AI-generated summary
· Application · 05/07/2026
Eight intervenor groups file 236 information requests challenging EfficiencyOne's proposed 2027–2031 Demand-Side Management Plan, pressing on affordability constraints, cost-effectiveness, industrial rate equity, demand response performance, and mid-course adjustment governance.
AI summary
- The Industrial Group filed 29 detailed IRs probing EfficiencyOne's decision to freeze annual DSM investment at the 2026 level of $63.75M with no inflationary adjustment, questioning whether this ceiling was analytically justified or simply assumed, and demanding rate-class-by-rate-class spending reconciliations showing that Large Industrial customers will face DSM rate impacts of 6.26% in 2027 and 6.02% in 2028 while paradoxically seeing increases — not decreases — from the Demand Response Load Control component unlike every other class.
- Synapse Energy Economics, acting as Board Counsel consultant, filed 90 IRs covering the broadest analytical scope: requests include full unprotected Excel workbooks for Round 1 and Round 2 modelling, portfolio-level cost-effectiveness under both the PAC and the Board-approved modified-PAC test, reconciliation of the Preferred Plan's 435.4 GWh savings against the 2022 IRP reference of 683.1 GWh, an explanation of why Strategic Electrification was excluded despite its statutory inclusion in the DSM definition, and detailed device-level and hourly event performance data for Eco Shift residential demand response.
- Multiple intervenors challenged the BNI Demand Response (Smart Synergy) program on equity and eligibility grounds: the Industrial Group asked why Large Industrial Interruptible customers remain ineligible to participate in Smart Synergy despite bearing an allocated share of its costs, while the Econoler evaluation apparently showed per-participant DR capacity collapsing from ~106 kW to ~42 kW in 2025 with a non-participation rate approaching 60%.
- NSPI filed 16 IRs focused on solar PV cost-effectiveness treatment (whether federal/provincial co-funding was included as a cost in PAC calculations for 2023–2025), the rationale for freezing Residential DR enrollment during 2027–2031, the environmental and permitting implications of the proposed load-shift-to-backup-generators (BUGs) pathway, and the governance and exit-strategy design for the new Market Transformation enabling strategies category.
- Governance of 2027-2031 Demand Side Management Preferred Resource Plan mid-course adjustments drew scrutiny from at least four intervenors — NSPI, the Industrial Group, Synapse, and the Consumer Advocate — each questioning whether the proposed 15%/20% rate-class/program spending thresholds are analytically grounded, how the mid-term check-in can be meaningful if it creates no obligation to act, and what distinguishes an event requiring a full Board application from one handled internally.
Disclaimer: This summary was generated by AI from the filings it describes. We take care to make it accurate, but errors are possible - and it isn't advice. Only the filings themselves are the record: if you're relying on something here, confirm it against the source documents or the Nova Scotia Energy Board's own record. Full disclaimer →
What was filed
Documents filed on this day
- 101893 CA (E1) IR 1 to 19
- 101895 EE (E1) IR 1 to 10
- 101899 NSEB (E1) IR 1 to 66
- 101900 Synapse (E1) IR 1 to 90
- 101901 MEUs (E1) IR 1
- 101902 NSPI (E1) IR 1 to 16
- 101905 SBA (E1) IR 1 to 8
- 101907 IG (E1) IR 1 to 29
- 101909 SNS (E1) IR 1 to 15