The Project Fact Sheets

LNG CANADA PHASE 2 (KITIMAT, BC)

Written by Canadian Indigenous Investment Forum | Dec 4, 2025, 11:11:12 AM

LNG Export Terminal Expansion, British Columbia

Executive Summary 

LNG Canada Phase 2 is a proposed $33 billion CAD expansion of Canada's first large-scale LNG export facility at Kitimat, British Columbia. The expansion would double production capacity from 14 to 28 million tonnes per annum, positioning Canada among the world's largest LNG exporters. It received Major Projects Office priority designation in September 2025, providing a streamlined two-year federal approval pathway. The Haisla Nation's longstanding partnership on Phase 1 provides a strong foundation for Indigenous engagement, though the expansion will require updated consultation and benefit agreements. 

Project Overview 

Location: Kitimat, British Columbia (Haisla Nation traditional territory) 

Proponent: LNG Canada Development Inc. 

Ownership: Shell Canada (40%, operator), Petronas (25%), PetroChina (15%), Mitsubishi Corporation (15%), Korea Gas Corporation (5%) 
Project Type: LNG export terminal expansion

Status: Major Projects Office priority designation (11 September 2025); FEED contract awarded to the Fluor Corporation–JGC Corporation joint venture (August 2025); Limited Notice to Proceed issued (1 June 2026) 

Project Description 

Phase 2 would add two LNG processing trains to the existing infrastructure, doubling facility capacity from 14 million tonnes per annum (mtpa) to 28 mtpa. Phase 1 achieved its first cargo export on 30 June 2025, with more than 50,000 Canadians directly contributing to construction over the project lifecycle. A further 25,000 Canadians were employed building the connecting Coastal GasLink pipeline. More than 300 permanent operations roles have been created (LNG Canada, 30 June 2025). 

The expansion would leverage existing site infrastructure, including the marine terminal, administration facilities and utilities. Phase 2 equipment would be fabricated as modules, following the Phase 1 approach, and transported to the site for assembly, reducing on-site construction complexity. 

Investment Value 

Phase 1: Approximately $40 billion CAD, comprising the Kitimat processing facility and the $14.5 billion CAD Coastal GasLink pipeline, together representing the largest private infrastructure investment in Canadian history (Government of Canada, June 2019). 

Phase 2: Estimated at a further $30 billion to $33 billion CAD, pending a final investment decision. The federal government estimates the expansion would attract $33 billion in private-sector capital to Canada (Canada.ca, Major Projects Office). 

Cost Structure: 

  • Engineering and design 
  • Module fabrication (international and Canadian) 
  • Marine transport and installation 
  • On-site assembly and commissioning 
  • Grid connection and utilities 
  • Contingencies 

Timeline and Milestones 

  • June 2025: Phase 1 first LNG cargo shipped
  • August 2025: FEED contract awarded to Fluor Corporation–JGC Corporation joint venture
  • June 2026: Limited Notice to Proceed issued to the Fluor-JGC joint venture, permitting early site preparation, procurement and design work ahead of FID
  • Late 2026/Early 2027: Final investment decision (FID) target
  • 2025–2026: Engineering work, regulatory preparation, Indigenous consultation
  • Post-FID: 5–7 year construction timeline
  • Early 2030s: Commercial operations target

Critical Path Dependencies: 

  • Global LNG market conditions and long-term offtake agreements
  • BC Hydro electricity availability for low-carbon operations
  • Confirmation of permit and monitoring conditions applicable to Phase 2 construction
  • Indigenous consultation completion
  • Partner consortium FID alignment

Indigenous Partnerships and Consultation  

Primary Partnership: Haisla Nation

Status: Site host, Phase 1 benefit agreements in place

Traditional Territory: Kitimat is located within Haisla Nation traditional territory 

 
 Phase 1 Results: 
  • Cumulative procurement from local, Indigenous-owned and other BC businesses exceeded CAD $5.8 billion, of which more than CAD $4.9 billion went to Indigenous-owned and local area businesses (LNG Canada, 30 June 2025)
  • HaiSea Marine: $500 million tugboat services contract with a majority Haisla-owned joint venture with Seaspan, providing harbour and escort tugboat services with a fleet of battery-powered, low-emissions vessels (Seaspan)
  • More than CAD $10 million invested in workforce development programmes (LNG Canada) 
    Employment and training programmes
  • Community investment initiatives   

Phase 2 Indigenous Investment: 

  • MNT Investments equity option: five First Nations (Gitga'at, Gitxaała, Haisla, Kitselas and Kitsumkalum) have been offered an equity option of up to C$1 billion to acquire a majority stake in a special-purpose entity that would own the planned Phase 2 storage tank, conditional on FID (Petroleum and Gas Journal, July 2026) 

Phase 2 Requirements

  • Updated benefit agreements reflecting expanded scope
  • Additional employment and procurement commitments
  • Environmental monitoring participation
  • Community infrastructure investments 

Coastal GasLink Pipeline Context 

Supply Infrastructure: 670 km pipeline delivering natural gas from northeastern British Columbia to Kitimat 

Indigenous Engagement: 10% equity participation offered to the 20 First Nations with benefit agreements along the route; take-up has varied, with 16 of 20 nations signing on in initial 2022 reporting, rising to 17 of 20 in later reporting (Daily Hive)

Construction Experience: Faced delays due to Indigenous opposition in certain territories, notably from Wet'suwet'en hereditary chiefs; completed through benefit agreements and extended consultation (CBC)

Learning Applied: Phase 2 consultation informed by Phase 1 and Coastal GasLink experiences 

Treaty & Rights Framework 

Legal Context: Operating on Crown lands within Haisla traditional territory 

Consultation Standard: Section 35 Constitution Act obligations; UNDRIP principles 

Marine Access: Douglas Channel vessel traffic consultation with coastal First Nations 

Precedent: LNG Canada established a consultation model for the BC LNG sector 

Regulatory & Approval Status 

Major Projects Office Designation 

Announcement: 11 September 2025, first tranche of Major Projects Office priorities (CBC News) 

Significance: Two-year maximum approval timeline; coordinated federal review 

Process: Single-window federal coordination; "one project, one review" with BC government  

Environmental Assessment 

Phase 1 Certificate: Received June 2015 from the BC Environmental Assessment Office (Certificate #E15-01), amended August 2016, October 2019, February 2021 and November 2022 to reflect specific project changes within its certified scope (BC EAO, Amendment #4 Assessment Report) 

Phase 2 Requirement: Covered under the original four-train scope of Certificate #E15-01 and the July 2016 federal Decision Statement, with Phase 2 expected to proceed via further amendment to the existing Certificate rather than a new environmental assessment (BC Energy Regulator; justandreasonable.com)  

 Key Issues: 

  • Greenhouse gas emissions (incremental from expansion) 
  • Marine vessel traffic impacts 
  • Air quality in the Kitimat area 
  • Water use from Kitimat River
  • Cumulative effects with Phase 1
Monitoring Obligations: Required to monitor and report local effects over project life 
 

Federal Approvals Required 

  • Fisheries Act authorisations
  • Navigation Protection Act approvals
  • Species at Risk Act considerations
  • Federal lands and waters permits 

Provincial Approvals Required 

  • BC Environmental Assessment Certificate amendment (under existing Certificate #E15-01) 
  • Provincial permits (air, water, waste)
  • Municipal development permits (District of Kitimat)  

Technical Specifications 

Capacity & Production 

Phase 2 Addition: 14 mtpa (two trains at 7 mtpa each) 

Total Facility: 28 mtpa (four trains total) 

Processing: Natural gas liquefaction to -162°C 

Storage: Existing tanks plus potential additional capacity 

Loading: Dual LNG carrier berths (existing infrastructure) 

Emissions Profile 

Competitive Advantage: 35% lower emissions than the world's best-performing LNG facilities; 60% lower than the global average (LNG Industry) 

Low-Carbon Pathway: 

  • BC Hydro renewable electricity (when available)
  • Energy-efficient natural gas turbines
  • Best-in-class liquefaction technology
  • 0.15 tonnes CO2e per tonne LNG: projected emissions intensity for Phase 1 and Phase 2 combined, operating at full capacity, versus a global average of 0.35 tonnes CO2e per tonne. This assumes partial electrification of the full facility, which remains uncertain given BC Hydro capacity constraints (International Institute for Sustainable Development) 

Electrification Dependency: Phase 2 economics and emissions performance depend on BC Hydro electricity availability. Without sufficient renewable power, the facility would rely on natural gas turbines, which would reduce its emissions advantage. 

Infrastructure 

Site: 400 hectares, Kitimat Industrial Site

Marine Terminal: Deep-water access, ice-free harbour 

Rail: Condensate loading via existing rail infrastructure 

Workers: Accommodation and facilities from Phase 1 

Utilities: Water treatment, flare systems, administration buildings (expandable) 

Market Positioning & Export Strategy 

Target Markets

Primary: Asian LNG importers (Japan, South Korea, China, Taiwan) 

Secondary: European markets seeking supply diversification following the disruption of Russian gas supply 

Advantage: Pacific coast location provides shorter shipping distances to Asia compared with US Gulf Coast LNG 

Competitive Positioning 

Low-Carbon Intensity: Marketing advantage in emissions-conscious markets; European buyers increasingly prioritising lower-carbon LNG 

Supply Security: Canadian political stability and rule of law; reliable North American gas reserves 

Price Competitiveness: Montney Formation gas costs; operational efficiency from Phase 1 learnings 

Long-Term Offtake 

FID Requirement: Phase 2 partners require long-term sales agreements before committing capital 

Market Dynamics: Global LNG demand growth; Asian energy security priorities; European supply diversification 

Competition: US Gulf Coast LNG expansions; Qatar North Field projects; Australian LNG 

Employment & Economic Impact 

Construction Phase 

Peak Employment: 10,000+ jobs during major construction 

Duration: 5–7 year construction phase 

Canadian Content: 80%+ of workforce expected to be Canadian 

Trades: Heavy emphasis on skilled trades (pipefitters, electricians, millwrights, ironworkers)  

Operations Phase 

Permanent Jobs: Hundreds of permanent positions (operations, maintenance, administration) 

Indirect Employment: Supply chain, services, contractors 

Skills: Highly skilled technical roles; competitive salaries 

Indigenous Employment 

Commitments: Minimum Indigenous employment percentages in agreements 

Training: Workforce development programmes (Phase 1 invested more than CAD $10 million) (LNG Canada) 

Businesses: Continued procurement from Indigenous-owned businesses 

Career Pathways: Trades training programmes for local and Indigenous residents 

Fiscal Benefits 

Property Taxes: Significant contributions to the District of Kitimat 

Procurement: Phase 1 procurement exceeded CAD $5.8 billion to BC businesses, of which more than CAD $4.9 billion went to Indigenous-owned and local area businesses (LNG Canada, 30 June 2025) 

Key Investment Risks 

Material Risks 

Electrification Constraints
  • Issue: Phase 2's low-carbon advantage depends on BC Hydro electricity availability
  • Current Status: British Columbia is facing electricity capacity constraints, compounded by drought impacts on hydroelectric generation
  • Impact: Without sufficient renewable power, the facility would rely on natural gas turbines, reducing the emissions advantage
  • Mitigation: The provincial government is aware of the economic benefits; discussions on power allocation are ongoing 
Global LNG Market
  • Issue: FID is contingent on securing long-term offtake agreements; LNG prices are volatile
  • Competition: US Gulf Coast expansions; Qatar North Field projects; Australian capacity
  • Asian Demand: Economic growth uncertainties; pace of the renewable energy transition
  • Mitigation: Canadian LNG's low-carbon profile; Asian energy security priorities 
Indigenous Consultation
  • Issue: Phase 2 requires updated consultation extending beyond Phase 1 agreements
  • Coastal Nations: Vessel traffic concerns from marine-focused First Nations
  • Cumulative Effects: Douglas Channel traffic increasing with multiple LNG proposals in the region
  • Mitigation: Established Haisla relationship; Phase 1 consultation experience; HaiSea Marine partnership and the MNT Investments equity option together demonstrate growing Indigenous economic participation  

Environmental Assessment

  • Issue: The regulatory pathway for Phase 2 (Certificate amendment versus new assessment) has not been explicitly confirmed by LNG Canada or the BC EAO, though existing evidence points toward amendment. Cumulative effects scrutiny remains relevant regardless of the pathway taken.
  • Timeline: Could extend if compliance, permitting or amendment review issues arise
  • Public Opposition: Environmental groups challenging LNG sector expansion; specific concerns from coastal and marine-focused First Nations regarding vessel traffic and cumulative effects
  • Mitigation: Major Projects Office two-year timeline commitment; established Certificate amendment precedent, with four amendments processed between 2016 and 2022 without a Community Advisory Committee or extended public engagement 

Capital Cost Escalation 

  • Issue: Global inflation; supply chain constraints; labour costs
  • Phase 1 Experience: The project was completed on schedule but faced cost pressures
  • Impact: Could affect FID if projected returns prove insufficient
  • Mitigation: Module fabrication approach; established supply chains; Phase 1 learnings  

Moderate Risks 

Regulatory Coordination
  • Federal-provincial-municipal coordination requirements 
  • Multiple permit streams requiring alignment 
  • Major Projects Office coordination intended to mitigate 
Construction Labour
  • Skilled trades availability in a tight labour market
  • Remote location challenges for workforce recruitment and retention
  • Accommodation and logistics   
Partner Alignment
  • Five international companies must align on FID
  • Each partner's corporate priorities and market perspectives differ
  • Consensus decision-making requirements   

Investment Opportunities and Strengths 

Regulatory Advantages 

Major Projects Office: Streamlined two-year approval pathway; federal priority support 

Precedent: Phase 1's successful completion demonstrates Canada's ability to deliver large-scale LNG infrastructure 

Provincial Support: BC government LNG-supportive policies; established tax frameworks 

Commercial Strengths 

Established Infrastructure: Phase 2 leverages Phase 1 investment, reducing capital intensity 

Operator Expertise: Shell's global LNG leadership; experienced partner consortium 

Market Access: Deep-water, ice-free harbour; Douglas Channel shipping route established 

Cost Learning: Phase 1 construction experience applied to Phase 2, reducing execution risk  

Strategic Value 

Supply Diversification: Reduces global reliance on specific LNG suppliers 

Canadian Economy: Tens of billions in private investment; thousands of jobs; government revenues 

Indigenous Reconciliation: Economic participation model for Indigenous communities, strengthened by the MNT Investments equity option 

Energy Security: Reliable North American supply for energy-importing nations 

Financial Structure Options 

Private Financing: Partners expected to fund through corporate resources and project finance 

Federal Support: Canada Infrastructure Bank potential involvement; federal loan guarantees 

Indigenous Participation: Future tranches could include further Indigenous equity participation; Indigenous Loan Guarantee Programme access 

Investment Intelligence Summary 

Risk Profile: Moderate (established Phase 1 foundation, offset by market and electrification uncertainties) 

Timeline: FID late 2026 or early 2027; commercial operations early 2030s 

Probability: High (60–70%) given Major Projects Office support, established infrastructure and partner commitment 

Investment Thesis: The best-positioned LNG expansion in Canada. Phase 1 demonstrated execution capability; low-carbon advantage in an evolving global market. 

UK/European Investor Considerations: 

  • European LNG demand is increasing as the continent diversifies away from Russian supply; Canadian LNG is an attractive alternative
  • Low-carbon intensity aligns with European emissions standards and buyer preferences
  • Canadian political stability and rule of law reduce sovereign risk compared with other LNG suppliers
  • The Indigenous partnership model demonstrates social licence strength
  • Major Projects Office support signals sustained federal commitment 

Due Diligence Priorities: 

  • Monitor FID decision timing and partner alignment
  • Track BC Hydro electricity allocation decisions
  • Assess long-term offtake agreement progress
  • Review the Phase 2 regulatory pathway (Certificate amendment versus new assessment)
  • Evaluate global LNG market supply-demand dynamics
  • Monitor MNT Investments equity option progress and confirm terms once FID is reached  

Sources 

 
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