34 244 69 EVERGREEN-MABURY 0 0 207 69 SOLEDAD #2 1 1 245 69 EXCHEQUER-MARIPOSA 0 0 208 69 STOCKTON "A"-WEBER #3 1 606 246 69 FAIRHAVEN-HUMBOLDT 0 0 209 69 TABLE MTN- PEACHTON 1 1 247 69 FULTON - WINDSOR 0 0 210 69 TULUCAY-NAPA #2 1 1 248 69 FULTON-MOLINO-COTATI 0 0 211 69 VALLEY SPRINGS-CLAY 1 1 249 69 GATES-HURON 0 0 212 69 WATSONVILLE-SALINAS 1 1 250 69 GATES-JAYNE SW STA 0 0 213 69 WEEDPATCH-SAN BERNARD 1 510 251 69 GATES-TULARE LAKE 0 0 214 69 WHEELER RIDGE-TEJON 1 13 252 69 GLASS-BIOLA-MADERA 0 0 215 69 WINDSOR -FITCH MOUNTAIN 1 1838 253 69 HAAS-WOODCHUCK 0 0 216 69 ALMADEN-LOS GATOS 0 0 254 69 HALSEY-PLACER 0 0 217 69 ARCATA-HUMBOLDT 0 0 255 69 HAMMER-COUNTRY CLUB 0 0 218 69 ARCO-POLONIO PASS PP 0 0 256 69 HARTLEY-CLEAR LAKE 0 0 219 69 BAIR-COOLEY LANDING #1 0 0 257 69 HENRIETTA-KENT SW STA 0 0 220 69 BORDEN-GLASS 0 0 258 69 HENRIETTA-LEMOORE 0 0 221 69 BORDEN-GLASS-BIOLA 0 0 259 69 HENRIETTA-LEMOORE NAS 0 0 222 69 BORDEN-MADERA #1 0 0 260 69 HERDLYN-TRACY 0 0 223 69 BORDEN-MADERA #2 0 0 261 69 HUMBOLDT BAY-HUMBOLDT #2 0 0 224 69 BUTTE-CHICO #1 0 0 262 69 HUMBOLDT-EUREKA 0 0 225 69 BUTTE-CHICO #2 0 0 263 69 HURON-GATES- FIVE POINTS SW STA 0 0 226 69 BUTTE-ESQUON 0 0 264 69 JAYNE SW STA-COALINGA #1 0 0 227 69 CALIF AVE-KEARNEY 0 0 265 69 JEFFERSON-HILLSDALE JCT 0 0 2 228 69 CAMDEN-KINGSBURG 0 0 266 69 JEFFERSON-LAS PULGAS 0 0

2019 Electric Transmission Annual Availability Performance Report 42 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 267 69 KEARNEY ALTERNATE TIE 0 0 268 69 KEARNEY TIE 0 0 269 69 KEARNEY-BIOLA 0 0 270 69 KEARNEY-CARUTHERS 0 0 271 69 KEARNEY-KERMAN 0 0 272 69 KENT SW STA-TULARE LAKE 0 0 273 69 KERN-FRUITVALE 0 0 274 69 KERN-KERN OIL-FAMOSO 0 0 275 69 KERN-OLD RIVER #1 0 0 276 69 KERN-OLD RIVER #2 0 0 277 69 KILARC-VOLTA TIE 0 0 278 69 KINGSBURG-LEMOORE 0 0 279 69 LAKEVILLE #2 0 0 280 69 LIVERMORE-LAS POSITAS 0 0 Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 281 69 LOCKEFORD #1 0 0 305 69 SAN MIGUEL-PASO ROBLES 0 0 282 69 LOCKEFORD-INDUSTRIAL 0 0 306 69 SAN RAMON-RADUM 0 0 283 69 LOCKEFORD-LODI #1 0 0 307 69 SCHINDLER-FIVE POINTS SW STA 0 0 284 69 LODI-INDUSTRIAL 0 0 308 69 SEMITROPIC-WASCO 0 0 285 69 LOS BANOS-MERCY SPRINGS SW STA 0 0 309 69 SMARTVILLE-MARYSVILLE 0 0 286 69 LOS BANOS-PACHECO 0 0 310 69 SMARTVILLE-NICOLAUS #2 0 0 287 69 MARTIN - SNEATH LANE 0 0 311 69 SOLEDAD #3 0 0 288 69 MENDOCINO #1 0 0 312 69 STAGG-COUNTRY CLUB #1 0 0 289 69 MENDOCINO-HARTLEY 0 0 290 69 MERCED #1 0 0 313 69 STAGG-COUNTRY CLUB #2 0 0 291 69 MERCY SPRINGS SW STA-CANAL-ORO LOMA 0 0 314 69 STAGG-HAMMER 0 0 292 69 MILLBRAE-SNEATH LANE 0 0 315 69 TAFT-CUYAMA #2 0 0 293 69 NICOLAUS-CATLETT JCT 0 0 316 69 TAFT-MARICOPA 0 0 294 69 PALERMO-OROVILLE #2 0 0 317 69 TIVY VALLEY-REEDLEY 0 0 295 69 PEASE-HARTER 0 0 318 69 TULE-SPRINGVILLE 0 0 296 69 PEASE-MARYSVILLE-HARTER 0 0 319 69 TULUCAY-NAPA #1 0 0 297 69 POTTER VALLEY-MENDOCINO 0 0 320 69 VALLEY SPRINGS-CALAVERAS CEMENT 0 0 298 69 RADUM-LIVERMORE 0 0 321 69 VASCO-HERDLYN 0 0 299 69 REEDLEY-DINUBA #1 0 0 300 69 RIO BRAVO HYDRO 0 0 322 69 WEBER-FRENCH CAMP #1 0 0 301 69 SALINAS-FORT ORD #2 0 0 323 69 WEEDPATCH-WELLFIELD 0 0 302 69 SALINAS-LAGUNITAS 0 0 324 69 WEIMAR-HALSEY 0 0 303 69 SAN BERNARD-TEJON 0 0 325 69 WHEELER RIDGE-LAKEVIEW 0 0 2 304 69 SAN MATEO-BAIR 0 0 326 69 WHEELER RIDGE-SAN BERNARD 0 0

2019 Electric Transmission Annual Availability Performance Report 43 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 115 MIDWAY-TEMBLOR 10 2487 115 BOGUE-RIO OSO 3 3 115 STANISLAUS-MANTECA #2 9 2642 115 DRUM-RIO OSO #2 3 3 115 OLEUM-"G" #2 7 5019 115 IGNACIO-MARE ISLAND #2 3 3 115 EL DORADO-MISSOURI FLAT #1 7 2758 115 RIO OSO-LINCOLN 3 3 115 CHOWCHILLA-KERCKHOFF 6 2703 115 STOCKTON A-LOCKEFORD-BELLOTA #2 2 5694 115 WILSON-LE GRAND 6 1481 115 DRUM-HIGGINS 2 4735 115 MI-WUK-CURTIS 6 1286 115 SISQUOC-SANTA YNEZ SW STA 2 4561 115 MELONES-CURTIS 6 135 115 DRUM-SUMMIT #2 2 4343 115 MELONES-RACETRACK 6 6 115 BRIGHTON-GRAND ISLAND #2 2 4321 115 WILSON-ORO LOMA 5 6479 115 GEYSERS #3-EAGLE ROCK 2 4321 115 GOLD HILL-BELLOTA-LOCKEFORD 5 5374 115 MISSOURI FLAT-GOLD HILL #2 2 3077 115 HUMBOLDT-TRINITY 5 3733 115 RAVENSWOOD-BAIR #2 2 2271 115 PARADISE-TABLE MOUNTAIN 5 2017 115 TRINITY-COTTONWOOD 2 2133 115 DRUM-RIO OSO #1 5 2015 115 VACA-VACAVILLE-JAMESON-NORTH TOWER 2 1719 115 SAN BENITO-HOLLISTER 5 901 115 TABLE MTN-BUTTE #1 2 1217 115 TESLA-SALADO-MANTECA 4 4787 115 MOSS LANDING-DEL MONTE #1 2 1192 115 IGNACIO-SAN RAFAEL #3 4 3148 115 PITTSBURG-KIRKER-COLUMBIA STEEL 2 990 115 STANISLAUS-MELONES SW STA-RIVERBANK JCT SW STA 4 836 115 SONOMA-PUEBLO 2 816 115 BELLOTA-RIVERBANK 4 279 115 NEWARK-NUMMI 2 796 115 CALLENDAR SW STA-MESA 4 185 115 WEST SACRAMENTO-DAVIS 2 684 115 MORGAN HILL-LLAGAS 3 8696 115 LAKEVILLE-SONOMA #2 2 656 115 SMYRNA-SEMITROPIC-MIDWAY 3 7902 115 COOLEY LANDING-PALO ALTO 2 620 115 GEYSERS #3-CLOVERDALE 3 5070 115 A-Y #1 2 591 115 LOWER LAKE-HOMESTAKE 3 4862 115 WEST FRESNO-CALIFORNIA AVE 2 545 115 DIXON LANDING-MCKEE 3 4334 115 PITTSBURG-CLAYTON #4 2 493 115 EAGLE ROCK-FULTON-SILVERADO 3 4322 115 RIPON-MANTECA 2 451 115 EL DORADO-MISSOURI FLAT #2 3 4091 115 CASCADE-COTTONWOOD 2 441 115 STOCKTON "A"-LOCKEFORD-BELLOTA #1 3 1696 115 LERDO-KERN OIL-7TH STANDARD 2 432 115 NEWARK-AMES #3 3 1407 115 KERN-TEVIS-STOCKDALE 2 377 115 BRIDGEVILLE-COTTONWOOD 3 829 115 BRITTON-MONTA VISTA 2 347 115 LIVE OAK-KERN OIL 3 608 115 EAGLE ROCK-CORTINA 2 344 115 PANOCHE-ORO LOMA 3 524 115 SAN MATEO-MARTIN #6 2 306 115 LAWRENCE-MONTA VISTA 3 416 115 MIDWAY-TAFT 2 272 115 HENRIETTA-LEPRINO SW STA 3 382 115 PALERMO-NICOLAUS 2 154 115 MIDWAY-TUPMAN-RIO BRAVO-RENFRO 3 338 115 HERNDON-WOODWARD 2 113 115 OLIVE SW STA-SMYRNA 3 281 115 HERNDON-BULLARD #2 2 92 115 LLAGAS-GILROY FOODS 3 215 115 ATLANTIC-PLEASANT GROVE #2 2 88 115 GREEN VALLEY-LLAGAS 3 214 115 SF AIRPORT-SAN MATEO 2 37 115 NEWARK-AMES #1 3 56 115 SOBRANTE-STANDARD OIL SW STA #2 2 25 2 115 CORCORAN-OLIVE SW STA 3 32 115 CONTRA COSTA #1 2 2

2019 Electric Transmission Annual Availability Performance Report 44 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 115 CRAZY HORSE CANYON SW STA-SALINAS-SOLEDAD #1 2 2 115 STONE-EVERGREEN-METCALF 1 131 115 CRAZY HORSE CANYON SW STA-SALINAS-SOLEDAD #2 2 2 115 CABRILLO-SANTA YNEZ SW STA 1 129 115 EXCHEQUER-LE GRAND 2 2 115 HERNDON-BULLARD #1 1 91 115 FULTON-PUEBLO 2 2 115 MANTECA-VIERRA 1 86 115 MANCHESTER-AIRWAYS-SANGER 2 2 115 RIO OSO-WOODLAND #1 1 53 115 SEMITROPIC-MIDWAY #1 2 2 115 SHAFTER-RIO BRAVO 1 53 115 TEMBLOR-SAN LUIS OBISPO 2 2 115 MIDWAY-RENFRO-TUPMAN 1 43 115 NEWARK-AMES DISTRIBUTION 1 3864 115 TESLA-TRACY 1 24 115 STANISLAUS-MELONES SW STA-MANTECA #1 1 3767 115 OLEUM-"G" #1 1 9 115 SWIFT-METCALF 1 3249 115 OCEANO-CALLENDER SW STA 1 7 115 SAN LUIS OBISPO-OCEANO 1 3081 115 HUMBOLDT-BRIDGEVILLE 1 4 115 UKIAH-HOPLAND-CLOVERDALE 1 3034 115 BARTON-AIRWAYS-SANGER 1 1 115 METCALF-EDENVALE #2 1 2090 115 BRIGHTON-GRAND ISLAND #1 1 1 115 BELLOTA-RIVERBANK-MELONES SW STA 1 1700 115 CALIFORNIA AVE-MCCALL 1 1 115 WOODLEAF-PALERMO 1 1407 115 DIVIDE-CABRILLO #1 1 1 115 OLEUM-MARTINEZ 1 917 115 GREEN VALLEY-PAUL SWEET 1 1 115 KINGS RIVER-SANGER-REEDLEY 1 709 115 HERNDON-MANCHESTER 1 1 115 PIERCY-METCALF 1 679 115 IGNACIO-MARE ISLAND #1 1 1 115 CRAG VIEW-CASCADE 1 664 115 KERCKHOFF-CLOVIS-SANGER #1 1 1 115 PITTSBURG-CLAYTON #1 1 649 115 KERN-TEVIS-STOCKDALE-LAMONT 1 1 115 MARTIN-SF AIRPORT 1 579 115 KINGSBURG-WAUKENA SW STA 1 1 115 PITTSBURG-COLUMBIA STEEL 1 549 115 MARTIN-DALY CITY #2 1 1 115 FULTON-SANTA ROSA #1 1 433 115 MARTIN-EAST GRAND 1 1 115 VACA-SUISUN-JAMESON 1 421 115 MCCALL-REEDLEY 1 1 115 VACA-SUISUN 1 417 115 MCCALL-WEST FRESNO #2 1 1 115 PITTSBURG-CLAYTON #3 1 375 115 MCKEE-PIERCY 1 1 115 EAGLE ROCK-REDBUD 1 363 115 MESA-DIVIDE #2 1 1 115 BRIGHTON-DAVIS 1 353 115 METCALF-EDENVALE #1 1 1 115 CORTINA-MENDOCINO #1 1 349 115 METCALF-GREEN VALLEY 1 1 115 MORAGA-OAKLAND #1 1 346 115 MORAGA-SAN LEANDRO #2 1 1 115 SOBRANTE-G #2 1 329 115 MORRO BAY-SAN LUIS OBISPO #2 1 1 115 MORAGA-SAN LEANDRO #3 1 323 115 MOSS LANDING-DEL MONTE #2 1 1 115 MISSOURI FLAT-GOLD HILL #1 1 309 115 OLEUM-NORTH TOWER-CHRISTIE 1 1 115 GRANT-EASTSHORE #1 1 232 115 PANOCHE-EXCELSIOR SW STA #2 1 1 115 NEWARK-KIFER 1 218 115 PARADISE-BUTTE 1 1 115 DRUM-SUMMIT #1 1 203 115 PEASE-RIO OSO 1 1 115 LAKEVILLE-SONOMA #1 1 191 115 RIO OSO-NICOLAUS 1 1 115 STELLING-WOLFE 1 138 115 RIVERBANK JCT SW STA-RIPON 1 1 115 MARTINEZ-SOBRANTE 1 137 115 SANGER-REEDLEY 1 1 2 115 X-Y #1 1 133 115 SYCAMORE CREEK-NOTRE DAME-TABLE MTN 1 1

2019 Electric Transmission Annual Availability Performance Report 45 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 115 TESLA-SALADO #1 1 1 115 EL PATIO-SAN JOSE "A" 0 0 115 7th STANDARD-KERN 0 0 115 EXCELSIOR SW STA-SCHINDLER #1 0 0 115 ADOBE SW STA-LAMONT 0 0 115 EXCELSIOR SW STA-SCHINDLER #2 0 0 115 A-H-W #1 0 0 115 FELLOWS-MIDSUN 0 0 115 A-H-W #2 0 0 115 FELLOWS-TAFT 0 0 115 AMES DISTRIBUTION-AMES 0 0 115 FMC-SAN JOSE B 0 0 115 A-P #1 0 0 115 FULTON JCT-VACA 0 0 115 APPLIED MATERIALS-BRITTON 0 0 115 FULTON-SANTA ROSA #2 0 0 115 ATLANTIC-PLEASANT GROVE #1 0 0 115 GOLD HILL-CLARKSVILLE 0 0 115 ATWATER-CRESSEY 0 0 115 GRANT-EASTSHORE #2 0 0 115 ATWATER-EL CAPITAN 0 0 115 GREEN VALLEY-CAMP EVERS 0 0 115 ATWATER-MERCED 0 0 115 GWF-KINGSBURG 0 0 115 A-X #1 0 0 115 HERNDON-BARTON 0 0 115 A-Y #2 0 0 115 HIGGINS-BELL 0 0 115 BAIR-BELMONT 0 0 115 H-P #1 0 0 115 BALCH-SANGER 0 0 115 H-P #3 0 0 115 BELL-PLACER 0 0 115 H-P #4 0 0 115 BUTTE-SYCAMORE CREEK 0 0 115 IGNACIO-SAN RAFAEL #1 0 0 115 CAMP EVERS-PAUL SWEET 0 0 115 K-D #1 0 0 115 CHARCA-FAMOSO 0 0 115 K-D #2 0 0 115 CHRISTIE-SOBRANTE 0 0 115 KERCKHOFF #1-KERCKHOFF #2 0 0 115 C-L #1 0 0 115 KERCKHOFF-CLOVIS-SANGER #2 0 0 115 CLAYTON-MEADOW LANE 0 0 115 KERN OIL-WITCO 0 0 115 CONTRA COSTA #2 0 0 115 KERN-LIVE OAK 0 0 115 CORONA-LAKEVILLE 0 0 115 KERN-MAGUNDEN-WITCO 0 0 115 COTTONWOOD-PANORAMA 0 0 115 KERN-ROSEDALE 0 0 115 CRAZY HORSE CANYON SW STA-HOLLISTER 0 0 115 KERN-WESTPARK #1 0 0 115 CRAZY HORSE CANYON SW STA-SAN BENITO 0 0 115 KERN-WESTPARK #2 0 0 115 CRESSEY-GALLO 0 0 115 KIFER-FMC 0 0 115 C-X #2 0 0 115 KINGSBURG-CORCORAN #1 0 0 115 C-X #3 0 0 115 LAKEWOOD-CLAYTON 0 0 115 DAIRYLAND-MENDOTA 0 0 115 LAKEWOOD-MEADOW LANE-CLAYTON 0 0 115 DIVIDE-CABRILLO #2 0 0 115 LAMMERS-KASSON 0 0 115 D-L #1 0 0 115 LAMONT-GRIMMWAY-MALAGA 0 0 115 DUMBARTON-NEWARK 0 0 115 LE GRAND-CHOWCHILLA 0 0 115 EAST GRAND-SAN MATEO 0 0 115 LE GRAND-DAIRYLAND 0 0 115 EASTSHORE-DUMBARTON 0 0 115 LEPRINO FOODS-LEPRINO SW STA 0 0 115 EASTSHORE-MT EDEN #1 0 0 115 LEPRINO SW STA- GWF HANFORD SW STA 0 0 115 EASTSHORE-MT EDEN #2 0 0 115 LERDO-FAMOSO 0 0 2 115 EL CAPITAN-WILSON 0 0 115 LINCOLN-PLEASANT GROVE 0 0

2019 Electric Transmission Annual Availability Performance Report 46 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 115 LOS ESTEROS-MONTAGUE 0 0 115 MOSS LANDING-SALINAS #1 0 0 115 LOS ESTEROS-NORTECH 0 0 115 MOSS LANDING-SALINAS #2 0 0 115 LOS ESTEROS-TRIMBLE 0 0 115 MOUNTAIN VIEW-MONTA VISTA 0 0 115 MADISON-VACA 0 0 115 NEWARK-AMES #2 0 0 115 MARTIN-DALY CITY #1 0 0 115 NEWARK-APPLIED MATERIALS 0 0 115 MARTIN-MILLBRAE #1 0 0 115 NEWARK-DIXON LANDING 0 0 115 MCCALL-CORCORAN 0 0 115 NEWARK-FREMONT #1 0 0 115 MCCALL-KINGSBURG #1 0 0 115 NEWARK-FREMONT #2 0 0 115 MCCALL-KINGSBURG #2 0 0 115 NEWARK-JARVIS #1 0 0 115 MCCALL-MALAGA 0 0 115 NEWARK-JARVIS #2 0 0 115 MCCALL-SANGER #1 0 0 115 NEWARK-LAWRENCE 0 0 115 MCCALL-SANGER #2 0 0 115 NEWARK-LAWRENCE LAB 0 0 115 MCCALL-SANGER #3 0 0 115 NEWARK-MILPITAS #1 0 0 115 MENDOCINO-REDBUD 0 0 115 NEWARK-MILPITAS #2 0 0 115 MENDOCINO-UKIAH 0 0 115 NEWARK-NORTHERN RECEIVING STATION #1 0 0 115 MESA-DIVIDE #1 0 0 115 NEWARK-NORTHERN RECEIVING STATION #2 0 0 115 MESA-SANTA MARIA 0 0 115 NEWARK-TRIMBLE 0 0 115 MESA-SISQUOC 0 0 115 NORTECH-NORTHERN RECEIVING STATION 0 0 115 METCALF-EL PATIO #1 0 0 115 NORTHERN RECEIVING STATION-SCOTT #1 0 0 115 METCALF-EL PATIO #2 0 0 115 NORTHERN RECEIVING STATION-SCOTT #2 0 0 115 METCALF-EVERGREEN #1 0 0 115 NOTRE DAME-BUTTE 0 0 115 METCALF-MORGAN HILL 0 0 115 OAKLAND "J"-GRANT 0 0 115 MIDSUN-MIDWAY 0 0 115 OAKLAND C-MARITIME 0 0 115 MIDWAY-SHAFTER 0 0 115 PALERMO-BOGUE 0 0 115 MILLBRAE-SAN MATEO #1 0 0 115 PALERMO-PEASE 0 0 115 MILPITAS-SWIFT 0 0 115 PALERMO-WYANDOTTE 0 0 115 MONTA VISTA-WOLFE 0 0 115 PANOCHE-EXCELSIOR SW STA #1 0 0 115 MONTAGUE-TRIMBLE 0 0 115 PANOCHE-MENDOTA 0 0 115 MORAGA-CLAREMONT #1 0 0 115 PITTSBURG-MARTINEZ #1 0 0 115 MORAGA-CLAREMONT #2 0 0 115 PITTSBURG-MARTINEZ #2 0 0 115 MORAGA-LAKEWOOD 0 0 115 PLACER-GOLD HILL #1 0 0 115 MORAGA-OAKLAND #2 0 0 115 PLACER-GOLD HILL #2 0 0 115 MORAGA-OAKLAND #3 0 0 115 P-X #1 0 0 115 MORAGA-OAKLAND #4 0 0 115 P-X #2 0 0 115 MORAGA-OAKLAND J 0 0 115 RAVENSWOOD-AMES #1 0 0 115 MORAGA-SAN LEANDRO #1 0 0 115 RAVENSWOOD-AMES #2 0 0 115 MORRO BAY-SAN LUIS OBISPO #1 0 0 115 RAVENSWOOD-BAIR #1 0 0 115 MOSS LANDING-CRAZY HORSE CANYON SW STA #1 0 0 115 RAVENSWOOD-COOLEY LANDING #1 0 0 115 MOSS LANDING-CRAZY HORSE CANYON SW STA #2 0 0 115 RAVENSWOOD-COOLEY LANDING #2 0 0 115 MOSS LANDING-GREEN VALLEY #1 0 0 115 RAVENSWOOD-PALO ALTO #1 0 0 2 115 MOSS LANDING-GREEN VALLEY #2 0 0 115 RAVENSWOOD-PALO ALTO #2 0 0

2019 Electric Transmission Annual Availability Performance Report 47 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 115 RAVENSWOOD-SAN MATEO 0 0 115 RIO OSO-WEST SACRAMENTO 0 0 115 RIO OSO-WOODLAND #2 0 0 115 SAN JOSE "A"-SAN JOSE "B" 0 0 115 SAN JOSE "B"-STONE-EVERGREEN 0 0 115 SAN LEANDRO-OAKLAND J #1 0 0 115 SAN LUIS OBISPO-SANTA MARIA 0 0 115 SAN MATEO-BAY MEADOWS #1 0 0 115 SAN MATEO-BAY MEADOWS #2 0 0 115 SAN MATEO-BELMONT 0 0 115 SAN MATEO-MARTIN #3 0 0 115 SAN MATEO-MARTIN #4 0 0 115 SANGER-CALIFORNIA AVE 0 0 115 SANGER-MALAGA 0 0 115 SANTA MARIA-SISQUOC 0 0 115 SANTA ROSA-CORONA 0 0 115 SCHULTE SW STA-KASSON-MANTECA 0 0 kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 115 SCHULTE SW STA-LAMMERS 0 0 115 TRIMBLE-SAN JOSE B 0 0 115 SEMITROPIC-CHARCA 0 0 115 SEMITROPIC-MIDWAY #2 0 0 115 TUPMAN-NORCO TAP 0 0 115 SHEPHERD-WOODWARD 0 0 115 VACA-VACAVILLE-CORDELIA 0 0 115 SILVERADO-FULTON JCT. 0 0 115 VIERRA-TRACY-KASSON 0 0 115 SOBRANTE-G #1 0 0 115 WAUKENA SW STA-CORCORAN 0 0 115 SOBRANTE-GRIZZLY-CLAREMONT #1 0 0 115 SOBRANTE-GRIZZLY-CLAREMONT #2 0 0 115 WEST SACRAMENTO-BRIGHTON 0 0 115 SOBRANTE-MORAGA 0 0 115 WESTPARK-MAGUNDEN 0 0 115 SOBRANTE-R #1 0 0 115 WHEELER RIDGE-ADOBE SW STA 0 0 115 SOBRANTE-R #2 0 0 115 SOBRANTE-STANDARD OIL SW STA #1 0 0 115 WHISMAN-MONTA VISTA 0 0 115 STELLING-MONTA VISTA 0 0 115 WHISMAN-MOUNTAIN VIEW 0 0 115 TABLE MOUNTAIN-BUTTE #2 0 0 115 WILSON-ATWATER #2 0 0 115 TEMBLOR-KERNRIDGE 0 0 115 WILSON-MERCED #1 0 0 115 TESLA-SCHULTE SW STA #1 0 0 115 TESLA-SCHULTE SW STA #2 0 0 115 WILSON-MERCED #2 0 0 2 115 TESLA-STOCKTON COGEN JCT 0 0 115 WOODLAND-DAVIS 0 0 3

2019 Electric Transmission Annual Availability Performance Report 48 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 230 TESLA-NEWARK #2 2 4321 230 BELLOTA-TESLA #2 1 25 230 GREGG-HERNDON #2 1 4320 230 WEBER-TESLA 1 25 230 SARATOGA-VASONA 1 4320 230 LODI STIG-EIGHT MILE ROAD 2 9 230 DIABLO-MESA 3 3835 230 GATES-MIDWAY 1 8 230 MORRO BAY-CALIFORNIA FLATS SW STA 2 3273 230 MIDWAY-WHEELER RIDGE #1 3 3 230 GOLD HILL-LODI STIG 3 2586 230 BALCH-MCCALL 2 2 230 MORRO BAY-MESA 2 1970 230 BRIGHTON-BELLOTA 2 2 230 COBURN-LAS AGUILAS SW STA 1 1778 230 HERNDON-ASHLAN 1 2 230 MIDDLE FORK-GOLD HILL 3 1634 230 TABLE MTN-RIO OSO 2 2 230 VASONA-METCALF 1 1617 230 CONTRA COSTA-MORAGA #1 1 1 230 GATES-PANOCHE #2 1 1535 230 COTTONWOOD-DELEVAN #1 1 1 230 PIT #3-PIT #1 5 1260 230 DELEVAN-CORTINA 1 1 230 METCALF-MOSS LANDING #1 2 1247 230 DELEVAN-VACA #3 1 1 230 CRESTA-RIO OSO 4 1156 230 DELTA SWITCHING YARD-TESLA 1 1 230 PIT #1-COTTONWOOD 5 1138 230 ELECTRA-BELLOTA 1 1 230 PIT #3-CARBERRY SW STA 3 1113 230 GOLD HILL-EIGHT MILE ROAD 1 1 230 LOS ESTEROS-METCALF 3 1102 230 HELM-MCCALL 1 1 230 MONTA VISTA-JEFFERSON #2 2 956 230 KERN-BAKERSFIELD 1 1 230 PARKWAY-MORAGA 2 765 230 LOS BANOS-PANOCHE #2 1 1 230 BAHIA-MORAGA 2 698 230 MIDWAY-WHEELER RIDGE #2 1 1 230 RAVENSWOOD-SAN MATEO #1 1 622 230 PALERMO-COLGATE 1 1 230 GATES-MUSTANG SW STA #2 1 610 230 RIO OSO-LOCKEFORD 1 1 230 PITTSBURG-TIDEWATER 1 494 230 ROCK CREEK-POE 1 1 230 MORRO BAY-SOLAR SW STA #2 5 493 230 TESLA-NEWARK #1 1 1 230 LONE TREE-CAYETANO 1 478 230 TIDEWATER-SOBRANTE 1 1 230 MONTA VISTA-SARATOGA 2 442 230 TRANQUILLITY SW STA-HELM 1 1 230 BUCKS CREEK-ROCK CREEK-CRESTA 3 381 230 TRANQUILLITY SW STA-KEARNEY 1 1 230 CARBERRY SW STA-ROUND MTN 2 381 230 VALLEY SPRINGS-BELLOTA 1 1 230 MORRO BAY-SOLAR SW STA #1 3 380 230 ARCO-MIDWAY 0 0 230 POE-RIO OSO 1 375 230 ATLANTIC-GOLD HILL 0 0 230 MORRO BAY-DIABLO 1 330 230 BELLOTA-COTTLE 0 0 230 CARIBOU-TABLE MTN 2 290 230 BELLOTA-WARNERVILLE 0 0 230 PITTSBURG-SAN RAMON 1 255 230 BELLOTA-WEBER 0 0 230 IGNACIO-SOBRANTE 1 239 230 BIRDS LANDING SW STA-CONTRA COSTA PP 0 0 230 MOSS LANDING-COBURN 1 232 230 BIRDS LANDING SW STA-CONTRA COSTA SUB 0 0 230 NEWARK-RAVENSWOOD 1 210 230 BORDEN-GREGG #1 0 0 230 GREGG-HERNDON #1 1 183 230 BORDEN-GREGG #2 0 0 230 NEWARK-LOS ESTEROS 1 142 230 BRENTWOOD-KELSO 0 0 230 PANOCHE-TRANQUILLITY SW STA #1 1 138 230 CALIENTE SW STA-MIDWAY #1 0 0 2 230 TESLA-RAVENSWOOD 1 78 230 CALIENTE SW STA-MIDWAY #2 0 0

2019 Electric Transmission Annual Availability Performance Report 49 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 230 CALIFORNIA FLATS SW STA-GATES 0 0 230 LAS POSITAS-NEWARK 0 0 230 CASTRO VALLEY-NEWARK 0 0 230 LOCKEFORD-BELLOTA 0 0 230 COLGATE-RIO OSO 0 0 230 LOGAN CREEK-DELEVAN 0 0 230 CONTRA COSTA PP-CONTRA COSTA SUB 0 0 230 LOS BANOS-DOS AMIGOS 0 0 230 CONTRA COSTA-BRENTWOOD 0 0 230 LOS BANOS-PADRE FLAT SW STA 230kV Line 0 0 230 CONTRA COSTA-DELTA SWITCHING YARD 0 0 230 LOS BANOS-QUINTO SW STA 0 0 230 CONTRA COSTA-LAS POSITAS 0 0 230 LOS BANOS-SAN LUIS PUMPS #1 0 0 230 CONTRA COSTA-LONE TREE 0 0 230 LOS BANOS-SAN LUIS PUMPS #2 0 0 230 CONTRA COSTA-MORAGA #2 0 0 230 MELONES-WILSON 0 0 230 CORTINA-VACA 0 0 230 METCALF-MONTA VISTA #3 0 0 230 COTTLE-MELONES 0 0 230 METCALF-MOSS LANDING #2 0 0 230 COTTONWOOD-DELEVAN #2 0 0 230 MIDWAY-KERN #1 0 0 230 COTTONWOOD-GLENN 0 0 230 MIDWAY-KERN #3 0 0 230 COTTONWOOD-LOGAN CREEK 0 0 230 MIDWAY-KERN #4 0 0 230 COYOTE SW STA-METCALF 0 0 230 MONTA VISTA-COYOTE SW STA 0 0 230 DELEVAN-VACA #1 0 0 230 MONTA VISTA-HICKS 0 0 230 DELEVAN-VACA #2 0 0 230 MONTA VISTA-JEFFERSON #1 0 0 230 DOS AMIGOS PUMPING PLANT-PANOCHE 0 0 230 MORAGA-CASTRO VALLEY 0 0 230 EASTSHORE-SAN MATEO 0 0 230 MORRO BAY-TEMPLETON 0 0 230 EIGHT MILE ROAD-STAGG 0 0 230 MOSS LANDING-LAS AGUILAS SW STA 0 0 230 EIGHT MILE ROAD-TESLA 0 0 230 MUSTANG SW STA-GREGG 0 0 230 FULTON-IGNACIO #1 0 0 230 MUSTANG SW STA-MCCALL 0 0 230 FULTON-LAKEVILLE 0 0 230 NEWARK E-F BUS TIE 0 0 230 GATES-ARCO 0 0 230 NORTH DUBLIN-CAYETANO 0 0 230 GATES-MUSTANG SW STA #1 0 0 230 NORTH DUBLIN-VINEYARD 0 0 230 GATES-PANOCHE #1 0 0 230 PADRE FLAT SW STA-PANOCHE 230kV Line 0 0 230 GLENN-DELEVAN 0 0 230 PANOCHE-TRANQUILLITY SW STA #2 0 0 230 GREGG-ASHLAN 0 0 230 PEABODY-BIRDS LANDING SW. STA. 0 0 230 HAAS-MCCALL 0 0 230 PITTSBURG-EASTSHORE 0 0 230 HERNDON-KEARNEY 0 0 230 PITTSBURG-SAN MATEO 0 0 230 HICKS-METCALF 0 0 230 PITTSBURG-TASSAJARA 0 0 230 HZ-1 0 0 230 PITTSBURG-TESLA #1 0 0 230 HZ-2 0 0 230 PITTSBURG-TESLA #2 0 0 230 JEFFERSON-MARTIN 0 0 230 PITTSBURG-TESORO 0 0 230 KELSO-TESLA 0 0 230 QUINTO SW STA-WESTLEY 0 0 230 LAKEVILLE-IGNACIO #1 0 0 230 RANCHO SECO-BELLOTA #1 0 0 230 LAKEVILLE-IGNACIO #2 0 0 230 RANCHO SECO-BELLOTA #2 0 0 230 LAKEVILLE-SOBRANTE #2 0 0 230 RAVENSWOOD-SAN MATEO #2 0 0 230 LAKEVILLE-TULUCAY 0 0 230 RIO OSO-ATLANTIC 0 0 230 LAMBIE SW STA-BIRDS LANDING SW STA 0 0 230 RIO OSO-BRIGHTON 0 0 230 LAS AGUILAS SW STA-PANOCHE #1 0 0 230 RIO OSO-GOLD HILL 0 0 2 230 LAS AGUILAS SW STA-PANOCHE #2 0 0 230 ROUND MOUNTAIN-COTTONWOOD #2 0 0

2019 Electric Transmission Annual Availability Performance Report 50 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 8. SUMMARY OUTAGE DATA (cont’d)

kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 230 ROUND MOUNTAIN-COTTONWOOD #3 0 0 230 SAN MATEO-MARTIN 0 0 230 SAN RAMON-MORAGA 0 0 230 SOLAR SW STA-CALIENTE SW STA #1 0 0 230 SOLAR SW STA-CALIENTE SW STA #2 0 0 230 STAGG-TESLA 0 0 230 TABLE MTN-PALERMO 0 0 230 TASSAJARA-NEWARK 0 0 230 TEMPLETON-GATES 0 0 230 TESLA-TRACY #1 0 0 230 TESLA-TRACY #2 0 0 230 TESLA-WESTLEY 0 0 230 TESORO-SOBRANTE 0 0 230 TIGER CREEK-ELECTRA 0 0 230 TIGER CREEK-VALLEY SPRINGS 0 0 230 TULUCAY-VACA 0 0 230 VACA-BAHIA 0 0 230 VACA-LAKEVILLE #1 0 0 230 VACA-LAMBIE SWITCHING STATION 0 0 230 VACA-PARKWAY 0 0 230 VACA-PEABODY 0 0 230 VINEYARD-NEWARK 0 0 230 WARNERVILLE-WILSON 0 0 230 WILSON-BORDEN #1 0 0 230 WILSON-BORDEN #2 0 0 2 230 ZA-1 0 0 Count kV Class Line Name Accumulated Outage Frequency Accumulated Outage Duration 1 500 ROUND MOUNTAIN-TABLE MOUNTAIN #1 4 2962 2 500 MALIN-ROUND MOUNTAIN #2 2 574 3 500 ROUND MOUNTAIN-TABLE MOUNTAIN #2 2 4996 4 500 VACA-TESLA 2 8640 5 500 LOS BANOS-GATES #1 1 2009 6 500 LOS BANOS-MIDWAY #2 1 65 7 500 MOSS LANDING-LOS BANOS 1 705 8 500 TRACY-LOS BANOS 1 39 9 500 DIABLO-GATES #1 0 0 10 500 DIABLO-MIDWAY #2 0 0 11 500 DIABLO-MIDWAY #3 0 0 12 500 GATES-MIDWAY 0 0 13 500 MOSS LANDING-METCALF 0 0 14 500 TABLE MOUNTAIN-TESLA 0 0 15 500 TABLE MOUNTAIN-VACA 0 0 16 500 TESLA-LOS BANOS #1 0 0 17 500 TESLA-METCALF 0 0 3 18 500 TESLA-TRACY 0 0

2019 Electric Transmission Annual Availability Performance Report 51 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 9. ORIGINAL CONTROL CHARTS FROM CAISO

2

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2019 Electric Transmission Annual Availability Performance Report 52 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 9. ORIGINAL CONTROL CHARTS FROM CAISO (cont’d)

2 3

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2019 Electric Transmission Annual Availability Performance Report 53 PACIFIC GAS AND ELECTRIC COMPANY ANNUAL ELECTRIC TRANSMISSION AVAILABILITY REPORT: 2019

1 9. ORIGINAL CONTROL CHARTS FROM CAISO (cont’d)

2 3

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2019 Electric Transmission Annual Availability Performance Report 54 PACIFIC GAS AND ELECTRIC COMPANY