Fact-checked by Grok 2 weeks ago

BC Hydro

BC Hydro is a provincial wholly owned by the , , responsible for generating, transmitting, distributing, and selling to approximately 95 percent of the province's population, serving around 5 million people through more than 2 million customer accounts. Formed in through the merger of the private BC Electric Company—established in 1897—and the public BC Power Commission—created in 1945—BC Hydro operates one of North America's largest hydroelectric systems, with over 80 percent of its installed capacity derived from facilities in the and basins. The corporation manages 30 hydroelectric generating stations, supplemented by thermal and renewable sources, producing 43,000 to 54,000 gigawatt hours of annually depending on water flows, and maintains an extensive and network spanning over 80,000 kilometers of power lines. Approximately 90 percent of its energy supply is clean and renewable, primarily hydroelectric, enabling BC Hydro to meet rising demand from , electrification of and heating, and industrial expansion while pursuing projects like the Site C Clean Energy Project to add 1,100 megawatts of capacity. Key achievements include the development of major infrastructure under the , such as the , Revelstoke, and Hugh Keenleyside dams, which harnessed the region's potential and facilitated international energy exports via subsidiary Powerex. However, BC Hydro has faced challenges including cost overruns on capital projects like Site C—initially budgeted at $6.6 billion but exceeding $16 billion due to geological issues and regulatory delays—and upward pressure on customer rates amid debt accumulation and the need for system reinforcements to support net-zero goals. As a regulated , its operations emphasize reliability, with a focus on integrating independent power producers for wind and run-of-river additions, though critics have noted risks from over-reliance on variable renewables without adequate storage.

History

Formation and Early Expansion (1961–1980s)

The Hydro and Power Authority, commonly known as BC Hydro, was established as a provincial on March 30, 1962, via the amalgamation of the British Columbia Electric Company Limited—expropriated by the province in 1961—and the British Columbia Power Commission. This merger centralized , , and under public ownership, enabling coordinated development of hydroelectric resources to address surging postwar demand. Early expansion prioritized large-scale hydroelectric projects, particularly along the , pursuant to the 1961 between and the , which emphasized and power generation through upstream storage. BC Hydro advanced construction of the , which entered operation on March 29, 1973, creating Kinbasket Reservoir and contributing over 1,700 megawatts of capacity for baseload supply. The , completed in 1984 with an initial installed capacity of 2,480 megawatts, extended this infrastructure downstream, optimizing river flow for enhanced generation. These initiatives delivered reliable, low-cost hydroelectric power that underpinned British Columbia's during the period, powering resource-intensive industries such as aluminum —exemplified by facilities like those of —and pulp and paper mills tied to expansion. By the late , BC Hydro's capacity had expanded from approximately 500 megawatts in the early to several multiples thereof, supporting and industrial booms while financed initially through provincial debt mechanisms including guaranteed bonds.

Major Dams and Treaty Commitments (1990s–2000s)

During the , BC Hydro emphasized management and optimization of existing hydroelectric assets rather than pursuing large-scale new dam construction, as domestic electricity demand growth moderated following the expansions of prior decades. The W.A.C. Bennett Dam on the , operational since 1967, continued to support flood control through Williston Reservoir operations while generating approximately 2,730 MW, with ongoing maintenance addressing reservoir levels to balance power production and environmental flows. Expansions were limited, reflecting fiscal constraints and reduced need for additional capacity amid surplus generation margins that persisted into the early . Under the 1964 Columbia River Treaty, BC Hydro maintained commitments to operate Duncan Dam, completed in 1972 on the , in coordination with the U.S. Army Corps of Engineers' Libby Dam to regulate flows for and downstream benefits. This arrangement provided Canada with half of the additional power generated downstream in the U.S., marketed by BC Hydro as the Canadian Entitlement, yielding annual revenues estimated in the billions through sales to American utilities. Operations involved precise water releases to optimize these benefits, though environmental critiques highlighted adverse effects on downstream salmon migration and fisheries due to altered seasonal flows, with studies linking dam-regulated hydrographs to persistent declines in fish returns. In the early 2000s, BC Hydro commissioned the 450 MW Generating Station in 2002 adjacent to the existing Hugh Keenleyside Dam, enhancing power output from Treaty storage without requiring new reservoir construction and adding flexibility to Columbia Basin operations. Amid broader North American pressures for deregulation following California's 2000-2001 , BC Hydro shifted toward integrated resource planning that preserved public ownership of core assets while exploring limited contracts with independent producers for smaller run-of-river projects, prioritizing reliability over rapid . This approach sustained focus on mega-scale public infrastructure amid emerging debates on long-term supply security.

Restructuring and Shift to IPPs (2010s)

The British Columbia Energy Plan of November 2002, introduced by the BC Liberal government, mandated that all new clean or renewable electricity generation be developed by independent power producers (IPPs) rather than BC Hydro, prohibiting the Crown corporation from building additional capacity beyond its existing assets. This restructuring aimed to stimulate private investment in non-utility generation, particularly wind and run-of-river hydroelectric projects, while maintaining public control over transmission and distribution. Into the 2010s, BC Hydro implemented this policy through competitive calls for power, including the 2010 Clean Power Call that resulted in over 70 contracts awarded, expanding IPP contributions to address projected demand from population growth and electrification. By fiscal year 2016, IPPs delivered approximately 20,000 GWh annually, comprising about one-third of BC Hydro's domestic supply. Run-of-river projects, which dominated IPP development and accounted for roughly 70% of active agreements, faced criticism for their intermittent output and low effective factors relative to BC Hydro's facilities. These facilities, lacking significant , generated during spring freshet but underperformed during winter highs, with capacity factors typically ranging from 40% to 80% but yielding unreliable baseload supply due to hydrological variability. Wind IPPs similarly exhibited low capacity factors, often below 30%, exacerbating dependence on BC Hydro's dispatchable assets for grid stability. Long-term power purchase agreements (PPAs) under the guaranteed IPPs fixed payments, often at rates exceeding prices, effectively transferring risk to ratepayers and subsidizing private returns amid policy-driven emphasis on renewable expansion. A 2019 provincial review identified these contracts as contributing to excess non-firm energy, with BC Hydro acquiring more supply than needed given slower-than-forecast demand growth, locking in billions in future costs. Despite warnings from analysts about potential shortfalls in dry conditions and the limitations of intermittent sources for electrification-driven load increases, the prioritized targets over integrated for reliable .

Generation and Supply

Core Hydroelectric Assets

BC Hydro owns and operates over 30 hydroelectric generating stations, providing the majority of its electricity generation with an installed capacity exceeding 12,000 megawatts (MW). These facilities, concentrated in the Peace, Columbia, and coastal regions, rely predominantly on storage hydroelectric technology, featuring large reservoirs that enable flexible dispatch for baseload supply and seasonal peaking to meet demand variations. Unlike run-of-river systems, this storage capability allows water accumulation during high-flow periods for release during dry seasons or peak usage, achieving effective capacity factors through regulated river flows. The Columbia River basin hosts BC Hydro's largest assets, stemming from developments under the 1961 Columbia River Treaty with the United States, which facilitated multi-purpose dams for power, flood control, and navigation. Key installations include the Mica Generating Station (2,805 MW capacity after expansions completed in 2019–2020) and Revelstoke Generating Station (2,480 MW, with Unit 6 adding 500 MW operational by late 2025), forming a sequential chain on the upper Columbia that collectively exceeds 5,000 MW. Additional facilities like the 1,000 MW Arrow Lakes Generating Station contribute to this system's dominance, accounting for nearly half of BC Hydro's total capacity and enabling efficient energy export entitlements under the treaty, averaging 3,990 gigawatt-hours annually. The Peace River system complements this with 3,424 MW from dams such as W.A.C. Bennett (2,730 MW) and Peace Canyon (1,000 MW, upgraded in phases through 2014), supporting northern load growth and interbasin transfers. Coastal and Lower Mainland facilities, totaling about 1,104 MW across stations like the 225 MW Stave Falls complex and 200 MW Buntzen units, provide localized supply but face unique operational constraints due to smaller reservoirs and runoff dependency. These owned assets deliver low marginal production costs inherent to mature hydroelectric systems, far below alternatives, supporting BC Hydro's emphasis on reliable, renewable baseload without fuel expenses. However, many facilities date to the 1960s–1980s, prompting ongoing maintenance to address aging components such as turbines and spillways. Seismic vulnerabilities, particularly in coastal areas prone to Cascadia subduction zone events, have driven upgrades; BC Hydro conducts regular hazard assessments and retrofits, including spillway reinforcements at sites like La Joie Dam (allocated $1.2 billion in 2024 for seismic and reliability improvements). Independent audits since 2013 affirm compliance with modern standards, though induced seismicity risks from reservoir fluctuations or nearby activities remain monitored. These efforts ensure long-term dispatchability amid infrastructure lifecycle challenges.

Role of Independent Power Producers

Independent Power Producers (IPPs) supplement BC Hydro's owned hydroelectric generation through private development of renewable projects, primarily under long-term Purchase Agreements (EPAs) that commit BC Hydro to buying output at fixed or indexed prices. These contracts shift upfront capital and development risks to private entities, enabling capacity additions without direct increases to BC Hydro's debt, which stood at significant levels from builds. As of April 1, 2025, BC Hydro maintains 119 operational EPAs with IPPs, many initiated since the early policy shift toward private procurement. The majority of IPP capacity derives from run-of-river hydroelectric projects, which lack substantial storage and yield annual capacity factors of approximately 38%, alongside resources that exhibit variability. These sources deliver over 21,000 GWh annually but pose reliability challenges due to seasonal mismatches—high spring output from run-of-river coinciding with BC Hydro's surplus from releases, versus limited winter peaking. Oversupply has necessitated curtailment payments to IPPs, totaling millions of dollars yearly to forgo production when system needs are low, highlighting tensions between incentivizing private investment and operational efficiency. EPAs typically guarantee payments for contracted regardless of BC Hydro's immediate dispatch needs, fostering incentives for rapid deployment but at costs exceeding the near-zero marginal expenses of existing hydro assets. Average payments to IPPs reached $101 per MWh in fiscal 2023/24, compared to recent bids as low as $74/MWh levelized for new projects—still premiums over hydro's variable costs, borne by ratepayers and raising critiques of subsidized returns for developers amid ample public supply. This structure avoids public borrowing for speculative builds but exposes BC Hydro to fixed obligations during low-demand periods, potentially straining system reliability without storage flexibility. To address projected load growth from electrification, BC Hydro's 2025 Call for Power targets up to 5,000 GWh per year from large-scale clean or renewable projects, prioritizing those offering winter-peaking capacity to align with demand patterns. Proposals must include at least 25% equity ownership by First Nations, with dedicated support for participation to advance economic reconciliation and self-determination. Successful bids will extend the IPP model, balancing private capital's speed against the need for dispatchable resources to mitigate intermittency risks.

Imports, Exports, and Interconnections

BC Hydro maintains electrical interconnections with the through the Westside Intertie, consisting of two 500 kV lines from Ingledow Substation to Custer Substation with a capacity of up to 2,000 MW, and the Eastside Intertie, including the 400 MW Boundary-Nelway line. These ties facilitate power trading with the states of and , as well as wheeling arrangements to access markets in . Through its trading arm Powerex, BC Hydro exports surplus hydroelectric generation to the U.S. during wet years, with exports historically accounting for 10-20% of system supply in peak periods and generating revenues exceeding $200 million annually, including nearly $1 billion in sales to the U.S. in fiscal year 2024. These exports operate on market pricing principles, providing a against domestic supply variability by offsetting fixed costs of hydroelectric during high-water periods. However, conditions reduce exportable surplus, as evidenced by a 45% decline in British Columbia's U.S. exports from 2022 to 2023. In dry years, BC Hydro imports power to meet demand, primarily from U.S. sources via the interties, with additional wheeling through American grids for opportunities and limited trades with to balance regional needs. 2024 saw record imports of 13,600 GWh—equivalent to about 25% of domestic requirements—costing $1.377 billion, driven by low impacting output. Over the longer term, spanning 15 to 2025, BC Hydro achieved net exporter status in eight years, enabling revenue diversification that bolsters system reliability without relying on subsidized exports. Provincial government communications often emphasize trading's role in broader public benefits, such as reducing emissions in import partners like , though economic analyses highlight its primary function in covering capital costs through competitive sales rather than altruism.

Major Projects and Infrastructure

Site C Dam Development and Completion

The Site C Clean Energy Project, the third hydroelectric dam on the following the W.A.C. Bennett Dam and Peace Canyon Dam, was approved by the government in December 2014 after environmental assessments completed in October 2014 and prior regulatory reviews, including input from the BC Utilities Commission. began in summer 2015, with the project engineered to deliver 1,100 MW of installed capacity and approximately 5,100 GWh of annual energy generation, equivalent to powering about 450,000 homes and augmenting BC Hydro's overall supply by 8%. Full operations were achieved on August 9, 2025, with all six generating units in service following the first unit's commissioning in October 2024. The development addressed projected electricity load growth of at least 15% by 2030, driven by population expansion, industrial demand, and of transportation and heating, with system-wide requirements anticipated to reach around 70,000 GWh annually in the 2030s. This baseload facility provides dispatchable, reliable power with lower variability than run-of-river projects, enhancing system redundancy and stability amid increasing reliance on intermittent renewables and imports. Engineering focused on a , 60 meters high and 1,050 meters long, with an 83-kilometer , incorporating co-benefits like augmented for the Peace River basin. Initial cost estimates in 2014 stood at $6.6 billion to $8.8 billion, but geotechnical issues, including right-bank stability concerns identified in 2019, necessitated foundation enhancements and contributed to substantial escalations, underscoring the fiscal risks of large-scale despite its long-term value for . While construction timelines were compressed through phased unit commissioning, avoiding full stoppages, the project's completion balances the imperative for firm baseload capacity against higher-than-anticipated capital outlays, positioning it as a cornerstone for BC Hydro's supply amid rising demand pressures.

Transmission Expansions like North Coast Line

The North Coast Transmission Line (NCTL) is a key BC Hydro project to expand the grid in northwest British Columbia, enabling the delivery of clean hydroelectric power to support LNG facilities and mining operations while unlocking remote generation potential. The initiative involves constructing new 500 kV lines from Williston Substation near Prince George to Skeena Substation near Terrace, with Phase 2 alone adding approximately 145 km from Telkwa to Skeena. In October 2025, provincial legislation expedited the project via Bill 31, addressing rising costs for the first two phases now estimated at $6 billion, up from an initial $3 billion projection. Construction is set to commence in 2026, targeting Phase 1 operations by fall 2030 and overall completion by 2034, with projections of 9,700 jobs created and $10 billion annual GDP contribution from enabled resource projects. Complementary expansions address diverse demands, such as the Clayburn Substation upgrade in Abbotsford, which boosts capacity by 50% to serve population growth equivalent to 17,500 additional homes, with work starting September 2025 and finishing in 2028 as part of broader regional investments. For coastal reliability, BC Hydro completed removal of a record-length marine crossing at Jervis Inlet in October 2025, with full upgrades to 230 kV standards across Jervis Inlet and Channel slated for spring 2027 to increase capacity and mitigate risks for Powell River communities. These buildouts respond to private sector needs, particularly from resource extraction, amid policy shifts limiting AI and data center allocations to 400 MW every two years (300 MW for AI, 100 MW for general data centers) to prioritize transmission for high-impact industries like mining and LNG over less essential loads.

Upgrades and Decommissioning Efforts

BC Hydro has pursued upgrades to enhance turbine efficiency and overall capacity at existing facilities, such as the Mica Generating Station, where two new 500-megawatt generating units (Units 5 and 6) were installed in empty bays of the powerhouse, completed in March 2016. This $714 million project increased the station's capacity by approximately 1,000 megawatts, enabling it to produce power for over 650,000 homes annually and representing about a 10 percent boost to BC Hydro's total generation capability. Such retrofits leverage underutilized infrastructure to add output without requiring entirely new dams, though they are constrained by site-specific and original powerhouse designs that limit further expansions. Seismic reinforcements form a core component of BC Hydro's asset lifecycle management, particularly following assessments of earthquake risks in . The John Hart Dam Seismic Upgrade Project, a $1 billion initiative, began construction in summer 2023 with completion targeted for 2030, focusing on reinforcing structures to withstand major seismic events while maintaining water passage capabilities. Similarly, at Ladore Dam near Campbell River, seismic upgrades commenced in January 2025, including reinforcements, intake tower modifications, and installation of new gates to ensure operational integrity during earthquakes or floods. These efforts, supplemented by $700 million in broader dam safety investments, prioritize retrofitting over replacement to extend asset life amid regional seismic hazards. Decommissioning activities target aging or redundant to reduce environmental impacts and facilitate modern . In 2025, BC Hydro removed a record-setting 138-kilovolt marine transmission line crossing Jervis Inlet, once among the longest of its kind globally, as part of a to enhance and reliability. The subsequent phase involves removing and upgrading the Agamemnon Channel crossing in spring 2026, minimizing marine disruptions while transitioning to higher-capacity lines. Overall, these lifecycle strategies favor cost-effective upgrades and selective decommissioning over developments, as renewing existing assets yields longer at lower expense than full rebuilds, despite limitations from hydrological variability and aging foundations.

Financial and Economic Aspects

Revenue Sources and Debt Accumulation

BC Hydro's revenues for the ended March 31, 2025, totaled $7.478 billion, with approximately 90% derived from domestic sales to residential, , and customers, supplemented by sales and wheeling charges for services. reached $587 million, up from $323 million the prior year, though pressured by escalating operations and maintenance expenses amid higher energy costs and system demands. Net long-term debt increased to $32.049 billion as of March 31, 2025, from $29.294 billion the previous fiscal year, driven primarily by capital-intensive investments including the completion of the Site C Clean Energy Project. This debt is financed through provincial government guarantees, long-term bonds, and revolving credit facilities, supporting an . However, Fitch revised the outlook to negative on May 13, 2025, citing risks from a $32 billion capital plan through 2034, which accelerates spending on generation and transmission assets. Capital expenditures on mega-projects like Site C have pushed BC Hydro's beyond the targeted 60:40 threshold, resulting in no payments to the province for fiscal 2025 and heightening relative to peers. This elevated debt load, backed by provincial credit, imposes long-term fiscal burdens equivalent to implicit taxes on future taxpayers, as servicing costs are absorbed through government support rather than fully self-financing operations.

Electricity Rates and Consumer Costs

BC Hydro's residential electricity rates feature a tiered structure designed to encourage conservation, with a lower Step 1 rate of 11.72 Canadian cents per kilowatt-hour (¢/kWh) applied to the first 1,376 kWh of bimonthly usage, escalating to a Step 2 rate of 14.08 ¢/kWh for consumption beyond that threshold, as of July 2025. Customers also incur a basic daily service charge of $0.2330. This structure replaced an earlier inclining block model with a steeper penalty, though recent approvals introduced optional flat-rate alternatives at around 12.63 ¢/kWh for higher-usage households exceeding 1,100 kWh monthly. For 2025, the Utilities Commission (BCUC) approved an average bill increase of 3.75%, effective April 1, 2025, adding approximately $3.75 monthly to typical residential accounts, driven primarily by debt servicing costs from infrastructure expansions and rising operational expenses. This adjustment, mandated under provincial government direction to cap increases below cumulative , follows a 6.42% net rise in the prior and supports recovery of expenditures on imports and projects passed through to ratepayers via regulatory mechanisms. Large industrial customers receive discounted rates under programs like CleanBC Industrial Electrification, with incentives reducing effective costs below residential levels to promote grid connection and economic retention, funded in part by the overall rate base that includes higher residential contributions. Such cross-subsidization exposes residential users to from export sales, where surplus power is sold at prices that may not fully offset domestic supply costs, as evidenced by periods of low export revenues amid drought-driven imports. Relative to Alberta's deregulated , where competitive retailers offer fixed rates as low as 8.15–9.99 ¢/kWh, BC Hydro's regulated pricing—averaging 11–14 ¢/kWh post-tiers—imposes higher burdens on consumers, prompting critiques that monopoly oversight stifles and inflates costs for households and small businesses. BCUC approvals facilitating cost pass-through from megaprojects like Site C have amplified affordability pressures, with average monthly bills nearing $100 for moderate users amid demand growth from .

Economic Impacts and Subsidies

BC Hydro's supply of low-cost hydroelectric power underpins British Columbia's resource sectors, including , , (LNG), and , facilitating economic activity by providing reliable for industrial operations. The completion of the in 2025 adds approximately 1,100 megawatts of capacity, equivalent to powering 500,000 homes annually and boosting overall supply by 8%, which supports expanded industrial investments in the Peace region through enhanced local job creation and skills training programs funded at $1.5 million. Similarly, the North Coast Transmission Line (NCTL), expedited for in 2025 at an estimated cost of $6 billion, is projected to enable resource and projects by delivering clean to northern ports and mines, generating 9,700 direct full-time jobs and contributing nearly $10 billion annually to provincial (GDP), alongside $950 million in yearly public revenues. Despite these contributions, BC Hydro's structure as a provincially owned incurs opportunity costs, including inefficient capital allocation and debt accumulation that could otherwise fund private-sector efficiencies. Power purchase agreements (PPAs) with independent power producers (IPPs) have drawn criticism for market distortions, as BC Hydro has paid millions to IPPs to curtail production amid oversupply conditions, effectively subsidizing non-generation at ratepayer expense. In 2025, BC Hydro allocated $1 million through the Peace Agriculture Compensation Fund to two regional projects for handling and agrifoods development, aimed at offsetting Site C-related impacts but raising questions about targeted grants favoring specific interests over broader economic optimization. Advocates for reform, including analyses from the , contend that privatizing BC Hydro—restructuring it into a competitive pool akin to Alberta's deregulated model with private providers—could lower electricity rates, reduce $40 billion-plus in accumulated , and enhance by assigning existing PPAs and assets to market mechanisms rather than public stewardship. Alberta's system, while experiencing price volatility (e.g., rises from 7-10 cents per kWh in 2021 to 10-17 cents in 2022), demonstrates potential for innovation through competition, contrasting BC Hydro's monopoly-driven subsidies that critics argue entrench and hinder dynamic .

Regulation and Governance

BC Utilities Commission Oversight

The British Columbia Utilities Commission (BCUC) functions as the independent regulator for public utilities in the province, including BC Hydro, with authority to set rates, approve major capital expenditures, and evaluate the prudence of resource acquisition decisions to ensure safe, reliable service at just and reasonable prices. Established under the Utilities Commission Act, the BCUC mandates BC Hydro to adopt least-cost planning principles in its integrated resource plans, prioritizing options that minimize costs while meeting demand in an environmentally responsible manner. This oversight historically promoted fiscal discipline by requiring evidence that proposed investments represent the most economical path forward, subject to public scrutiny and evidentiary hearings. The BCUC's review processes for BC Hydro include assessments of power purchase agreements (PPAs) with , determining whether contract terms are prudent and avoid excessive ratepayer burdens. These evaluations often involve formal proceedings where the examines acquisition costs, profiles, and alignment with load forecasts; for example, a multi-year review of legacy IPP contracts concluded in 2022, affirming the need for ongoing prudence tests amid criticisms of over-reliance on high-cost non-hydro sources. Public input is integral, with open hearings allowing interventions from ratepayer groups, experts, and stakeholders to challenge assumptions and propose alternatives, fostering transparency in rate-setting applications. To mitigate rate volatility, BC Hydro employs deferral accounts for timing differences between recognized revenues, expenses, and cash flows, deferring items like forecast variances and recoveries for future amortization. As of February 2019, these accounts totaled $5.5 billion, reflecting accumulated deferrals from prior periods that the BCUC approves for gradual recovery through rates, though this practice has drawn scrutiny for potentially masking underlying cost pressures and deferring accountability to future consumers. The commission's approval of such mechanisms balances short-term against long-term financial , requiring BC Hydro to demonstrate that deferrals do not compromise overall .

Provincial Government Interventions

In September 2023, the government under Premier dismissed BC Utilities Commission (BCUC) chair David Morton over a year before his term ended, amid ongoing disputes over BC Hydro's proposed rate increases, which the commission had partially rejected. This action, followed by the appointment of Mark Jaccard as the new chair on September 14, 2023, was interpreted by former commissioners and analysts as eroding the BCUC's independence from political influence, particularly in regulating Crown-owned utilities like BC Hydro. The NDP government's interventions extended to legislative measures, exemplified by Bill 31, the Energy Statutes Amendment Act, introduced on October 20, 2025, which mandates BC Hydro to advance the $6-billion North Coast Transmission Line (NCTL) and enables agreements for co-ownership while prioritizing electricity allocation for projects, including data centers, in northwest . The bill scraps the prior policy of equal electricity distribution to customers, favoring sectors to attract investments, but critics, including the BC Greens, contend it circumvents BCUC oversight, potentially politicizing approvals and increasing fiscal risks without full regulatory scrutiny. Further directives shaped BC Hydro's 2025 Integrated Resource Plan (IRP), with provincial legislation under the Clean Energy Act compelling a focus on acquiring additional clean and renewable sources to achieve 100% clean energy supply, despite the utility's existing hydroelectric dominance supplying approximately 98% clean power. Government mandates, including the 2025 Call for Power launched in July 2025, prioritize non-hydro renewables and goals over cost-minimizing hydro expansions, effectively limiting comprehensive BCUC reviews of long-term planning to align with policy timelines. These actions have been linked to diminished regulatory , as evidenced by overrides on BC Hydro's requirements—such as a July 2024 directive to cap allowed income at government-set levels—and heightened vulnerability to cost overruns, mirroring the escalated expenses observed in the Site C project under accelerated political directives. Such interventions prioritize expedited development for economic and environmental objectives but compromise independent fiscal prudence, according to assessments from former regulators.

Performance Metrics and Accountability

BC Hydro's distribution system reliability, measured by the System Average Interruption Frequency Index () and System Average Interruption Duration Index (SAIDI), has consistently outperformed Canadian benchmarks over the past decade. From fiscal 2016 to 2025, the stood at 2.10 interruptions per annually, compared to Electricity Canada's of 2.66, while the SAIDI was 6.78 hours of outage per , against a national of 7.70 hours (excluding major events). These metrics reflect the operational provided by the utility's hydroelectric , where reservoir enables rapid reconfiguration to isolate faults and maintain supply continuity, resulting in lower outage frequencies and durations than systems reliant on less flexible or intermittent sources. Key performance indicators for generation efficiency include system-wide capacity factors, which for BC Hydro's owned hydroelectric assets typically range from 40% for run-of-river facilities to over 60% for reservoir-based plants, yielding an overall average around 50-60% due to seasonal water inflows and storage capabilities. However, the integration of (IPP) contracts, often involving lower-capacity-factor run-of-river projects (40-50%), dilutes effective output utilization across the broader supply portfolio, as these assets contribute less reliably during dry periods without equivalent storage redundancy. As a provincial , BC Hydro's mechanisms center on annual Service Plan Reports and reliability filings submitted to the BC Utilities Commission and the provincial government, detailing operational KPIs against planned targets. This structure ensures public reporting of metrics like reliability indices and generation performance but lacks the market-driven disciplines of private utilities, such as direct pressure for efficiency gains or divestitures of underperforming assets, potentially allowing directives to overshadow pure operational optimization.

Controversies

Cost Overruns and Non-Competitive Contracting

The Site C hydroelectric project, managed by BC Hydro, exemplifies significant cost overruns linked to non-competitive practices. Initially budgeted at $6.6 billion when approved in , the project's estimated cost escalated to $8.8 billion by formal sanction in 2014 and reached $16 billion by 2021, with completion targeted for late 2025. These overruns, totaling over $7 billion beyond the initial estimate, stem partly from geotechnical challenges and scope changes but have been exacerbated by procurement decisions that prioritized speed over market scrutiny. Between 2020 and 2022, BC Hydro awarded $430 million in direct, non-tendered contracts for Site C work to approximately three dozen companies and consultants, justified by claims of specialized expertise, project urgency, and accommodations. Among the recipients was firm SNC-Lavalin (now ), which secured over $62 million in such awards, including a single contract exceeding $25 million for geotechnical and design services—despite the firm's recent history of corporate malfeasance, including a guilty plea to charges in resulting in a $280 million fine and a prior World Bank debarment for from 2013 to 2021. BC Hydro later acknowledged failing to disclose an additional $128 million in these non-competitive contracts, primarily for work, attributing the omission to a "human error" in data reporting; the utility issued a public apology in August 2023 and corrected its records, revealing a broader $558 million in undisclosed direct awards over the same period. Non-competitive contracting at BC Hydro, as a provincially owned exempt from standard public tender disclosure rules, bypasses the competitive bidding mechanisms that enforce cost discipline in -sector projects. Political imperatives, such as rushed approvals under successive governments to affirm the project's viability amid mounting risks, accelerated without full evaluation, potentially allowing premiums of 20-50% over competitive rates as firms face no pressure to undercut rivals. This contrasts with infrastructure developments, where open tenders typically yield efficiencies through and vendor ; public-sector exemptions, while enabling speed, have invited criticism for eroding fiscal oversight and inflating taxpayer-funded expenditures. Independent audits, including those highlighting inadequate pre-qualification standards in Site C's early phases, underscore how such practices compound overruns in megaprojects lacking robust contestability.

Environmental and Indigenous Rights Disputes

The Site C Clean Energy Project has sparked disputes over its ecological footprint, including the permanent flooding of 5,550 hectares of Valley land, comprising agricultural fields, forests, and riparian habitats vital for . This inundation disrupts downstream sediment flows and nutrient cycling, altering aquatic and terrestrial ecosystems in a region already fragmented by prior dams. For , the submerges traditional territories promised under the 1899 treaty for hunting, , and , with a joint federal-provincial review panel concluding significant adverse effects on these rights, including reduced access to non-salmon fish species and big game populations. Legal challenges from affected nations, such as West Moberly and Prophet River , have alleged treaty violations due to inadequate consultation and unmitigated harms to cultural practices and , resulting in 2022 settlements providing compensation and offsets, though critics maintain these fail to restore pre-project conditions. In May 2016, the Royal Society of endorsed a by over 200 academics urging suspension of construction, highlighting procedural exemptions from utilities oversight and risks of irreversible damage, positions rejected by BC Hydro and the provincial government in favor of proceeding with environmental certificates issued in 2014. Fish mitigation efforts at Site C, including structures, face skepticism given evidence of recruitment failures in —a listed as endangered in the Nechako and systems—where block spawning migrations and fragment habitats, compounding declines observed post-upstream impoundments. BC Hydro's run-of-river contracts, exceeding 600 projects since 2002, have drawn criticism for diverting stream flows and installing weirs that strand and degrade habitats critical for salmonids, yielding intermittent power without storage to buffer ecological variability. While hydroelectric facilities like Site C emit approximately 10 grams of CO2 equivalent per over their lifecycle—contrasting sharply with 490 grams for —advocates for the projects emphasize avoided displacement in meeting baseload demand. Opponents counter that such metrics overlook causal chains of biodiversity and lost , arguing that hyped intermittent alternatives, despite higher emissions in some analyses, avoid the permanent hydrological shifts imposed by large-scale development.

Supply Reliability and Oversupply Payments

BC Hydro's supply reliability has been strained by variable hydro conditions, particularly droughts that reduce reservoir levels and generation capacity. In 2024, persistent drought conditions necessitated imports accounting for approximately 25% of the province's electricity supply, as domestic hydro output fell short during peak demand periods. Entering 2025, while drought effects eased somewhat, early-year snowpack levels remained at 72-73% of normal, limiting water availability for generation. La Niña conditions, forecasted to persist into early 2025 before transitioning to neutral, introduce additional risks through heightened storm activity and weakened vegetation from prior droughts, elevating outage probabilities across the grid. Forecasted demand growth exacerbates these reliability gaps, with of and projected to increase needs by 15% by 2030. The , scheduled for full operation in 2025, will add 1,100 megawatts of capacity—equivalent to about 8% of current supply—but experts warn it alone cannot meet the surge, particularly without complementary measures to address dry-year shortfalls. Pre-2020s planning underestimated this rapid demand escalation driven by policy mandates for EV adoption and industrial expansion, leaving the system vulnerable as connection queues swelled to over 7,000 megawatts of unserved requests by mid-2025. Conversely, oversupply scenarios arise during high-precipitation periods or low-demand events, where contracts with —primarily run-of-river hydro facilities—obligate BC Hydro to purchase power beyond immediate needs. In , amid COVID-19-reduced and ample water inflows, BC Hydro paid millions to IPPs to curtail and avoid spilling reservoir , as long-term power purchase agreements lacked sufficient flexibility for volume reductions. These payments stem from "take-or-pay" clauses in IPP contracts, which a 2019 provincial review criticized for inflating costs, with BC Hydro acquiring surplus energy at premiums exceeding $100 per megawatt-hour only to export or spill it at minimal value. Policy emphasis on renewable IPPs has fostered over-reliance on intermittent, non-dispatchable sources, heightening vulnerability without robust backups like market-priced thermal plants, which could provide flexible peaking capacity during deficits. Critics, including analyses from the Energy Futures Institute, argue that eschewing options in favor of hydro-centric expansion ignores causal risks from climate variability, as run-of-river IPPs falter in droughts while contractual rigidities prevent efficient curtailment in wet years, distorting supply-demand balance. This approach prioritizes emission reductions over operational resilience, potentially necessitating costlier imports or emergency measures amid growing loads.

Energy Policy and Sustainability

Renewable Initiatives and Calls for Power

Following the 2021 Integrated Resource Plan, which projected a 15% or greater increase in electricity demand by 2030 driven by of , , and heating, BC Hydro initiated diversification efforts to meet rising loads from clean sources beyond its traditional hydroelectric base. These plans emphasized acquiring additional through independent power producers (IPPs) rather than solely expanding owned assets, responding to updated load forecasts incorporating adoption and industrial growth. In the 2025 Call for Power, BC sought up to 5,000 gigawatt-hours (GWh) per year of new clean energy from privately developed resources, prioritizing , , and hybrid projects capable of delivering by the early 2030s. The request for proposals (RFP) process, building on the 2024 Call that received 21 submissions totaling over 9,000 GWh—more than three times the targeted acquisition—demonstrated strong developer interest in non- renewables. Selected projects from prior calls included nine facilities and one installation, adding approximately 5,000 GWh annually and diversifying supply while requiring integration with firm resources for reliability. Amid British Columbia's target by 2050, BC Hydro maintained focus on firm, dispatchable resources like to backstop variable outputs from and , as necessitates reservoir balancing or imports to avoid shortfalls during low-generation periods. The North Coast Transmission Line (NCTL), advanced post-2023 following expressions of interest from northwest industrial customers, enables hybrid developments in remote areas by expanding 500 kV lines from Prince George northward, unlocking over 3,000 megawatts of potential clean capacity tied to load growth in mining and LNG sectors. Hydroelectric generation continues to comprise over 90% of BC Hydro's supply mix, providing the stable backbone for integrating smaller-scale renewables without compromising system firmness, as evidenced by annual reports showing 91% hydro dominance alongside 3-4% from and . This empirical reliance on underscores the causal need for backups in diversified portfolios, where sources' output fluctuations elevate integration expenses through enhanced and coordination.

Conservation Programs and Demand-Side Measures

BC Hydro implements demand-side management () and conservation programs under its Power Smart initiative to reduce electricity consumption through incentives, rebates, and behavioral measures, positioning these as lower-cost alternatives to expanding generation capacity. These efforts target residential, , and sectors with rebates for high-efficiency appliances, , , and building retrofits, aiming to defer or avoid new supply investments by optimizing existing demand. Since 2008, the programs have achieved cumulative energy savings exceeding 7,000 gigawatt-hours (GWh), equivalent to the annual consumption of over 700,000 households. Annual incremental savings from DSM initiatives have consistently met or exceeded targets, with fiscal 2024 results showing 27 GWh/year above planned levels, representing a 5% overachievement relative to the fiscal 2023-2025 revenue requirements application. Overall, these programs contribute approximately 2,000 GWh in annual avoided use, sufficient to around 200,000 homes, through measures like strategic for large commercial users consuming over 2 GWh annually. Residential consumption has declined by about 12% since the early , partly attributable to rebate-driven efficiency upgrades and time-of-use pricing signals that encourage load shifting. The rollout of smart meters in the early 2010s facilitated real-time demand monitoring and targeted DSM interventions, such as dynamic pricing and automated load control, enhancing program precision by providing granular usage data. However, the installation process, which began around 2011, drew criticism for inadequate customer notification on data collection practices, leading to a 2011 finding by British Columbia's Information and Privacy Commissioner that BC Hydro violated privacy obligations under the Freedom of Information and Protection of Privacy Act by failing to inform affected households. Despite encryption and security protocols akin to online banking, ongoing concerns about data security and potential grid vulnerabilities persisted into the decade. In 2025, emphasis has shifted toward integrating customer-owned via the self-generation program (formerly ), allowing credits for excess production up to the customer's annual demand while exporting surplus at avoided rates to mitigate strain. System size limits, typically under 100 kilowatts for residential and small commercial setups, reflect integration constraints to prevent reverse power flows that could overload local distribution during peak output, with recent updates increasing allowable capacities but requiring annual credit payouts to align incentives with utility . Rebates for paired and cap at 50% of project (up to $5,000), prioritizing self-consumption to minimize net exports amid rising demands. DSM measures demonstrate cost-effectiveness, with program costs evaluated against BC Hydro's long-run (LRMC) of approximately 7 cents per for new non-emitting supply, yielding positive utility cost tests as savings avoid pricier additions estimated at 8-10 cents per . Fiscal 2025 activities reported expenditures of $107.4 million for the prior year, delivering savings at rates below LRMC through scalable rebates and audits, though actual per- costs vary by initiative with simple paybacks often under two years at average rates of 6.6 cents per . This approach has deferred equivalent new builds, underscoring efficiency's role in balancing supply without proportional expense.

Critiques of Policy-Driven Expansions

Critics of BC Hydro's policy-driven expansions contend that the emphasis on (IPP) projects, particularly run-of-river hydro and facilities, has ignored the inherent low dispatchability of these renewables, which generate power unpredictably and cannot be readily curtailed without economic loss during periods of high hydroelectric output. This has led to oversupply scenarios where BC Hydro pays IPPs millions annually to halt production, as run-of-river and operations are difficult to throttle compared to storage-based hydro. A provincial review highlighted how government-mandated acceleration of IPP contracting under the 2007 Clean Energy Act resulted in uneconomic long-term purchase agreements, forcing BC Hydro to acquire surplus power at above-market rates and exposing ratepayers to an estimated $16 billion in overpayments over 20 years for not required to meet demand. Integrated Resource Plans (IRPs), such as the 2021 iteration, have faced scrutiny for downplaying investments in upgrades to existing hydroelectric —potentially adding up to 5% more capacity through refurbishments—in favor of diversifying into intermittent sources like and to meet symbolic policy goals for renewables penetration. Empirical assessments underscore hydro's superiority in British Columbia's wet, mountainous climate, where large-scale storage reservoirs enable high s (typically exceeding 50%) and dispatchable output, contrasting with average 30% capacity factor and minimal viability due to limited insolation. Policy prioritizations have thus elevated less reliable options, contributing to rate pressures—exacerbated by Clean Energy Plan mandates imposing hundreds of millions in avoidable costs—without delivering proportional emissions reductions or system resilience during droughts when imports spike to cover peaks. Guaranteed pricing and subsidies for renewables have distorted market signals, crowding out private investment in hydro enhancements or other dispatchable innovations better aligned with BC Hydro's needs, as evidenced by the program's evolution into a $58 billion contractual that prioritizes policy optics over fiscal prudence. This approach, critics argue, reflects an overreliance on non-firm generation in a hydro-dominant , amplifying vulnerabilities to variability rather than leveraging empirical advantages of controllable resources.

References

  1. [1]
    About us - BC Hydro
    BC Hydro is a provincial Crown corporation, owned by the government and people of British Columbia, Canada. We generate and deliver electricity to 95% of the ...
  2. [2]
    [PDF] BC Hydro Quick Facts 2023/24
    BC Hydro provides electricity to 5,000,000 people, serving 95% of the province, with 90% from clean/renewable sources. Average household uses 10,000 kWh ...
  3. [3]
    Our history - BC Hydro
    BC Hydro was created in 1962 when the government of BC, under Premier WAC Bennett, passed the BC Hydro Act.
  4. [4]
    Operations - BC Hydro
    Learn where our dams are across BC. Over 80% of our installed generating capacity is at hydroelectric installations in the Peace and Columbia river basins.
  5. [5]
    Our system - BC Hydro
    We have 30 hydroelectric plants and a network of over 80,000 kilometres of power lines that transport electricity from our generating stations over mountain ...
  6. [6]
    BC Hydro and Power Authority - Province of British Columbia
    Jun 24, 2025 · The BC Hydro and Power Authority is a Crown corporation responsible for generating, purchasing, distributing and selling electricity.
  7. [7]
    Projects - BC Hydro
    Learn about the major capital projects in your area by navigating through the list of regions below. Search for projects by region.<|separator|>
  8. [8]
    Independent projects history & maps - BC Hydro
    BC Hydro acquires power from Independent Power Producers (IPPs) to help meet B.C.'s electricity needs. IPPs develop and operate projects such as wind, water and ...
  9. [9]
    [PDF] British Columbia Hydro And Power Authority First Annual Report C file
    The Authority was constituted on 30 March 1962 by the amalgamation of British Columbia Electric Company Limited and British Columbia Power Commission pursuant ...
  10. [10]
    B.C. Hydro - Northwest Power and Conservation Council
    BC Hydro serves 1.6 million customers, or about 94 percent of the population of the province, and also operates 44,640 miles (72,000 kilometers) of transmission ...
  11. [11]
    Columbia River Treaty - Northwest Power and Conservation Council
    If the Treaty is terminated, BC Hydro would operate Mica, Keenleyside, and Duncan dams for Canadian power benefits, except for called-upon flood control and ...
  12. [12]
    Mica Dam and Kinbasket Lake - USACE Northwestern Division
    Sep 29, 2015 · Mica Dam was built in 1973. Mica Dam, which forms Kinbasket Lake was built as one of three Canadian projects under the terms of the 1964 ...
  13. [13]
    Mica Dam at 50 years - How an international treaty changed the face ...
    Apr 8, 2023 · The dam began operations on March 29th, 1973, and in the years that followed, the lush valley south of Valemount would transform from an age-old ...
  14. [14]
    [PDF] The Columbia River Treaty Revisited
    A third B.C. Hydro project on the Columbia. River was completed at Revelstoke in 1983. The reservoir for this new facility needed to be coordinated with that ...
  15. [15]
    Our Hydroelectric Heritage | Site C
    Over time, our hydroelectric capacity grew from about 500 megawatts (MW) in the early 1960s to several times that by the late 1980s. B.C. became recognized as ...
  16. [16]
    Our Facilities - BC Hydro
    Columbia Region. A quarter of BC Hydro's power comes from the Mica, Revelstoke and Hugh Keenleyside dams on the Columbia River.Lower Mainland and Coast · Columbia Region · Peace Region · Vancouver IslandMissing: expanded 1990s 2000s
  17. [17]
    Columbia River Treaty - United States Department of State
    ... Treaty projects—Keenleyside (also known as Arrow), Duncan and Mica dams—and from Libby Dam in the United States. These projects together are collectively ...
  18. [18]
    Efforts to modernize the Columbia River Treaty provide an ...
    Aug 27, 2024 · A dam holds back a lake under a blue sky. The four treaty dams are the Duncan Dam, Mica Dam and Keenleyside Dam in B.C. and the Libby Dam in ...
  19. [19]
    Partnering in Power Development In British Columbia
    May 1, 2009 · Arrow Dam (later renamed Hugh Keenleyside Dam) was completed in 1968; Duncan Dam on the Kootenay River was completed in 1970; Mica Dam on the ...<|separator|>
  20. [20]
    The Deregulation Zombie Rises Again in Texas - CCPA
    Mar 3, 2021 · There was significant pressure on the BC government to follow the US model. Afraid of public backlash if it privatized BC Hydro, in the early ...
  21. [21]
    [PDF] The Evolution of British Columbia's Industrial Electricity Policy
    BC Hydro sold 13,375 GWh of energy to industrial customers in 1990. This increased 11 per cent to 14,894 GWh in 1999. Year-over-year industrial demand slowed ...
  22. [22]
    BC Government Overrules Independent Regulator and Lines ...
    Oct 29, 2009 · The BC government has come under intense criticism since the introduction of the BC Energy Plan in 2002 which prohibited BC Hydro from producing ...
  23. [23]
    [PDF] SERVICE PLAN 2002/2003 – 2004/2005 - BC Budget
    Feb 6, 2002 · Market restructuring in the Pacific Northwest electricity sector has provided for the growth of independent power producer project development ...
  24. [24]
    Independent power projects a gift to private industry and a curse to ...
    Aug 5, 2013 · More than 70 contracts were signed with independent power producers in 2010, the last call for independent energy contracts. In 2011-12, BC ...
  25. [25]
    [PDF] Zapped - Gov.bc.ca
    Feb 11, 2019 · A run-of-river project may have rated capacity of 100 MW and will typically generate that maximum power at spring freshet (at the same time as ...Missing: criticisms | Show results with:criticisms
  26. [26]
    Run of River Power - Energy BC
    Without a dam for storing water, there is no stored power. This means the capacity factor of run of river projects varies between 40% and 80%. By comparison ...Run of River Power · How it Works · Geography · EconomicsMissing: criticisms | Show results with:criticisms
  27. [27]
    On the “shocking” revelations in the BC Hydro IPP review and the ...
    Feb 13, 2019 · To put it bluntly BC Hydro, in 2019, is suffering because they are ahead of the curve and got locked into intermittent renewables which is ...Missing: criticisms | Show results with:criticisms
  28. [28]
    Previous government's BC Hydro contracts to cost ratepayers billions
    Feb 13, 2019 · BC Hydro's energy planning should be able to rely on a reasonable level of Powerex trading and not reflect the need for insurance energy.
  29. [29]
    EXCLUSIVE: BC Hydro Paying Millions to Independent Power ...
    "According to BC Hydro they are losing $1.4 billion in IPP power." in about a decade, putting massive amounts of power into the system."Missing: percentage | Show results with:percentage
  30. [30]
    Generation System - BC Hydro
    We generate over 43,000 gigawatt hours of electricity annually to supply more than 1.9 million residential, commercial and industrial customers. Over 80% of BC ...
  31. [31]
    Columbia Region - BC Hydro
    The Columbia region is also home to four smaller hydroelectric generating stations with generating capacity of 233.4 MW. These stations are Waneta, Shuswap ...
  32. [32]
    Mica Units 5 & 6 Projects - BC Hydro
    In 2011, we started the Mica 5 and 6 Project to install two new 500 megawatt generating units to the two empty bays in the powerhouse.
  33. [33]
    Peace Region - BC Hydro
    Total capacity: About 3,424 MW, 29 per cent of BC Hydro's total capacity. Total power generated: The combined power from the Peace region facilities averages ...
  34. [34]
    [PDF] Columbia River Operations Summary - BC Hydro
    The Canadian Entitlement varies from year to year, but is currently about 3,990 gigawatt hours (GWh) per year of energy and 1,141 megawatts (MW) of capacity for ...<|separator|>
  35. [35]
    Lower Mainland and Coast - BC Hydro
    Built: The original powerhouse, the oldest in BC Hydro's system, came into service in 1904, and was replaced in 1951. A second powerhouse, Buntzen No. 2, was ...
  36. [36]
    Seismic hazards & our dams - BC Hydro
    BC Hydro has for many decades assessed seismic hazards at our dams and related facilities, and seismic upgrades are ongoing. A 2013 independent external audit ...Missing: aging | Show results with:aging
  37. [37]
    B.C. powering southern Interior growth with clean, affordable electricity
    Jul 29, 2024 · About $1.2 billion will go toward improvements to the La Joie dam facility on the Bridge River to address aging infrastructure and seismic ...
  38. [38]
    [PDF] Independent Power Producer (IPP) Supply List - BC Hydro
    Apr 1, 2025 · * Ocean Falls is an IPP in the Non-Integrated Area which, as of 2019, provides a regulated service to BC Hydro.<|separator|>
  39. [39]
    [PDF] Illustrative Evaluation Price Adjuster Formulas - BC Hydro
    Jan 17, 2024 · Annual Capacity. Factor. Peak Capacity. Factor. Wind. 36%. 24 %. Solar. 19%. 0 %. Run of River Hydro. 38%. 15 %. Small Storage Hydro. 52%. 71 %.Missing: IPPs | Show results with:IPPs
  40. [40]
    How BC Hydro incentivizes independent power producers
    Dec 16, 2024 · Looking at the last fiscal year 2023/24 which ended in March 2024, BC Hydro paid on average $101/MWh on purchases from IPPs. The levelized cost ...Missing: above | Show results with:above
  41. [41]
    Statement: BC Hydro secures Electricity Purchase Agreements with ...
    Feb 12, 2025 · The weighted average levelized price for these successful projects is $74 per megawatt hour (2024), which is around 45 per cent lower than the ...
  42. [42]
    2025 Call for Power - BC Hydro
    New to the 2025 Call is the First Nations Clean Energy Representative, a resource to help ensure that First Nations are meaningfully informed, supported and ...
  43. [43]
    BC Hydro 2025 Call for Power: Overview of Request for Proposal ...
    Aug 7, 2025 · The RFP aims to acquire up to 5,000 GWh/year of electricity from large, clean or renewable projects through partnerships between First Nations ...
  44. [44]
    https://www.bchydro.com/content/dam/BCHydro/customer-portal/documents/corporate/independent-power-producers-calls-for-power/call-for-power/2025-cfp-rfp-informational-meeting.pdf
  45. [45]
    [PDF] NORTHWEST - CANADA - BC Hydro
    Flow cannot exceed 2000 MW on both Custer-. Ingledow lines 1&2 (Westside Intertie) or 400 MW on the Boundary-Nelway line. (one of the two Eastside Interties).
  46. [46]
    [PDF] British Columbia - BC Hydro
    South to North: Up to 2000 MW (all ties). Flow cannot exceed 2000 MW on both Custer-Ingledow lines 1&2 (Westside Intertie) or 400 MW on the. Boundary ...
  47. [47]
    Market Snapshot: Which states trade electricity with British Columbia?
    Nov 28, 2023 · Electricity exported from Canada via BC mainly goes to California, Washington, and Oregon (Figure 1). Electricity imported from the US to BC also mainly comes ...
  48. [48]
    Importing and exporting power - BC Hydro
    One of B.C.'s electricity trading partners is Alberta. Electricity exports from B.C. can help to reduce greenhouse gas emissions there. Our clean energy ...
  49. [49]
    B.C. plans for future without U.S. electricity | The Narwhal
    Mar 6, 2025 · “We made almost a billion dollars selling electricity to the United States last year, so [cutting off exports to the U.S.] will have significant ...
  50. [50]
    Market Snapshot: British Columbia Uses its Hydro System to ... - CER
    Nov 28, 2023 · h. 1. B.C. firms sold these exports for $388 million and purchased these imports for $306 million, resulting in net export revenue of $82 ...
  51. [51]
    U.S. electricity exports to Canada have increased since September ...
    Nov 12, 2024 · British Columbia's total electricity exports to the United States, which include exports from BC Hydro, declined by 45% in 2023 from 2022. From ...
  52. [52]
    British Columbia's evolving electricity trade with the United States
    May 12, 2024 · BC profits much from exporting to California right through 2022. However, the picture changes in 2022 and 2023, when BC also benefits from ...
  53. [53]
    BC Hydro imported a quarter of the province's power in the last 12 ...
    Nov 28, 2024 · According to documents filed with the B.C. Utilities Commission, BC Hydro imported 13600 gigawatt hours of electricity in fiscal year 2024, ...
  54. [54]
    Record Electricity Imports Cost BC Hydro Almost $1.4 billion
    According to documents filed with the BC Utilities Commission (BCUC), BC Hydro spent more than $1.377 billion on imported electricity in a 12-month period.
  55. [55]
    [PDF] 2024/25 Annual Service Plan Report - BC Hydro
    Aug 13, 2025 · The Company's debt comprises bonds and ... In addition, the Company's debt is either held or guaranteed by the Province (see Note 18).
  56. [56]
    Site C Clean Energy Project - BC Hydro
    Site C will provide 1,100 megawatts (MW) of capacity, and produce about 5,100 gigawatt hours (GWh) of electricity each year – enough energy to power the ...
  57. [57]
    Project Overview | Site C
    Site C will be a source of affordable power to meet B.C.'s future electricity needs, and we expect to require the energy and capacity from Site C by about 2030.Missing: annual estimate
  58. [58]
    Site C project comes into full operation - BC Hydro
    Aug 9, 2025 · With all six units now in service, Site C has the capacity to generate more than 1,100 megawatts of electricity, and enough energy to reliably ...Missing: estimate | Show results with:estimate
  59. [59]
    BC Hydro receives strong response to call for clean electricity to ...
    Sep 18, 2024 · Electricity demand in B.C. is expected to increase by 15% or more between now and 2030. BC Hydro has kept rate increases below the rate of ...Missing: necessity | Show results with:necessity
  60. [60]
    [PDF] SITE C CLEAN ENERGY PROJECT - Gov.bc.ca
    Feb 15, 2021 · BC Hydro conducted extensive engineering studies into the geology of the Site C project area – including the dam site – for decades prior to ...
  61. [61]
    Site C dam was in serious trouble over a year ago: FOI docs
    Oct 21, 2020 · The belated BC Hydro reports said the Site C dam faces unknown cost overruns, schedule delays and such profound geotechnical troubles that its ...
  62. [62]
    North Coast electrification and economic development - BC Hydro
    Our proposed schedule is for North Coast Transmission Line Phase 1 (Prince George to Glenannan Transmission) to be in operation by Fall 2030 and Phase 2 ( ...
  63. [63]
    North Coast Transmission Line (NCTL) | BC Energy Regulator (BCER)
    An approximately 145 km line from Telkwa substation to Skeena substation. For more information, visit the BC Hydro NCTL Phase 2 page. Additional infrastructure ...
  64. [64]
    https://news.gov.bc.ca/releases/2025ECS0044-001032
  65. [65]
    https://thetyee.ca/News/2025/10/21/BC-Fast-Tracks-North-Coast-Transmission-Line/
  66. [66]
    https://vancouversun.com/news/bc-introduces-legislation-expedite-north-coast-transmission-line-halt-construction-ai-data-centres-explained
  67. [67]
    BC Hydro expands Clayburn Substation to support Fraser Valley ...
    Sep 29, 2025 · This critical infrastructure upgrade will boost the substation's capacity by 50 per cent, enhance reliability and deliver clean energy to ...
  68. [68]
    B.C. powering growth in the Fraser Valley with clean electricity
    Clayburn substation in Abbotsford, powering up to 17,500 additional homes by 2028; and; Mount Lehman substation in Abbotsford, powering up to 35,000 more ...
  69. [69]
    https://www.bchydro.com/news/press_centre/news_releases/2025/jervis-inlet.html
  70. [70]
    Jervis Inlet and Agamemnon Channel Power Line Replacement ...
    The 138 kV power line marine crossings will be upgraded to 230 kV standards by spring 2027.
  71. [71]
    https://www.cbc.ca/news/canada/british-columbia/bc-ai-power-centres-9.6946054
  72. [72]
    BC Hydro completes upgrades to one of B.C.'s largest power ...
    Mar 28, 2016 · Mica produces power for more than 650,000 homes each year. The two new generating units increase Mica's capacity by about 1,000 megawatts, ...
  73. [73]
    $$714-million Mica Dam upgrades boost B.C.'s ability to produce power
    Mar 28, 2016 · The $714-million upgrades significantly boosted the crown corporation's ability to generate power. “It represented about a 10 per cent increase ...
  74. [74]
    [PDF] John Hart Dam Seismic Upgrade Project Application - BC Hydro
    Dec 20, 2021 · BC Hydro is filing the attached application to the BCUC, pursuant to section 44.2 of the. Utilities Commission Act, for the John Hart Dam ...
  75. [75]
    BC Hydro begins major seismic upgrade at Ladore Dam
    Jan 30, 2025 · BC Hydro has begun work to enable seismic upgrades at Ladore Dam, near Campbell River, marking a major milestone for dam safety projects on Vancouver Island.Missing: reinforcements | Show results with:reinforcements
  76. [76]
    https://www.mypowellrivernow.com/62115/news/community/bc-hydro-completes-marine-power-line-removal-at-jervis-inlet-2/
  77. [77]
    [PDF] INDEPENDENT AUDIT OF CAPITAL ASSET MANAGEMENT IN BC ...
    BC Hydro's assets are typically costly to renew or replace, even though the return in service life is long. Electricity-generating assets, for example, have ...
  78. [78]
    [PDF] BC Hydro quick facts
    Generation capacity figures may vary slightly from those stated in BC Hydro's Annual Service Plan Report. Operating statistics for the years ended or as at ...Missing: key | Show results with:key
  79. [79]
    [PDF] BC Hydro 2024/2025 Third Quarter Financial Report
    Mar 31, 2025 · BC Hydro's net income was $210M for 3 months and $324M for 9 months. Total revenues were $1.96B and $5.32B, respectively. Net regulatory asset ...
  80. [80]
    Fitch Revises BC Hydro's Outlook to Negative; Affirms at 'AA+'
    May 13, 2025 · Fitch has also affirmed BC Hydro's Long-Term Issuer Default Rating (IDR) at 'AA+', Short-Term IDR at 'F1+', and senior unsecured debt at 'AA+'.Missing: FY2025 | Show results with:FY2025
  81. [81]
    [PDF] 2025/26 first quarter report for the three months ended ... - BC Hydro
    Jun 30, 2025 · Net loss for the three months ended June 30, 2025 was $53 million, $98 million lower than the net income of $45 million in the same period in ...
  82. [82]
    Residential Energy Rates - BCUC
    Jun 26, 2025 · BC Hydro Electricity Rates · Basic charge = $0.2330 per day · Step 1 energy charge (first 1376 kilowatt hours (kWh))1 = $0.1172/kWh · Step 2 energy ...Missing: structure | Show results with:structure
  83. [83]
    Canada Electricity Rates – July 2025 | Off-Grid Solar Savings Analysis
    Jul 22, 2025 · Latest Rate (¢/kWh), Source / Notes. British Columbia, BC Hydro: 11.72¢ (Step 1), 14.08¢ (Step 2); FortisBC: 14.96¢, BCUC, as of July 1, 2025.
  84. [84]
    BCHydro flat rate vs tired vs TOU : r/britishcolumbia - Reddit
    Apr 2, 2025 · Flat is 12.63 cents/kwh (need to use > 1100 kwh/mo for any savings) Tiered is 11.72 to 14.08 (note no more 50% surcharge here, the 14.08 is frozen)
  85. [85]
    Electrification trumps affordability as BC Hydro abandons its two-tier ...
    Mar 3, 2025 · Electrification trumps affordability as BC Hydro abandons its two-tier residential rate structure. By. Richard Mason. Published. March 3, 2025.
  86. [86]
    Revenue requirements - BC Hydro
    In March 2025 BC Hydro filed a two-year Revenue Requirements Application for Fiscal 2026-2027 with the BCUC, requesting an annual average bill increase of 3.75% ...
  87. [87]
    New direction ensures affordable, stable electricity rates
    Mar 17, 2025 · The rate increases will take effect April 1, 2025, and April 1, 2026. Through the rate stability direction and other actions, the B.C. ...
  88. [88]
    [PDF] BC Hydro - Electricity Rate Comparison Annual Report No. 17
    Feb 18, 2025 · For BC Hydro, the report uses a net bill increase of 2.3% which is calculated based on the approved final rate increase for fiscal 2025 of 6.42% ...
  89. [89]
    Industrial electrification rates - BC Hydro
    The CleanBC Industrial Electrification Rates are intended to help existing and new industrial customers connect to BC Hydro's grid by offering discounted rates.Missing: cross | Show results with:cross
  90. [90]
    Residential power users to subsidize industrial customers
    Jul 21, 2013 · BC Hydro's own figures show that Site C's power will cost upward of 10 cents per kilowatt hour and industrial users currently pay less than 4 ...
  91. [91]
    Here's What Alberta Electricity Rates Look Like Right Now
    Fixed electricity rates in Alberta ; ¢8.23. Compare to Floating Rates. ¢9.99 ; ¢8.57. Compare to Floating Rates. ¢10.08 ; With 2-Year Natural Gas Bundle. ¢8.15.
  92. [92]
    My Alberta electric bill... In BC, the same usage would have cost just ...
    Feb 20, 2022 · 540 votes, 223 comments. Current bc hydro rates are: Step 1 rate (up to 1376 kWh): $0.0939/kWh Step 2 rate (above 1376 kWh): $0.1408/kWh ...Real electricity price : r/alberta - RedditWhat is a decent rate to pay for electricity in Alberta at present time?More results from www.reddit.com
  93. [93]
    BC Hydro balances affordability with essential infrastructure ...
    Mar 31, 2025 · The BC Utilities Commission issued orders as required by this direction on March 26, 2025, establishing a 3.75 per cent annual rate increase for ...Missing: cross subsidies
  94. [94]
    B.C. boosts clean-energy supply, drives economic growth
    Jul 28, 2025 · BC Hydro plans to award electricity purchase agreements to selected projects in early 2026. “Through collaboration with government, First ...
  95. [95]
    [PDF] ECONOMIC BENEFITS - Site C
    To help increase the availability of local labour, BC Hydro has invested approximately $1.5 million in a number of skills and trades training programs. The ...
  96. [96]
    https://dailyhive.com/vancouver/north-coast-transmission-line-nctl-bc-hydro-expedited-construction
  97. [97]
    BC Hydro Agricultural Fund Approves $1 Million in Funding for Two ...
    Sep 16, 2025 · This project will streamline the loading and blending of fertilizer for agriculture producers in the Buick Creek, Prespatou and Montney areas.
  98. [98]
    [PDF] The Case of BC Hydro: A Blueprint for Privatization - Fraser Institute
    This means that wheeling, paid power transmission will enable clients to buy from BC Hydro, other BC produc- ers, Alberta, or the United States, on the basis.
  99. [99]
    [PDF] Electricity Systems Across Western Canada
    Jun 15, 2023 · Alberta, in contrast, has no government ownership of assets, allows competition for some functions and has private sector electricity providers ...Missing: debate | Show results with:debate
  100. [100]
    What's Behind the Surge in Alberta's Electricity Prices | The Tyee
    Sep 28, 2023 · In 2021, electricity prices in Alberta ranged from seven to 10 cents per kilowatt hour. In 2022, prices increased to between 10 and 17 cents per kWh.
  101. [101]
    Long-term electricity planning - BC Hydro
    ... least cost electricity supply in an environmentally responsible manner. BC Hydro uses the Action Plan in assigning work plans and priorities from year to year.
  102. [102]
    BCUC Review of BC Hydro Independent Power Producer Agreements
    BC Utilities Commission. Review of BC Hydro Independent Power Producer Agreements. Completed: 2022. Hearing and Other Documents ...Missing: PPAs prudence
  103. [103]
    Proceedings - BCUC
    The BCUC reviews applications from regulated entities through open, transparent, public proceedings. ; BC Hydro, Electricity Purchase Agreement Renewal for ...
  104. [104]
    Customers on the hook for $5.5 billion in deferred BC Hydro ... - CBC
    Feb 6, 2019 · Auditor General Carol Bellringer says BC Hydro has deferred $5.5 billion in expenses that it plans to recover from ratepayers in the future.Missing: accumulation | Show results with:accumulation
  105. [105]
    Eby has destroyed the independence of B.C. Utilities Commission
    The New Democrats have revoked the independent oversight of B.C. Hydro in the two years since Premier David Eby fired the chair ...
  106. [106]
    BC Utilities chair fired, signalling major changes to energy law
    Sep 25, 2023 · Premier David Eby's cabinet announced last week it had removed BC Utilities Commission chair David Morton, more than a year before his term was ...
  107. [107]
    New chair, CEO appointed to BC Utilities Commission - BC Gov News
    Sep 14, 2023 · Mark Jaccard has been appointed chair and CEO of the BC Utilities Commission (BCUC), effective Thursday, Sept. 14, 2023.<|separator|>
  108. [108]
    [PDF] How Independent is the BCUC's Oversight of BC Hydro?
    Jul 25, 2024 · In September 2023 the government fired the BCUC chair over a year before the end of his term, with no evidence of a merit-based process to ...
  109. [109]
    https://thenarwhal.ca/bill-31-bc-north-coast-transmission-line/
  110. [110]
    https://www.theglobeandmail.com/canada/british-columbia/article-bc-to-scrap-rule-to-provide-electricity-equally-to-industrial/
  111. [111]
    Bill 31 - Legislative Assembly of British Columbia
    1 The Hydro and Power Authority Act, R.S.B.C. 1996, c. 212, is amended by adding the following section: North Coast transmission line ownership agreements.Missing: NCTL | Show results with:NCTL
  112. [112]
    https://bcgreens.ca/bill-31-writes-another-blank-cheque-and-weakens-public-oversight/
  113. [113]
    https://www.mynorthokanagannow.com/3077/news/provincial/b-c-government-proposes-more-legislation-to-fast-track-north-coast-power-project-with-first-nations/
  114. [114]
    [PDF] 2025 IRP engagement - Action items and responses to ... - BC Hydro
    BC Hydro has been supplied by approximately 98% clean energy in recent times, but we will be required to get to 100% clean energy based on the recent changes ...
  115. [115]
    The independence of the BCUC again ignored by the Eby cabinet
    Jul 24, 2024 · Premier David Eby has again interfered in the independent BC Utilities Commission, ordering the regulator to hold BC Hydro's income at a cabinet-approved level.Missing: revocation | Show results with:revocation
  116. [116]
    BC Hydro is no longer being independently regulated by the BCUC
    Sep 21, 2025 · The BCUC's role is to set public utilities' rates and approve investments according to regulatory principles, using a fair and transparent ...
  117. [117]
    [PDF] 2025 Annual Reporting of Reliability Indices (May 15 ... - BC Hydro
    May 15, 2025 · BC Hydro's average SAIFI performance from fiscal 2016 to fiscal 2025 is 2.10, which is better than the Electricity Canada average SAIFI of 2.66 ...
  118. [118]
    Annual reports - BC Hydro
    Aug 28, 2025 · BC Hydro's 2024/2025 Annual Service Plan Report was published on August 28, 2025, and includes performance, financial results, and a Fiscal ...Missing: breakdown | Show results with:breakdown
  119. [119]
    Site C Dam – Why Do Projects Fail? - Calleam Consulting
    Jun 14, 2023 · The Site C Dam project faces environmental concerns, cost overruns, and potential strategic misrepresentation, leading to tarnished credibility.
  120. [120]
    Site C dam budget nearly doubles to $16B, but B.C. NDP forging on ...
    Feb 26, 2021 · The Site C dam on the Peace River in northeastern BC is estimated to cost about $16 billion, nearly double the originally approved budget of $8.8 billion in ...
  121. [121]
    Site C report unlikely to get to the bottom of overruns - Vancouver Sun
    Oct 17, 2025 · The project budget soared from $8 billion at the outset to $16 billion. Two years into construction, a confidential report from Deloitte ...
  122. [122]
    BC Hydro secretly handed out $430 million in Site C dam contracts
    Apr 26, 2023 · SNC-Lavalin was among the big winners of BC Hydro's recent no-bid contracts for work on the Site C dam, The Narwhal has learned.
  123. [123]
    BC Hydro apologizes for $128-million Site C dam data error
    Aug 30, 2023 · BC Hydro has apologized for failing to disclose more than $128 million in contracts it awarded without competition for the Site C dam.
  124. [124]
    [PDF] BC Hydro - Site C Clean Energy Project – Infrastructure risk and cost ...
    Sep 13, 2016 · The Site C project team supports contract delivery by acting as project and interface manager between proponents. Since the beginning of Site ...<|separator|>
  125. [125]
    BC Government approves the Site C Dam – the fight continues!
    Dec 17, 2014 · BC Hydro would be building its third dam on the Peace River, flooding 5,550 hectares of land over an 83-kilometre stretch of valley. Site C ...
  126. [126]
    Site C Clean Energy - Environmental Impact Statement ( EIS )
    Mar 1, 2019 · Site C Clean Energy Project - Environmental Impact Statement (EIS) (Submitted by BC Hydro to the British Columbia Environmental Assessment ...
  127. [127]
    [PDF] The Treaty 8 First Nations and BC Hydro's Site C Dam
    The report of the. Joint Review Panel6 on Site C found—in disagreement with BC Hydro—that the project would have significant adverse effects on fishing ...<|control11|><|separator|>
  128. [128]
    Treaty 8 First Nations file lawsuits to protect sacred lands, stop Site ...
    Jun 29, 2015 · Treaty 8 First Nations have commenced proceedings in both the BC Supreme Court and the Federal Court of Canada challenging the federal and provincial ...Missing: disputes | Show results with:disputes
  129. [129]
    West Moberly First Nations, B.C., BC Hydro and Canada reach ...
    Jun 27, 2022 · The Province of British Columbia, BC Hydro, Canada and West Moberly First Nations have negotiated a settlement related to the Site C project.Missing: disputes | Show results with:disputes
  130. [130]
    Royal Society of Canada, academics, call Site C dam a test for ...
    May 24, 2016 · The Royal Society of Canada is joining some 250 academics in calling on the Liberal government to stop development on British Columbia's ...
  131. [131]
    [PDF] Environmental, social, and governance progress report - BC Hydro
    Aug 30, 2024 · BC Hydro is a provincial Crown corporation, owned by the Government of B.C., Canada. ... To demonstrate our accountability, we share.<|control11|><|separator|>
  132. [132]
    Dams trigger exponential population declines of migratory fish
    May 10, 2024 · However, the failure of the FRPs provides a rare opportunity to examine the true impact of dams on migratory fish. Dams can harm migratory fish ...
  133. [133]
    Potential Impacts of Run-of-River Power Hydroprojects on Salmonids
    Each hydroXelectric project in BC will also be associated with an environmental cost. The scale of impact can vary greatly from large reservoirs flooding ...
  134. [134]
    [PDF] The Environmental Impacts of Run-of-River Hydroelectric Projects in ...
    Apr 8, 2015 · Also, BC Hydro has signed 21 more EPA's with run-of-river IPPs that are currently in development and construction stages, that will supply a ...
  135. [135]
    Carbon emissions from hydropower reservoirs: facts and myths
    Sep 13, 2021 · For gas and coal, the values are 490 and 820 gCO2-eq/kWh respectively. Of course, this is only a median value. In a few rare and extreme cases, ...
  136. [136]
    Comparing CO₂ emissions from different energy sources - COWI
    Hydropower: approximately 4 g CO2e/kWh · Wind power: approximately 11 g CO2e/kWh · Nuclear power: approximately 12 g CO2e/kWh · Solar power: around 41 g CO2e/kWh ...
  137. [137]
    Site C Dam, Canada - Ej Atlas
    Apr 25, 2022 · Environmental Impacts: The findings of the JRP indicated that the Site C Project would have significant adverse environmental effects. These ...<|separator|>
  138. [138]
    BC Hydro imported 25% of the province's power last year
    The Energy Futures Institute said BC Hydro needs to ramp up power production as demand is forecast to keep climbing.
  139. [139]
    Early 2025 Drought | Groundwater Conditions in British Columbia
    Apr 19, 2025 · BC experienced extremely dry conditions in January 2025, with snowpack at 72% of normal by Feb 1. By early March, snowpack was 73% of normal, ...
  140. [140]
    La Niña, drought and storm readiness gap - BC Hydro
    Sep 30, 2025 · The findings come as BC Hydro braces for a La Niña season, which typically brings cooler, wetter weather and an increased likelihood of a very ...
  141. [141]
    BC Hydro warns of increased storm risks amid La Niña and drought ...
    Oct 7, 2025 · La Niña conditions, combined with weakened vegetation from drought, are expected to heighten outage risks across the province.
  142. [142]
    [PDF] BC Hydro 2023 Climate Change Accountability Report (May 2024)
    As a Crown Corporation, we play a crucial role in supporting the government's climate actions and targets. The specific measures and targets for GHG ...
  143. [143]
    Powering Our Future: BC's Clean Energy Strategy - Gov.bc.ca
    Jun 27, 2024 · As a start, the Site C dam is scheduled to be fully in service in 2025, adding approximately 8% more supply to BC's electricity grid (or 5,100 ...
  144. [144]
    Penner sounds alarm as BC faces risks to electricity reliability
    “We know Site C alone won't meet our province's growing energy needs,” concluded Penner. “Further expanding domestic energy production and lessening our ...
  145. [145]
    https://energyfuturesinstitute.ca/f/bc-government-acknowledges-serious-power-shortage-with-bill-31?blogcategory=electric%2Bvehicles
  146. [146]
    Floods or financial face-plant? BC Hydro looking to get out of contracts
    May 12, 2020 · BC Hydro says it is trying to get out of commitments to purchase electricity from independent power producers (IPPs), as demand drops and ...Missing: oversupply | Show results with:oversupply
  147. [147]
    More Alarms Sounded about Risks to BC's Electricity Reliability
    Jun 19, 2024 · This is more than half the maximum output of the still unfinished Site C dam, first announced 14 years ago. “BC needs an updated energy plan ...
  148. [148]
    In an era of drought, can B.C. rely on Site C and other hydro projects?
    Sep 30, 2024 · But even at full output, Site C will only satisfy a portion of B.C.'s near-future electricity needs, with demand expected to increase by 15 per ...
  149. [149]
    [PDF] 2021 Integrated Resource Plan - BC Hydro
    The expiring agreements are primarily small run-of-river facilities. ... With an installed capacity of 105 MW and a high capacity factor, this facility is.
  150. [150]
    [PDF] Request for Proposals (“RFP”) 22357 BC Hydro 2025 Call for Power
    Jul 28, 2025 · As noted in the plan, BC Hydro views calls for power as important opportunities for First Nations to advance self-determination and economic.
  151. [151]
    [PDF] 2024 Call for Power Electricity Purchase Agreements (EPAs ...
    Feb 12, 2025 · BC Hydro is filing 10 Electricity Purchase Agreements (EPAs) with the British Columbia. Utilities Commission (BCUC or Commission) for ...
  152. [152]
    [PDF] Energy economy report 2025 - BC Hydro
    May 5, 2025 · BC Hydro's Energy Efficiency Plan will save customers $80 million annually and achieve over 2,000 gigawatt-hours of electricity savings by 2030 ...Missing: necessity | Show results with:necessity
  153. [153]
    [PDF] Enhancing energy efficiency to support British Columbians - BC Hydro
    Since 2008, we have achieved over 7,000 gigawatt hours in energy savings through these initiatives, which is the equivalent to the annual energy consumption of ...
  154. [154]
    [PDF] F2024 Annual Report on Demand-Side Management Activities (July ...
    Jul 15, 2024 · Ongoing DSM performance reporting should demonstrate how BC Hydro is continuously pursuing. DSM and that specific programs are cost-effective.”.Missing: KPIs | Show results with:KPIs
  155. [155]
    Powering B.C.'s potential - BC Hydro
    Site C hydroelectric project: Increasing our energy supply by 8%, enough to power 500,000 new homes. 2024 Call for Power: Supporting 10 new renewable energy ...Missing: forecast 2030s
  156. [156]
    Meter Security and Your Privacy - BC Hydro
    The meter doesn't store any personal identifiers – no names or addresses. The data it does record – your electricity use – is protected by security certificates ...Missing: rollout 2010s
  157. [157]
    [PDF] Investigation Report F11-03 British Columbia Hydro and Power ...
    Dec 19, 2011 · This investigation focuses on BC Hydro's obligations under the Freedom of Information and Protection of Privacy Act (“FIPPA”). [14] The ...
  158. [158]
    BC Hydro smart meter installs violating privacy: report | CBC News
    Dec 19, 2011 · BC Hydro failed to notify customers who received new smart meters about how their personal information is being collected and used, B.C.'s ...Missing: rollout 2010s
  159. [159]
    Self-generation - BC Hydro
    Our self-generation program – previously called net metering – is designed for those who want to reduce their electricity bills and gain energy independence.Missing: reliance | Show results with:reliance<|control11|><|separator|>
  160. [160]
    [PDF] Net Metering Service Rate (May 1, 2024) - BC Hydro
    May 1, 2024 · Net metering allows customers to connect small renewable units. Excess generation is stored as credits, and unused credits are paid out ...
  161. [161]
    Net Metering Gets an Overhaul - BC Sustainable Energy Association
    Aug 8, 2024 · The overhaul includes changing to "net billing" where customers are paid for power delivered to BC Hydro, increasing facility size limits, and ...Missing: caps grid
  162. [162]
    https://solarenergies.ca/solar-power-bc-rebates/
  163. [163]
    [PDF] Adventures in Tweaking the TRC: Experiences from British Columbia
    As a result, the cost of BC Hydro's electricity DSM is typically compared against the cost of zero-emission energy sources—by using the long-run marginal cost ...
  164. [164]
    [PDF] F2023 Demand Side Management Milestone Evaluation ... - BC Hydro
    Jan 10, 2024 · 1 Simple payback was estimated with assumed average unit electricity cost of 6.6 cents per kilowatt-hour. 2 Details not disclosed due to ...
  165. [165]
    BC Hydro customers set to pay $16B over 20 years for power they ...
    Feb 14, 2019 · BC Hydro ratepayers are expected to overpay by billions of dollars for electricity it doesn't need, due to costly and unnecessary contracts ...Missing: uneconomic | Show results with:uneconomic<|separator|>
  166. [166]
    2025 Integrated Resource Plan - BC Hydro
    We're committed to supporting a strong economy and a clean energy future while keeping electricity affordable for British Columbians. Key aspects of the Plan.
  167. [167]
    Wind Electricity in BC - Business Council of British Columbia
    Sep 27, 2024 · This means B.C. Hydro's wind resources operate at about 30% for every MW of capacity (wind energy efficiency is typically between 20% and 40%).
  168. [168]
    [PDF] Clean misconceptions: - BC Hydro
    ○ 45 per cent of respondents think solar generation provides cleaner power than hydroelectricity, and 22 per cent think wind ... are ideally suited for B.C.'s ...
  169. [169]
    How the so-called “Clean Energy Plan” still wreaks havoc on BC ...
    Aug 22, 2016 · It was clear from the outset that the Clean Energy Plan would needlessly impose hundreds of millions of dollars of costs on BC Hydro. The Clean ...
  170. [170]
    BC government's Clean Energy Act means trouble ahead for BC Hydro
    Dec 4, 2024 · Reliance on 'clean' independent power producers means utility lacks 'reserve capacity' to meet emergencies and future demand, including switch to EVs.
  171. [171]
    B.C. racks up $58 billion in independent power producers contracts
    Mar 17, 2017 · Auditor general flags BC Hydro's contentious IPP program as province's single largest contractual obligation.Missing: uneconomic | Show results with:uneconomic
  172. [172]
    How did we get into this IPP mess? - Norm Farrell
    Jul 26, 2016 · What began more than 10 years ago as a not unreasonable concept for economic activity morphed into a financial disaster for taxpayers and non- ...Missing: program criticism uneconomic
  173. [173]
    [PDF] Benefits of wind power curtailment in a hydro dominated electric ...
    Existing flexibility in the large storage reservoirs was used by the model to shift the wind energy to export periods with the highest market prices.