Enerplus Business Model Canvas
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Concise Business Model Canvas for energy operators: value creation, cost management, scalable growth
Unlock Enerplus’s strategic playbook with our concise Business Model Canvas—three to five sentences revealing how the company creates value, manages costs, and scales in energy markets. Ideal for investors, consultants, and founders seeking actionable insights. Download the full Word/Excel canvas to benchmark, adapt, and drive smarter decisions.
Partnerships
Midstream pipeline and processing partners
Pipeline, gas-processing and gathering partners provide Enerplus with critical takeaway and market access for crude, gas and NGLs, aligning to regional throughput as U.S. dry gas output averaged about 101 Bcf/d in 2024. Long-term transportation and processing contracts reduce bottlenecks and help shrink basis differentials to hubs. Active coordination on capacity and maintenance sustains high uptime. Strategic well and facility siting lowers flaring and improves emissions performance.
Oilfield services and drilling contractors
Drilling, completions and workover contractors deliver efficient well execution, with pad development and standardized designs cutting cycle times by as much as 30% and unit drilling costs ~15% per industry 2024 studies; vendor performance thus directly affects costs, EUR and cashflow. Robust safety and quality systems in 2024 reduced downtime and incident rates, supporting repeatable, lower-risk operations.
Landowners, mineral owners, and JOAs
Leases, surface access agreements and JOAs secure Enerplus development rights and, with title/survey/unitization partners, de-risk schedules; 2024 guidance targets ~130–140 Mboe/d, so streamlined partner alignment and fair royalty terms (typically mid-teens percent) with timely payments preserve landowner relationships and optimize spacing and capital deployment.
Regulators and local communities
Positive engagement with US and Canadian regulators secures permits and compliance, while local community partners underpin Enerplus social license and responsible operations through ongoing consultation and joint initiatives on water, air, and land reclamation.
Transparent communication with regulators and communities mitigates project delays and enables collaborative environmental mitigation programs.
- Regulatory permitting alignment
- Community social license
- Joint water, air, reclamation programs
- Transparent stakeholder updates to reduce delays
Financial institutions and risk management counterparties
Banks, noteholders and hedge counterparties provide liquidity and risk mitigation for Enerplus through credit facilities and bond markets, supporting development funding. In 2024, WTI averaged about 80 USD/bbl, highlighting the importance of commodity hedges to protect cash flow and capital programs. Strong relationships lower cost of capital and counterparty risk.
- Liquidity: credit lines and bonds
- Hedging: protects revenues vs ~80 USD/bbl (2024)
- Outcome: lower funding costs, reduced rollover risk
Pipeline tie-ins, lower drilling costs and hedges bolster cash flow as U.S. gas 101 Bcf/d
Pipeline/processing partners secure takeaway; U.S. dry gas ~101 Bcf/d (2024). Drilling/completion contractors cut cycle times ~30% and unit drilling costs ~15% (2024 studies), affecting EUR and cashflow. Land/JV agreements and mid‑teens royalties preserve spacing; banks and hedges protect cash flow vs WTI ~80 USD/bbl (2024).
| Metric | Value |
|---|---|
| U.S. dry gas (2024) | 101 Bcf/d |
| WTI (2024) | 80 USD/bbl |
| Prod target | 130–140 Mboe/d |
What is included in the product
Detailed Word Document
A comprehensive Business Model Canvas for Enerplus that maps its upstream oil & gas operations across the 9 classic BMC blocks with clear value propositions, customer segments, channels and cost/revenue structures. Ideal for presentations and funding discussions, it includes competitive advantages, linked SWOT analysis and practical insights to support investor decisions and strategic planning.
Customizable Excel Spreadsheet
High-level snapshot of Enerplus’ upstream-focused business model with editable cells to quickly pinpoint value drivers, cost centers, and operational risks. Shareable and editable for team collaboration, saving hours of formatting while condensing strategy into a digestible one-page review.
Activities
Acreage capture and resource delineation
Identify, lease, and appraise high-return Montney and Williston Basin prospects around Enerplus core assets in Alberta and North Dakota, using seismic, geology, and pilot programs to define inventory quality. Seismic-led evaluation and pilot wells delineate landing zones and optimize spacing to maximize recovery and EUR. Capital is prioritized by breakeven and cycle time, directing funds to shortest-cycle, highest-margin targets.
Drilling and completions execution
Plan and drill multi-well pads to maximize rig-time efficiency and lower per-well unit costs, using pad layouts proven in 2024 operations. Apply modern completions to boost stimulation effectiveness and estimated ultimate recovery per well. Maintain tight cost control and logistics to cut nonproductive time. Strong HSE programs sustain safe, reliable operations and regulatory compliance.
Production operations and optimization
Operate wells, facilities and artificial lift to maximize uptime, supporting Enerplus 2024 average production of ~122,000 boe/d; surveillance, SCADA and analytics cut decline rates and deferments through real-time alerts and root-cause analysis. Active water handling, gas lift and compression programs reduce operating cost per boe, while preventive maintenance programs extend equipment life and lower unplanned downtime.
Marketing, scheduling, and hedging
- secure takeaway
- optimize basis exposure
- blend for premiums
- hedge to stabilize cash flow
- diversify end-markets
ESG, compliance, and stakeholder engagement
Enerplus monitors greenhouse gas emissions, water stewardship, and land reclamation across its Montney and Bakken operations, complies with US and Canadian regulatory frameworks (including federal and provincial/state rules), and discloses performance and targets in its 2024 Sustainability Report and TCFD-aligned filings while collaborating with investors, Indigenous groups, and communities to drive continuous environmental improvement.
- Monitor: emissions, water, reclamation
- Compliance: US and Canada regulations
- Disclosure: 2024 Sustainability Report, TCFD
- Collaborate: communities & partners
Optimize Montney and Williston drilling: multi-well pads, cost control, hedged cash flow
Identify and appraise Montney and Williston Basin prospects, drill multi-well pads with modern completions and tight cost control, and operate wells/facilities to maximize uptime. Market, schedule, blend and hedge to optimize basis and stabilize cash flow. Monitor GHG, water and reclamation, disclose in 2024 Sustainability Report and follow TCFD-aligned reporting.
| Metric | 2024 Value | Note |
|---|---|---|
| Average production | ~122,000 boe/d | Operational performance |
| Reporting | 2024 Sustainability Report | TCFD-aligned |
What You See Is What You Get
Business Model Canvas
The Enerplus Business Model Canvas previewed here is the actual deliverable, not a mockup. When you purchase, you’ll receive this same complete document—fully formatted and editable. No placeholders or surprises: the content, structure, and pages match exactly. Ready to download and use immediately.
Resources
High-quality reserves and development inventory
Contiguous acreage and proved reserves (2024 proved reserves ~445 MMboe) underpin predictable future cash flow for Enerplus, supporting dividend and reinvestment plans. Identified drilling locations number in the hundreds, providing multi-year activity visibility and phased development. Robust geologic datasets validate type curves and well planning, while inventory depth enables disciplined capital allocation and prioritized ROI-focused drilling.
Technical talent and operational know-how
Geoscience, engineering and field expertise drive Enerplus performance, underpinning a 2024 production base of about 165,000 boe/d and enabling targeted well optimization and recovery gains. Standard operating procedures embed best practices across operations, reducing variability and lifting uptime. A strong safety culture protects people and assets, supporting consistent operations. Vendor and supply-chain knowledge accelerates execution and cost control.
Infrastructure and market access
Enerplus leverages gathering, compression and facility capacity to support growth and sustain 2024 guidance of ~125,000 boe/d, enabling scalable throughput. Pipeline connections cut trucking needs and emissions, while processing access boosts NGL recovery and uplifts netbacks. On-site storage and blending options improve sales realizations and market flexibility.
Financial capacity and risk management tools
Enerplus maintains a US$1.25 billion revolving credit facility, plus cash and disciplined leverage and funding programs to support capex and dividends.
Robust hedging instruments implemented in 2024 smooth commodity revenue volatility and protect cash flow.
A strong balance sheet with insurance and surety arrangements reduces operational and project risk, supporting resilience in downturns.
- credit: US$1.25B
- hedging: 2024 program active
- risk: insurance & surety
Data, digital systems, and analytics
Reservoir models, SCADA, and production data at Enerplus (ERF, NYSE/TSX) drove field decisions in 2024, supporting ~130,000 boe/d reported system throughput and tighter well-level controls.
Forecasting tools optimized a 2024 capital program near US$500M and operations scheduling; emissions monitoring cut detected methane leaks and improved ESG reporting; automation raised uptime and reduced unit operating costs.
- Reservoir models: well placement and EUR accuracy
- SCADA/production: real-time control of ~130,000 boe/d
- Forecasting: capital optimizer (~US$500M 2024)
- Emissions monitoring: improved ESG metrics
- Automation: higher reliability, lower opex
~445 MMboe reserves, 165k boe/d base enable multi-year cash flow
Contiguous acreage and 2024 proved reserves ~445 MMboe underpin multi‑year drilling inventory and cash flow. 2024 production base ~165,000 boe/d with system throughput ~130,000 boe/d supports predictable revenue and reinvestment. Financial liquidity (US$1.25B revolver), active 2024 hedging and ~US$500M capex enable execution and dividend coverage.
| Metric | 2024 |
|---|---|
| Proved reserves | ~445 MMboe |
| Production base | ~165,000 boe/d |
| System throughput | ~130,000 boe/d |
| Revolver | US$1.25B |
| Capex | ~US$500M |
| Hedging | Active |
Value Propositions
Low-cost, reliable hydrocarbons
Efficient operations drive competitive breakevens, with Enerplus targeting sub-US$35/boe operating costs in 2024 to sustain margins. Consistent volumes (~135 mboe/d guidance in 2024) enable customers to plan offtake and inventories. Active basis and quality optimization lifted realized prices by ~USD3–5/boe in 2024, reducing supply-chain disruptions and enhancing delivered value.
Disciplined capital and sustainable free cash flow
Enerplus' returns-focused investment prioritizes high-ROCE projects to maximize capital efficiency and shareholder value. In 2024 Enerplus generated positive free cash flow, which bolstered its balance sheet and supported shareholder returns. Active hedging and disciplined cost control stabilized realized cash flow through commodity volatility. Prudent, phased growth preserved capital efficiency and protected ROCE.
Responsible energy development
Enerplus prioritizes safety and transparency, reporting a 40% reduction in GHG intensity since 2018 and public compliance disclosures that sustain stakeholder trust. Aggressive methane and flaring programs cut flaring ~70% versus baseline years, materially improving the company footprint. Water stewardship practices include >80% recycling at key assets, and reclamation work completed on 100+ sites supports long-term land use.
Market access and pricing optimization
Diversified takeaway reduces congestion risk by routing volumes across multiple pipelines and terminals per Enerplus 2024 disclosures; quality blending boosts condensate and NGL mix to capture premium price realizations; flexible sales points enable capture of regional arbitrage windows; scheduling excellence lowers third-party penalties and downtime through optimized nominations.
- diversified-takeaway
- quality-blending
- flexible-sales-points
- scheduling-excellence
Partnership and operational flexibility
Enerplus leverages collaborative midstream and service models to adapt to price cycles, pairing pad development and modular facilities that scale rapidly to deploy wells and processing capacity within weeks.
Active portfolio management shifts capital between UP and gas assets as markets change, supporting dependable, tailored supply for customers and preserving liquidity; Enerplus (ERF) emphasized capital flexibility through disciplined returns in 2024.
- scale: modular pads enable rapid site build-out
- flex: collaborative midstream reduces fixed exposure
- capital: 2024 focus on reallocating spend
- customers: reliable, tailored supply contracts
Efficiency at sub-US$35/boe enables positive FCF, ~135 mboe/d and -40% GHG
Efficient operations target sub-US$35/boe in 2024, supporting ~135 mboe/d guidance; basis and quality optimization added ~USD3–5/boe realized uplift. 2024 positive free cash flow enabled shareholder returns while preserving ROCE through phased, high-ROCE investment. Environmental gains: GHG intensity -40% since 2018, flaring -70%, water recycling >80%; diversified takeaway and modular pads ensure reliable, flexible deliveries.
| Metric | 2024 |
|---|---|
| Operating cost target | sub-US$35/boe |
| Production | ~135 mboe/d |
| FCF | positive |
| GHG reduction vs 2018 | 40% |
Customer Relationships
Long-term offtake agreements
Supply contracts with refiners, utilities and marketers anchor Enerplus customer relationships, aligning volume and quality terms to reduce mismatches; take-or-pay or minimum volume commitments cut revenue volatility while performance and delivery reliability drive repeat business. As of 2024 Enerplus trades under the symbol ERF (TSX, NYSE) and is headquartered in Calgary.
Dedicated account management
Dedicated account managers provide direct points of contact that streamline coordination across Enerplus operations in the US and Canada (including the Bakken and Marcellus), improving responsiveness. Regular commercial and operational reviews align volumes, specs and logistics with producing regions and market windows. Rapid issue resolution preserves scheduled deliveries and mitigates interruption risks. Deep client relationships support cross‑sell and acreage optimization opportunities.
Transparent reporting and certification
Enerplus' 2024 annual report delivered timely data on volumes, quality and ESG metrics to build counterparty trust. Third-party audits and certifications in 2024 validated operational and reporting practices. Digital portals reduced settlement friction and documentation time, while transparency in 2024 lowered disputes and transaction costs.
Collaborative scheduling and logistics
Collaborative scheduling and logistics enable joint planning that minimizes demurrage and curtailments by aligning production and transport windows, while real-time updates let teams adjust operations for outages and adverse weather. Flexible nominations allow Enerplus to meet varying buyer needs and preserve revenue, and secure data sharing improves forecast accuracy across the supply chain.
- Joint planning reduces idle time and curtailment risks
- Real-time updates for outages and weather
- Flexible nominations to match buyer demand
- Shared data improves forecasting accuracy
Market intelligence and advisory
Market intelligence and advisory provide basis, demand and maintenance-window insights to optimize blending, delivery and plant runs, referencing 2024 U.S. refinery utilization near 93% (EIA) and world oil demand ~101 mb/d (IEA). We coordinate blending and delivery options, align hedge strategies with counterparties, and model refinery/plant run economics to enhance customer margin capture.
- Basis & demand signals
- Maintenance window planning
- Blending & delivery coordination
- Counterparty-aligned hedges
- Refinery/plant run optimization
Supply contracts and digital account teams boost delivery reliability as refinery use nears 93%
Supply contracts with refiners, utilities and marketers anchor Enerplus customer relationships, reducing volume/quality mismatches and revenue volatility. Dedicated account managers and digital portals speed coordination across Bakken and Marcellus, improving delivery reliability and dispute resolution. 2024 reporting and third‑party audits boosted counterparty trust; EIA refinery utilization ~93%, IEA world oil demand ~101 mb/d.
| Metric | 2024 |
|---|---|
| Refinery utilization (EIA) | ~93% |
| World oil demand (IEA) | ~101 mb/d |
| Listing | ERF (TSX, NYSE) |
Channels
Direct sales to refiners and utilities
Direct bilateral sales place barrels and molecules directly with refiners and utilities, with tailored terms matching product quality and delivery points to end users. This reduces intermediary costs and improves margins, supporting Enerplus’s 2024 average realized liquids price uplift and leveraging ~113,000 boe/d scale to strengthen strategic customer relationships.
Marketers and commodity traders
Marketers and commodity traders aggregate, blend and place Enerplus barrels, expanding reach into multiple regions and end markets and tapping global oil demand of about 101 mb/d in 2024 (IEA) to find buyers and price pools. They provide liquidity and optionality via hedged swaps and term lifts, crucial when takeaway or processing capacity is constrained, enabling timely sales and optimized netbacks.
Pipelines and gathering systems
Pipelines and gathering systems serve as Enerplus primary conduit for crude, gas and NGLs, leveraging firm capacity contracts that ensure flow assurance; US crude pipeline capacity is about 12 million b/d (EIA 2024). Pipelines lower transport emissions versus trucking by roughly 3–4x per barrel-mile and access to hubs like Cushing and Henry Hub improves real-time price discovery and liquidity.
Gas processing plants and fractionators
Gas processing plants and fractionators convert raw gas into residue gas and NGL purity products, creating additional saleable streams that in 2024 supported incremental midstream margins for producers like Enerplus. Processing contracts determine fees and shrink, directly affecting plant economics and liftings; 2024 contract terms continued to prioritize fee-for-service and keep-or-pay structures. Efficient fractionation improves overall netbacks by capturing NGL value and reducing off‑spec penalties.
Rail and trucking where needed
Rail and trucking supplement pipelines for flexibility and specialty grades, enabling Enerplus to reach niche markets and manage pipeline outages; in 2024 the company maintained ~120,000 boe/d production capacity while using third-party logistics to preserve market optionality.
- Supplement pipelines — specialty grades
- Manage outages — preserve sales
- Short‑haul — supports early production
- Debottlenecking — eases takeaway constraints
Multi-channel commercialization boosts netbacks and market access on ~113,000 boe/d
Enerplus sells via direct bilateral contracts, marketers/traders, pipelines/gathering, processors and trucking/rail to maximize netbacks and market access, leveraging ~113,000 boe/d production (2024) and realized liquids price uplifts. Pipelines and processors secure flow and value; traders provide liquidity and hedging; trucking/rail add flexibility during takeaway constraints.
| Channel | Role | 2024 metric |
|---|---|---|
| Direct sales | Higher margins | ~113,000 boe/d |
| Traders | Liquidity/hedges | Global oil demand 101 mb/d |
| Pipelines | Flow assurance | US capacity 12 mln b/d |
Customer Segments
Refineries and integrated oil companies
Refineries and integrated oil companies are primary buyers of crude streams, anchoring demand in a market with global oil consumption near 101.9 million b/d in 2024. They prioritize consistent quality and reliable delivery to feed plants that in the US total 18.6 million b/d operable capacity and ~93% utilization. Long-term offtake contracts stabilize refinery throughput, while pricing is highly sensitive to grade differentials and product-spec premiums.
Natural gas utilities and power generators
Natural gas utilities and power generators purchase residue gas from Enerplus to meet residential and power demand, with firm-delivery contracts emphasizing reliability and nominated volumes that vary seasonally. Seasonal peaks drive higher winter nominations for heating and summer demand for gas-fired peakers; U.S. gas-fired generation accounted for about 40% of electricity in 2024 (EIA). Creditworthy counterparties underpin stable sales and lower counterparty risk for Enerplus, supporting predictable cash flow and contract renewals.
Natural gas processors and petrochemical buyers
Natural gas processors and petrochemical buyers either buy NGLs or process them into purity ethane, propane, butane and natural gasoline, demanding volume, timing and purity certainty to meet feedstock specs. They are sensitive to NGL price spreads—EIA noted U.S. NGL production remained near 5 million barrels per day into 2024, keeping spreads and market tightness influential on margins. Co-product integration, such as steam cracker feed flexibility or LPG blending, can materially enhance margins when spreads are favorable. Suppliers must price and schedule to align with these volatility and timing constraints.
Marketers, traders, and aggregators
- Logistics/basis optimization
- Liquidity & market access
- Volatility absorption
- Balancing & inventory support
Industrial end users
Industrial end users consume large volumes of gas and liquids for heat and feedstock, demanding predictable pricing and reliable supply; Enerplus serves these needs through long-term sale agreements and supply contracts that often include tailored product specifications and delivery terms.
- Large-volume offtake
- Predictable pricing & supply
- Tailored specs
- Long-term agreements
Refineries, utilities, NGLs anchor demand; oil 101.9M b/d
Refineries and integrated oils anchor demand (global oil use 101.9M b/d in 2024; US operable refining 18.6M b/d at ~93% utilization) with grade-sensitive pricing. Utilities/generators drive seasonal gas demand (US gas-fired gen ~40% of power in 2024) under firm contracts. NGL processors and industrials value volume, purity and long-term offtakes (US NGL prod ~5M b/d); traders provide liquidity (CME gas avg 1.2M contracts/day 2024).
| Metric | 2024 |
|---|---|
| Global oil demand | 101.9M b/d |
| US refinery capacity | 18.6M b/d (93% util) |
| US NGL production | ~5M b/d |
| Gas-fired power share | ~40% |
| CME gas vol | 1.2M contracts/day |
Cost Structure
Drilling and completions capital
Drilling and completions capex represents the major share of Enerplus’s upfront investment, with the 2024 capex program ~US$650 million; costs are driven by rig dayrates, proppant (sand) and service-contract pricing. Pad efficiencies and multi-well design have lowered unit capex per BOE, while shorter cycle times materially improve IRR and cash-on-cash returns.
Lease operating and production expenses
Day-to-day lease operating and production expenses cover labor, chemicals, power and repairs to run wells and facilities; Enerplus reported total LOE reductions in 2024 with unit LOE around $6.50/boe as automation and digital controls lowered per-barrel costs. Increased uptime from predictive maintenance and remote ops drove higher production efficiency, cutting unit LOE further versus prior years.
Gathering, processing, and transportation
Gathering, processing and transportation expenses include fees for moving and conditioning hydrocarbons and often involve firm take-or-pay commitments that create fixed-cost obligations; optimizing routes and balancing access between pipelines reduces basis differentials and penalty exposure, while contract terms (tolls, fuel, take-or-pay liability and term length) materially affect per‑boe margins and cash flow in 2024.
Royalties, taxes, and regulatory compliance
Royalties to mineral owners scale directly with Enerplus revenues and volumes; production and severance taxes differ by jurisdiction (eg Alberta, North Dakota). Compliance, monitoring and reporting increase operating and capital costs, while good governance mitigates fines and project delays; US federal corporate tax remains 21% in 2024.
G&A and decommissioning obligations
Corporate overhead funds planning and control functions at Enerplus (NYSE: ERF, TSX: ERF), covering IT, insurance and professional services while management targets lean structures to minimize per-barrel G&A. Decommissioning obligations are recognized as asset retirement obligations (ARO) on the balance sheet and must be reserved for plugging and reclamation. Ongoing efficiency initiatives aim to reduce fixed cost per BOE.
- G&A: centralized planning, IT, insurance, professional services
- ARO: reserved for plugging and reclamation per financial statements
- Efficiency focus: lower fixed cost per barrel through streamlined structures
Drilling capex US$650m drives costs; LOE $6.50/boe falls; federal tax 21%
Drilling/completions capex (~US$650m in 2024) is the largest cost driver; pad efficiencies lower unit capex and shorten cycles. LOE fell to ~US$6.50/boe in 2024 via automation and predictive maintenance. Midstream fees, royalties and regional taxes (eg Alberta, ND) create semi-fixed charges; US federal tax 21% in 2024.
| Metric | 2024 |
|---|---|
| Capex | ~US$650m |
| LOE | ~US$6.50/boe |
| US Federal Tax | 21% |
Revenue Streams
Crude oil sales
Crude oil sales are Enerplus major revenue driver, priced off benchmarks such as WTI and Canadian heavy differentials (WCS), with 2024 average WTI around 83 USD/bbl influencing top-line pricing. Quality (light vs heavy) and field location drive netbacks through transportation and differential impacts. Enerplus employs both long-term contracts and spot sales to balance certainty and upside. Active basis management in 2024 improved realizations versus regional benchmarks.
Natural gas sales
Residue gas is sold at hubs under index or fixed-price terms, with Henry Hub averaging about 2.80 USD/MMBtu in 2024; seasonal and regional demand drive summer/winter spreads and basis differentials. Firm transport agreements expand market access and can raise realized netbacks. Strategic hedging historically covers a significant portion of volumes to smooth cash flows.
NGL sales
NGL sales (Y-grade plus purity products like propane, butane and natural gasoline) provide diversified income for Enerplus; in 2024 NGLs materially supported liquids revenue as Mont Belvieu-linked prices averaged near industry levels and seasonal propane strength boosted value. Realized NGL pricing tracks petrochemical demand and seasonality, recoveries hinge on third-party processing agreements, and shifts toward heavier or lighter product mix materially alter per‑barrel margins.
Hedge settlements and marketing gains
Hedge settlements and marketing gains use financial derivatives to offset price volatility; realized gains or losses flow directly to cash earnings and can swing quarterly cash from operations. Basis and location swaps improve netbacks by reducing regional price differentials; in 2024 global oil averaged about 80 USD/bbl, influencing hedge outcomes. Structured sales capture premiums via term and indexed contracts, enhancing realized price per unit.
- derivatives offset volatility
- realized gains impact cash earnings
- basis/location swaps boost netbacks
- structured sales secure premiums
Other operating income
Other operating income for Enerplus includes occasional asset-sale and surface-use proceeds, water handling/disposal fees, make-whole and deficiency recoveries, plus interest and ancillary items; these line items were disclosed in Enerplus 2024 filings as contributing to non-core cash flow.
- Asset-sale proceeds
- Surface-use payments
- Water handling/disposal fees
- Make-whole/deficiency recoveries
- Interest & ancillary items
Crude-driven revenues tied to WTI; gas and NGLs plus hedges smooth cash flow
Crude oil sales remain Enerplus primary revenue, priced off benchmarks (WTI avg 83 USD/bbl in 2024) with netbacks affected by quality, location and transportation differentials.
Natural gas and NGLs diversify revenue; Henry Hub averaged 2.80 USD/MMBtu in 2024 and Mont Belvieu-linked NGLs materially supported liquids income.
Hedge settlements, structured sales and occasional asset/ancillary proceeds smooth cash flow and can swing quarterly realized earnings.
| Metric | 2024 |
|---|---|
| WTI | 83 USD/bbl |
| Henry Hub | 2.80 USD/MMBtu |
| Global oil avg | 80 USD/bbl |