Topic:"System Reliability" in M12786

Page 14 of 15 NS Power 2025 Storm Restoration Costs Non-Confidential 1 7.0 PREDICTED AND ACTUAL STORM LEVELS FOR REPORTED EVENTS 2 3 For the two Level 3 EOC activations in 2025 referenced above, December 5th and December 19th, 4 the predic...

AI summary NS Power's 2025 storm restoration report details two Level 3 EOC activations, showing significant discrepancies between predicted and actual customer impacts during storms on December 5 and December 19-20, 2025. The report includes capital expenditures incurred.

METHODOLOGY • The report assigns the temperature and wind data based on the highest observed speeds that occurred during the event. • Full accounting of hourly weather data is provided as an appendix for the eight representative stations u...

AI summary The methodology outlines using weather data from eight representative stations to assess outage impacts, defining unique and total customer impacts, and explaining the rationale for selecting stations to ensure accurate analysis of storm event effects.

2 2025 Storm Restoration Cost Report Attachment 1 Page 4 of 29 SECTION 2: WIND OBSERVATIONS Forecast (24Hr Prior) Actuals Region Wind Wind Weather Weather Sustained Max Wind Precipitation Gust Temp (°C) Direction Station Observation Wind (...

AI summary The document presents wind observation data from various regions in Nova Scotia during a storm, comparing forecasted and actual weather conditions, including precipitation, wind speeds, temperatures, and directions. The data spans multiple locations such as Annapolis Valley, South Shore, and Northern Nova Scotia.

Rain 93 115 180 (ES) CB West Rain 100 Grand Étang 14 Rain 52 96 160 (CBW) CB East Rain 100 Sydney 11 Rain 48 91 190 (CBE) Note: Temperatures shown were recorded during the hour peak winds were observed in each region. Weather service provi...

AI summary The 2025 Storm Restoration Cost Report details an outage affecting 198,998 unique customers across Nova Scotia, with 98.93% restored within 48 hours. NS Power prioritized larger outages first, addressing smaller ones afterward, which often involved remote or flooded areas.

oration principles, these smaller outages are addressed following restoration of larger outages and are often complicated by off-road or remote locations of damage or tree contacts or flooded areas. Event End Time is noted as the beginning...

AI summary The text describes storm restoration processes, noting that smaller outages are addressed after larger ones and are complicated by remote locations. It defines 'Event End Time' as the start of the final outage linked to a storm, with restoration continuing beyond this time as shown in a graph.

SECTION 4: PROVINCIAL IMPACT SUMMARY – DECEMBER 19-20, 2025 NS experienced a wind, snow and rain event This map presents a geospatial bringing strong gusts and significant view of the overall impact to the precipitation on December 19-20,...

AI summary A December 19-20, 2025, wind, snow, and rain event caused power outages across Nova Scotia, with over 600 field resources mobilized for restoration. A geospatial map highlights customer hours of interruption (CHI) by 8 geographical zones, showing red/orange zones with over 25,000 CHI.

Impacted Customers Interruptions (CHI) Valley Eastern Shore (CI) Impacted Yellow >10,000 Halifax Valley Green <10,000 43,852 36,199 289,711 Customers Restored within x South Shore 20,075 17,194 230,061 hours of Storm Onset Northern 20,595...

AI summary The table details customer interruptions and restoration rates following a storm in Nova Scotia, showing impacted customers across regions like Halifax, Valley, and Eastern Shore, with restoration percentages within 6, 12, 24, and 48 hours. Over 98% of customers were restored within 48 hours, though regional disparities exist.

ge. Province 268,354 198,998 2,112,088 93.62% of customers were restored prior to the stormy weather ceasing. Average restoration time for the storm was under 19.5hrs. 5 Customers Impacted (CI) reflects total not unique impacted 2025 Storm...

AI summary The 2025 Storm Restoration Cost Report details a provincial outage on 12/19/2025 in the Valley Zone, where 3,404 customers were impacted for 10.53 hours due to high winds and heavy rain. 93.62% of customers were restored before storm conditions ceased, with an average restoration time under 19.5 hours.

Wind 3,404 10.53 23:03 Weather caused the recloser to operate.

AI summary The text includes a table row with 'Wind' and numerical data (3,404; 10.53) and a note that weather caused a recloser to operate. The context suggests weather-related grid equipment response and potential generation data, though details are limited.

High winds caused trees to South 12/19/2025 Tree Yarmouth 190 52 81 12 Falling Trees contact the primary lines, 1,764 13.5 Shore 20:28 Contacts opening the recloser. High winds and heavy rain 12/19/2025 Loss of Transmission Northern Nappan...

AI summary The text logs power outages caused by high winds and falling trees on December 19, 2025, affecting locations in Yarmouth, Nappan, Caribou Pt., and Halifax. Incidents include tree contact with power lines, broken transmission line leads, and recloser operations, resulting in service interruptions and transmission supply losses.

High winds caused trees to 12/19/2025 Halifax Tree Metro 180 55 85 12 Falling Trees contact the primary lines, 3,587 18.33 17:02 Airport Contacts opening the recloser. High winds caused trees to Eastern 12/20/2025 Beaver Tree 180 96 115 11...

AI summary The text details multiple incidents of high winds causing trees to fall on power lines in Nova Scotia between December 19-20, 2025, leading to outages. Locations include Halifax, Beaver Island, Gr. Etang, and Sydney, with data on affected lines, recloser actions, and associated costs.

12/19/2025 Tree CB East Sydney 190 48 70 11 Falling Trees contact the primary lines, 1,670 15.02 21:26 Contacts opening the recloser. 6 2025 Storm Restoration Cost Report Attachment 1 Page 8 of 29 SECTION 4: PROVINCIAL HIGHLIGHTS – TOP 5 E...

AI summary The text presents a section from a 2025 Storm Restoration Cost Report, highlighting provincial storm events impacting customers. It lists details such as wind speeds, temperatures, and customer impact numbers, focusing on a specific event involving falling trees and power line disruptions.

Station (Degrees) (km/h) (°C) Impacted (Hours) (km/h) High winds and heavy rain 12/19/2025 Caribou Transmission Northeast 170 46 57 11 Loss of Supply caused a broken lead on 4,921 8.59 17:09 Pt. Substation the transmission line. High winds...

AI summary On December 19, 2025, high winds and heavy rains caused power outages in Caribou and Halifax, Nova Scotia. Incidents included a broken lead on a transmission line in Caribou and tree contacts causing recloser operations in Halifax. Weather conditions led to loss of supply and infrastructure damage, impacting thousands of hours of service.

23:06 Airport Weather operate. High winds caused trees to 12/19/2025 Halifax Halifax 180 55 85 12 Tree Contacts Falling Trees contact the primary lines, 3,587 18.33 17:02 Airport opening the recloser. Failed/ High winds caused the 12/20/20...

AI summary The document details storm-related power outages in Halifax on December 19 and 20, 2025, caused by high winds leading to tree contacts and equipment damage. It includes incident data such as the number of trees contacting primary lines, recloser openings, and damaged equipment, with associated restoration costs.

SECTION 4: PROVINCIAL HIGHLIGHTS – TOP 5 EVENTS BY DURATION Max Wind Weather Direction Wind Temp Sub- Customers Duration Zone Date/ Time Gusts Cause Description Station (Degrees) (km/h) (°C) Cause Impacted (Hours) (km/h) High winds caused...

AI summary Two weather-related power outages in Nova Scotia are detailed, caused by high winds toppling trees onto service lines. The South Shore event on 12/20/2025 impacted 1 customer over 79 hours, while a Northeast event on 12/19/2025 affected 49 customers over 69 hours. Both required crew intervention due to road conditions and tree damage.

49 69.84 17:26 Contacts Trees for improved conditions and day light to access this line through the woods. High winds caused a tree to damage South 12/19/2025 Tree Falling the customer’s service line. Crews Yarmouth 190 52 81 12 1 68.35 Sh...

AI summary Reports of tree-related power outages in Yarmouth on December 19, 2025, caused by high winds damaging service lines and primary power lines, leading to delayed restoration efforts due to increased load on downstream customers.

s of interruption: 289,711 Full Restoration : 66.8 Hours 68% elapsed time from first outage event to restoration of last event Customers Restored within X hours of Storm Onset Adverse Weather Cause of Outage (CHI) Valley % This table repre...

AI summary The text provides statistics on service interruptions and restoration times following a storm, including 289,711 interruptions, 66.8 hours for full restoration, and customer restoration percentages within various time frames. Adverse weather, specifically wind and wet snow, is identified as the cause of outages.

ng Trees 1 49.3 8:56 Contacts customer’s service line. High winds caused a tree to break the 12/19/2025 Tree Valley Greenwood 160 41 65 14 Falling Trees customer’s service line. 1 47.39 19:08 Contacts Customer Impact Max Wind Weather Direc...

AI summary On December 19, 2025, high winds and heavy rain caused a tree to break a customer’s service line in Valley, Greenwood, impacting 3,404 customers for 10.53 hours. The adverse weather triggered recloser operations, highlighting grid reliability challenges during extreme weather events.

dual outage. Average restoration time for this Wind region was 23.1 hours. 100% 11 2025 Storm Restoration Cost Report Attachment 1 Page 13 of 29

AI summary The text references an average restoration time of 23.1 hours for a region experiencing a 'dual outage,' with wind-related implications. It is part of the '2025 Storm Restoration Cost Report Attachment 1' from page 13 of 29, indicating analysis of outage recovery metrics.

SECTION 4: ZONE IMPACT SUMMARY – SOUTH SHORE TOP TWO EVENTS BY DURATION & CUSTOMER IMPACT Duration Max Weather Direction Wind Wind Temp Customers Duration Zone Date/ Time Cause Sub-Cause Description Station (Degrees) (km/h) Gusts (°C) Impa...

AI summary The South Shore zone experienced two significant outages caused by high winds and falling trees, impacting one customer each. The first event on December 20, 2025, lasted 79.39 hours, while the second on December 19, 2025, lasted 68.35 hours. Both incidents involved tree damage to customer service lines and challenges accessing affected areas due to road conditions.

14 of 29 SECTION 4: ZONE IMPACT SUMMARY – NORTHERN Cause of Outages (CHI) This region was impacted by high winds and heavy rain during the weather event. The largest cause of outages 29% was due to a transmission line outage which caused o...

AI summary The Northern region experienced outages primarily due to a transmission line failure (29%) and tree contacts (49%), impacting 20,595 customers with 126,874 customer-hours of interruption. Full restoration took 64.03 hours, with 92.34% of customers restored within 24 hours. Adverse weather contributed 20% of outages, and average restoration time was 7.9 hours.

ual outage. Within 48 Hrs 100.00% Average restoration time for this Wind region was 7.9 hours. 100% 13 2025 Storm Restoration Cost Report Attachment 1 Page 15 of 29 SECTION 4: ZONE IMPACT SUMMARY – NORTHERN TOP TWO EVENTS BY DURATION & CUS...

AI summary A severe wind event on December 19, 2025, caused a tree to fall on a primary power line in the Northern zone, impacting 50 customers and requiring 45.86 hours for restoration. The incident highlights infrastructure vulnerabilities to adverse weather.

45.86 17:09 Contacts pole. Hight winds and heavy rain 12/20/2025 Adverse Northern Nappan 280 35 74 -1 Wind caused a branch line fuse to 1 42.6 14:35 Weather open. Customer Impact Max Weather Direction Wind Wind Customers Duration Zone Date...

AI summary Adverse weather events on December 19 and 20, 2025, caused outages in Northern Nappan due to high winds and heavy rain. The incidents impacted 2,525 customers for 5.68 hours and involved equipment failures such as recloser operations and branch line fuse openings.

Wind 2,525 5.68 22:24 Weather the recloser to operate. High winds and heavy rain caused 12/19/2025 Loss of Northern Nappan 170 43 74 13 Transmission a broken lead on the transmission 2,348 8.55 22:13 Supply line. 14 2025 Storm Restoration...

AI summary A storm on 12/19/2025 caused outages in Nova Scotia's Northeast region due to high winds (104 km/h) and heavy rain. Tree contacts (20%) and adverse weather (18%) were primary causes, impacting 55,377 customers with 525,566 interruption hours. Full restoration took 72.92 hours.

100% 15 2025 Storm Restoration Cost Report Attachment 1 Page 17 of 29

AI summary The text references a 2025 Storm Restoration Cost Report, Attachment 1, Page 17 of 29. It includes a line with '100% 15' and formatting symbols, suggesting a document section discussing storm-related restoration costs in Nova Scotia.

17:09 Pt. Supply transmission line. 16 2025 Storm Restoration Cost Report Attachment 1 Page 18 of 29 SECTION 4: ZONE SUMMARY IMPACT SUMMARY – METRO Cause of Outages (CHI) This region was impacted by strong winds and periods of 1% heavy rai...

AI summary The 2025 Storm Restoration Cost Report's Metro region section details outages caused primarily by tree contacts (29%) and adverse weather (67%), impacting 92,007 customers with 559,818 customer-hours of interruption. Full restoration took 69.97 hours, with failed/damaged equipment contributing 3% of outages.

100% 2025 Storm Restoration Cost Report Attachment 1 Page 21 of 29 SECTION 4: ZONE IMPACT SUMMARY –EASTERN SHORE TOP TWO EVENTS BY DURATION & CUSTOMER IMPACT Duration Weather Direction Wind Max Wind Temp Customers Duration Zone Date/ Time...

AI summary The 2025 Storm Restoration Cost Report details two major outage events on Eastern Shore due to high winds (93 km/h gusts) causing tree-related damage. The first event impacted 1 customer for 57 hours, while the second affected 160 customers over 56.97 hours, both attributed to falling trees and primary line contact.

Adverse Weather Full Restoration : 56.69 Hours elapsed time from first outage event to restoration of last event 79% Customers Restored within X hours of Storm Onset Adverse Weather Cause of Outage (CHI) CB West % This table represents the...

AI summary The document details a storm-related outage event, reporting 56.69 hours for full restoration and 79% customer restoration within 48 hours. It highlights regional restoration metrics, including 99.97% of customers restored within 48 hours, with an average restoration time of 14.4 hours. The data is part of a 2025 Storm Restoration Cost Report.

100% 2025 Storm Restoration Cost Report Attachment 1 Page 23 of 29 SECTION 4: ZONE IMPACT SUMMARY – CAPE BRETON WEST TOP TWO EVENTS BY DURATION & CUSTOMER IMPACT Duration Max Wind Customer Weather Direction Wind Duration Zone Date/ Time Gu...

AI summary The 2025 Storm Restoration Cost Report details a power outage in Cape Breton West on December 19, 2025, caused by a tree falling due to high winds (57 km/h gusts). The event impacted 42.13 customers and lasted 1 hour. The report highlights the need for grid resilience against adverse weather events.

22 2025 Storm Restoration Cost Report Attachment 1 Page 24 of 29 SECTION 4: ZONE IMPACT SUMMARY – CAPE BRETON EAST Cause of Outages (CHI) This region was impacted by high winds and heavy rain during the weather event. Winds were above warn...

AI summary The 2025 Storm Restoration Cost Report details Cape Breton East's outage causes: 28% tree-line contacts, 1% equipment failure, and 71% adverse weather. 22,770 customers were impacted, with 253,180 customer-hours of interruption and full restoration taking 66.18 hours.

Adverse Weather Customers Impacted: 22,770 Customer hours of interruption: 253,180 Full Restoration : 66.18 Hours 71% elapsed time from first outage event to restoration of last event Customers Restored within X hours of Storm Onset Advers...

AI summary The document details an adverse weather outage impacting 22,770 customers with 253,180 customer hours of interruption. Restoration data shows 58.72% of customers were restored within 24 hours, with an average restoration time of 19.87 hours. The report is part of the 2025 Storm Restoration Cost Report, focusing on outage management and system reliability.

100% 2025 Storm Restoration Cost Report Attachment 1 Page 25 of 29 SECTION 4: ZONE IMPACT SUMMARY – CAPE BRETON EAST TOP TWO EVENTS BY DURATION & CUSTOMER IMPACT Duration Max Weather Direction Wind Wind Customers Duration Zone Date/ Time T...

AI summary The 2025 Storm Restoration Cost Report details two major outage events in Cape Breton East caused by adverse weather and falling trees, impacting 1 customer each. The first event on 12/19/2025 involved high winds and heavy rain, while the second on 12/20/2025 was due to a tree falling on a service line. Both events are classified under 'Adverse Weather Cause of Outage' (CHI).

Contacts Trees East opening the recloser. 24 2025 Storm Restoration Cost Report Attachment 1 Page 26 of 29 SECTION 5: COMPARISON TO SIMILAR OUTAGE EVENTS • The 2018 storm brought stronger peak winds than the Event December 19- January 4-5...

AI summary The document compares the 2025 and 2018 storms in Nova Scotia, noting similar peak wind strengths but differing weather conditions (2018 had snow/ice; 2025 had heavy rain). Both caused significant tree and line damage, affecting over 200,000 customers and resulting in millions of interruption hours.

, Customer 2,112,088 2,094,094 while 2025 brought upwards of 40 mm of heavy rain that Hours of tapered off before temperatures fell below freezing. Interruption • During the December 19–20, 2025 storm, crews worked Customers 98.93 99.88 Re...

AI summary The 2025 storm caused significant outages due to heavy rain and freezing temperatures, challenging NS Power's restoration efforts. Crews faced obstacles like broken poles and poor visibility, leading to slower response times. Lessons include improved prediction models and reliance on ground patrols during adverse weather.

y work for crews the following morning. This work was very useful for restoration and will be considered for following events as the weather is cleared and they can patrol main feeders. 26 2025 Storm Restoration Cost Report Attachment 1 Pa...

AI summary The text defines terms from the 2025 Storm Restoration Cost Report, including 'Customer Interruptions' (CI) and 'Customer Hours of Interruption' (CHI), which measure outage impacts. It highlights restoration efforts following a storm and categorizes outage causes, such as transmission issues and scheduled outages.

Loss of supply Interruptions due to problem in the bulk electricity system (transmission) SAIFI = Average Outage Frequency Tree contacts Interruptions caused by trees or tree limbs contacting energized circuits Customer interruptions / # o...

AI summary The text categorizes electricity supply interruptions by cause, including tree contacts, lightning, defective equipment, and adverse weather, and defines metrics SAIFI, SAIDI, and CAIDI to quantify outage frequency and duration. These metrics help assess system reliability and customer impact.

, i c e s t o r m s , s n o w , w i n d s , extreme ambient temperatures, freezing fog, or frost) Customer hours of interruption / # of customer interruptions Adverse environment Interruptions due to equipment being subjected to abnormal e...

AI summary The document categorizes customer interruptions by cause: adverse environments (e.g., storms, freezing conditions), human error, and foreign interference. It references a 2025 Storm Restoration Cost Report and weather data filed on December 19–20, 2025, highlighting infrastructure resilience and outage management challenges.

anticipates using this information to inform future 18 operational and contracting standards. 19 20 Response IR-2: 21 22 (a) Example of Mid-Storm reporting provided to the EOC: 23 External Day Region Diggers Veg Day TCP Night TCP Buckets W...

AI summary NSPI provides a 2025 Storm Restoration Cost Report (NSEB M12786) detailing mid-storm outage reporting practices. The response indicates no immediate plans to use this data for future operational/contracting standards, though granular regional reporting is available during events.

improvement. It should be noted that the general approach to pre-storm prediction does not 30 change depending on whether or not NS Power expects a level 1, 2, 3 or 4 event and is Date Filed: May 21, 2026 NSPI (CA) IR-3 Page 1 of 2 2025 St...

AI summary NSPI explains its pre-storm prediction methodology for storm restoration costs, emphasizing consistency across event levels (1-4) and reliance on data assessments and expert judgment. The response is part of the NSEB M12786 proceeding regarding the 2025 Storm Restoration Cost Report.

1 (iii) Based on the forecast, 43 percent of the external PLT contractors were staged in the 2 Cape Breton region prior to the event; 24 percent West, 20 percent in the Northeast 3 and 13 percent in the Metro region. 4 5 For the December 1...

AI summary The text outlines contractor deployment during two storm events in December 2025 and describes a post-event critique process mandated by the Emergency Storm Response Plan (ESRP) to evaluate restoration efforts and identify improvements. Regional contractor distribution and post-event review procedures are detailed.

2025 Storm Restoration Cost Report (NSEB M12786) NSPI Responses to Industrial Group Information Requests NON-CONFIDENTIAL 1 Request IR-8: 2 3 Reference: The Board Decision in M12188 acknowledged NSPI’s commitment to provide 4 5 “more speci...

AI summary NSPI asserts that its December 2025 storm lessons learned report fulfills the Board's directive, emphasizing that wind-driven storm restoration relied on established practices with incremental improvements rather than systemic changes. The response highlights the event's unique challenges compared to prior storms like ice events.

content creator roster for Communications Lead. 27 28 • Access passwords for some systems expire 30 days and mass resets need to be explored by 29 the Operational Technology lead. 30 Date Filed: April 17, 2026 NSPI (NSEB) IR-14 Page 1 of 2...

AI summary NSPI states it will not alter its vegetation management program post-storm, maintaining spending per the Five-Year Reliability Plan and adhering to existing clearance standards. The document includes a Post-Event Critique for a December 2025 storm and references NSEB M12728 and IR-8.

(still in flight) ▪ Warming centers – should come through PCC ▪ Sanjeev to take away and follow up with EMO 7 2025 Storm Restoration Cost Report IG IR-8 Attachment 2 Page 8 of 9 IT Lead: Done Well: • Thankful for the December 4th event/tab...

AI summary The IT lead highlighted successful aspects of the December 4th storm response, including effective technology use and proactive monitoring, while noting areas for improvement like coverage gaps and data integration issues.

equipment is subject to the actual weather which occurs and its relative accuracy to a 30 forecast produced in advance of an event and may change considerably over time. Third- Date Filed: May 21, 2026 NSPI (IG) IR-9 Page 1 of 2 2025 Storm...

AI summary NSPI explains its use of weather forecasts and continuous model calibration for storm restoration planning, acknowledging forecast limitations. It references the 2025 Storm Restoration Cost Report and ESRP, emphasizing preparedness for potential events and model refinement using past data, including December 5, 2025, in Q3 2026 calibration.

1 Request IR-1: 2 3 On pdf pg. 5 of the report, NS Power states: 4 5 “An outage report was not compiled for the Level 3 Winter Storm EOC event 6 on December 5, 2025, as the storm did not meet the reporting threshold. 7 Outage prediction mo...

AI summary NS Power's response to an inquiry about a Level 3 Winter Storm EOC event on December 5, 2025, explains that the 28,000 customer impact estimate was derived from its Damage Prediction Model (DPM) using weather forecasts. The response also mentions restoration delay expectations but does not yet address the actual restoration time.

Customers Out/PH to Repair Damages Trees Customers Vegetation Transmission Conductor Transmission Region PLT Person Hrs Feeders Off Branch-Lines Off Services Transformers Poles on Out Person Hrs Person Hrs Spans Structures Spans West 3,609...

AI summary The table presents statistics on customer outages, repair efforts, and infrastructure disruptions across Nova Scotia regions (West, Metro, Northeast, Cape Breton), including metrics such as customers out, person-hours for repairs, vegetation management, transmission feeders, and conductor spans affected. Data highlights regional differences in service disruptions and repair activities.

Customers Out/PH to Repair Damages Trees Customers Vegetation Transmission Conductor Transmission Region PLT Person Hrs Feeders Off Branch-Lines Off Services Transformers Poles on Out Person Hrs Person Hrs Spans Structures Spans SYD 4,505...

AI summary The table presents outage and repair data across regions (SYD, PHA, RIB, BAD), tracking metrics like customers out, repair hours, vegetation damage, and infrastructure impacts (e.g., transmission feeders, poles, transformers). It highlights regional differences in outage frequency and repair efforts, likely relevant to assessing grid reliability and service restoration priorities.

1 Request IR-7: 2 3 On pdf pg. 14 of the report NS Power notes it is planning to implement a software platform 4 in 2026 to further monitor and control contractor costs. NS Power notes that the 5 commercially available software will enable...

AI summary NS Power plans to implement AI-based software in 2026 to monitor contractor costs and predict storm impacts. The software has not been tested against its existing Damage Prediction Model (DPM), though consultations with other utilities suggest AI tools improve predictions. Current storm impact predictions rely on the DPM.

2025 Storm Restoration Cost Report (NSEB M12786) NSPI Responses to Industrial Group Information Requests NON-CONFIDENTIAL 1 Request IR-6: 2 3 Reference: At p. 3, NSPI sets out its storm classification scheme which includes two 4 metrics –...

AI summary The document addresses NSPI's storm restoration timelines, confirming that estimated durations (12/24/36 hours) assume 100% customer restoration within specified timeframes. It references the ESRP document's Section 5.2 and acknowledges that pre-storm forecasts may differ from actual event conditions.

2025 Storm Restoration Cost Report (NSEB M12786) NSPI Responses to Industrial Group Information Requests NON-CONFIDENTIAL 1 2 3 (b) Yes. For events where fewer than 50,000 customers are expected to be impacted the 4 determination of the re...

AI summary NSPI's response to Industrial Group information requests regarding the 2025 Storm Restoration Cost Report (NSEB M12786) outlines criteria for determining response levels based on anticipated restoration durations for events impacting fewer than 50,000 customers, referencing NSEB IR-01 part (b). The document was re-filed on May 25, 2026.

dith Ferguson, Others: ☐ Matt Drover, ☐ Mike Sampson, ☐ Emily MacNeil, Post Event Review (Per PEC Sub-Process 9 & ESRP Appendix 7) Welcome and Overview: Safety Performance: Done Well: o Testing our abilities after a while of not mobilizing...

AI summary Post-event review of the 2025 storm restoration highlights successful transmission system resilience, effective resource mobilization, and ETR strategy improvements. Areas for improvement include updating safety subplans for out-of-province contractors and ensuring all transmission leads are in the GE APM solution for standby.

50,000 customers where restoration duration was the sole determinant of the Level 3 designation, require NSPI to demonstrate specifically: - the basis for the pre-storm restoration duration forecast, - a comparison of forecast versus actua...

AI summary Nova Scotia Power Incorporated (NSPI) is required to justify its Level 3 storm restoration classification based on restoration duration forecasts and actual impacts. NSPI argues that maintaining the classification supports resource coordination and system restoration, and that adjusting classifications mid-storm could disrupt operations. It emphasizes operational flexibility and contractor arrangements in managing resource deployment.

Document: 329289 Date Filed: April 29/26 Page 1 1 Request IR-1: 2 On pdf pg. 5 of the report, NS Power states: “An outage report was not compiled for the Level 3 3 Winter Storm EOC event on December 5, 2025, as the storm did not meet the r...

AI summary The document contains two regulatory requests (IR-1 and IR-2) directed at Nova Scotia Power, seeking explanations on outage impact estimates, restoration delay calculations, cost breakdowns, and resource allocation during a Level 3 Winter Storm EOC event on December 5, 2025. The requests emphasize the need for quantitative analysis and documentation.

Any deficiencies, limitations, or failures identified post- 9 event. 10 (c) Please quantify, where possible, the cost savings attributed to: 11 (i) Standardized storm contractors; 12 (ii) Per diem meal reimbursement practices; and 13 (iii)...

AI summary The document outlines requests for quantifying cost savings from storm contractor practices, explaining contractor invoice validation, and clarifying NSPI's storm level declarations. It also seeks expanded data on predicted vs. actual restoration times and the use of impact forecasts in emergency decisions.

(b) Please confirm that where fewer than 50,000 customers are forecasted to 24 be affected, the sole differentiating factor is the expected time to restore? 25 (c) Please provide the criteria that NSPI applies to establish the expected tim...

AI summary The text raises questions about NSPI's storm-level designation policies, specifically whether conservative restoration time estimates lock in higher storm levels and associated costs, and whether those costs are recoverable via the storm rider. It also references a Board Decision (M12188) and a 2025 wind storm report's lessons learned.