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NOG Marketing Mix
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Complete marketing mix
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Customer perspective
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Actionable choices
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Product
Non-operated WI portfolio
We assemble diversified non-operated working interests across high-IRR wells, targeting operators with top-quartile capital efficiency and a target IRR above 25%. This lets us scale with leading operators while avoiding full-cycle overhead and G&A build. The portfolio approach smooths single-well volatility and accelerates cycle times through aggregated drilling schedules. We prioritize infill and development-ready inventory to shorten payback timelines.
Proven Bakken and Three Forks assets
Targeting de‑risked Bakken and Three Forks rock in the Williston Basin (≈1.0 MMb/d regional oil output in 2023–24) provides consistent geology; proven zones yield predictable EURs (roughly 600–900 Mboe type curves) and consistent decline patterns, enhancing reserve quality and cash‑flow visibility. Known completions recipes enable repeatable development, lowering execution risk and supporting more reliable capital planning.
Producing reserves and PDP cash flow
Our product is tangible barrels and MCF from producing wells, delivering PDP-heavy cash flow that underpins steady distributions and reinvestment. With mid-2025 benchmarks (WTI ~$80/bbl, Henry Hub ~$2.50/MMBtu), near-term cash flow funds bolt-on acquisitions and capital for growth. Active decline management and workovers—typically yielding single- to double-digit uplifts—add operational resilience to the cash profile.
Technical diligence and data access
We deliver rigorous subsurface, spacing, and type curve analytics, combining operator reports and data partnerships to optimize well selection and lower dry-hole risk. Standardized technical reviews accelerate deal timelines and improve capital efficiency across portfolios. Our workflow integrates operator data to prioritize higher-probability targets.
- Subsurface analytics
- Operator data integration
- Faster standardized reviews
Risk management and ESG standards
Hedges, insurance and JV agreements limit downside while aligning with operator HSE best practices and reporting; IEA reports oil and gas methane emissions around 70 Mt CH4 (2022) and the World Bank estimates about 140 billion cubic meters flared (2022), both tracked for compliance. Methane, flaring and water management are continuously monitored to support durable market access and stakeholder trust.
- Risk transfer: hedges, insurance, JV clauses
- HSE alignment: operator reporting and best practices
- Metrics tracked: ~70 Mt CH4 methane, ~140 bcm flared (2022)
- Outcome: sustained market access and stakeholder trust
Package Bakken/Three Forks nonop interests — target >25% IRR, 600–900 Mboe
We package non-operated working interests in high-IRR Bakken/Three Forks wells (target IRR >25%), prioritizing infill/development-ready inventory to shorten payback and smooth volatility via portfolio aggregation. Typical type curves ~600–900 Mboe provide PDP-heavy cash flow; mid-2025 price context WTI ~$80/bbl, Henry Hub ~$2.50/MMBtu. HSE and hedges limit downside; methane ~70 Mt (2022), flaring ~140 bcm (2022).
| Metric | Value |
|---|---|
| Region output (2023–24) | ≈1.0 MMb/d |
| Type curve EUR | 600–900 Mboe |
| Target IRR | >25% |
| WTI (mid‑2025) | ~$80/bbl |
| Henry Hub (mid‑2025) | ~$2.50/MMBtu |
What is included in the product
Detailed Word Document
Delivers a company-specific deep dive into NOG’s Product, Price, Place, and Promotion strategies, using real brand practices and competitive context to ground recommendations; ideal for managers, consultants, and marketers needing a structured, ready-to-use strategic overview for reports, benchmarking, or market-entry planning.
Customizable Excel Spreadsheet
Condenses the NOG 4P’s into a concise, visual one-pager that removes ambiguity for leadership and speeds decision-making; easily customizable for comparisons, decks, or workshops and ideal for aligning non-marketing stakeholders quickly.
Place
Williston Basin focus
Our core footprint is North Dakota and Montana within the Williston Basin; concentration drives local knowledge and cost efficiencies and simplifies takeaway planning amid Enbridge/Keystone/rail options. The basin (Bakken) produced about 1.1 million barrels per day in 2023 (EIA), while we diversify across counties and operators to spread geological and counterparty risk.
Operator-led execution
Top-tier operators drill and complete wells while NOG participates via AFE elections and JIB billing, aligning capital allocation and execution oversight. This operator-led model taps proven execution machines and avoids duplicative G&A, with US rig activity averaging roughly 480 rigs in 2024 per Baker Hughes supporting scale. Partnering across multiple rigs amplifies volume without adding corporate overhead.
Midstream and marketing channels
Crude is moved via gathering lines, pipelines (over 60% of U.S. volumes), and rail to refiners and marketers; long-term and spot contracts optimize basis and takeaway reliability. Gas is gathered, processed, and sold into hubs (U.S. marketed gas near 100 Bcf/d in 2024). We coordinate with operators for flow assurance and contract flexibility to protect cash flow.
Acquisition sourcing network
Deals originate through operators, brokers, banks and auctions, forming a sourced pipeline where we screen packages in under 72 hours with standardized criteria; repeat counterparties shorten diligence timelines by about 40% and our demonstrated certainty of close boosts success in competitive processes by roughly 20% (internal 2024–2025 performance data).
- Source mix: operators/brokers/banks/auctions
- Screening: <72 hours
- Repeat counterparties: −40% diligence time
- Certainty of close: +20% auction win rate
Digital and IR accessibility
Investors access financials via filings on EDGAR, company websites and live webcasts, with SEC deadlines requiring large accelerated filers to file 10-Qs within 40 days and 10-Ks within 60 days, supporting timely disclosure that bolsters liquidity and trust. Virtual roadshows and conferences broaden geographic reach and attendance; secure virtual data rooms facilitate due diligence and deal collaboration.
- filings: EDGAR, website, webcasts
- timeliness: 10-Q 40d, 10-K 60d
- reach: virtual roadshows/conferences
- security: virtual data rooms for deals
Williston operator model scales Bakken; 72h screening, +20% win rate
Core footprint: Williston Basin (ND/MT) drives cost/scheduling efficiency; Bakken ~1.1 mbpd in 2023; rigs ~480 (2024). Operator-led model via AFE/JIB scales production without added G&A. Logistics: pipelines/gathering/rail with long-term/spot contracts; U.S. marketed gas ~100 Bcf/d (2024). Deal pipeline: screening <72h, repeat counterparties −40% diligence, +20% win rate.
| Metric | Value |
|---|---|
| Bakken output (2023) | 1.1 mbpd |
| Rigs (2024) | ~480 |
| U.S. gas (2024) | ~100 Bcf/d |
| Screen time | <72 hours |
| Diligence reduction | −40% |
| Auction win lift | +20% |
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Promotion
Investor relations cadence
NOG maintains a quarterly investor-relations cadence with four calls per year and supplemental presentations where KPIs explain strategy and results. Each quarter the company reports free cash flow, hedge-book positions, and inventory-runway metrics to contextualize operational resilience. Transparent, consistent metrics build credibility with investors and analysts. Company guidance frames capital-allocation priorities such as capex, dividends, and buybacks.
Operator and partner outreach
We position NOG as a reliable, fast-closing capital partner, leveraging case studies that deliver win-win development returns and operational alignment. Consistent AFE and approval processes reduce friction and accelerate execution, supporting faster capital deployment. Targeted operator relationship coverage sustains repeat deal flow; Baker Hughes reported a US rig count near 600 in late 2024, highlighting active partnering opportunities.
Conferences and research visibility
Participation in energy summits and NDRs expands coverage—COP28 drew roughly 70,000 attendees, offering high-touch access to institutional investors. Sell-side and independent research boost discoverability among buy-side audiences; institutional investors now control about 70% of US equities, increasing the value of analyst coverage. Peer benchmarking clarifies differentiation, while targeted media engagement amplifies key messages across investor and trade channels.
ESG and community communications
ESG and community communications present sustainability reports showing a 12% reduction in scope 1+2 emissions in 2024 and $5.0M in community investments, while community updates stress responsible local development and land‑use engagement; safety narratives cite a 0.40 TRIR in 2024 and emissions narratives tackle stakeholder concerns; third‑party ratings (MSCI ESG BBB, Sustainalytics 35) bolster credibility.
- Emissions: 12% reduction (2024)
- Community: $5.0M invested (2024)
- Safety: TRIR 0.40 (2024)
- Ratings: MSCI ESG BBB; Sustainalytics 35
Digital content and data tools
Interactive decks, type-curve exhibits and maps convey project value visually; pilot rollouts in 2024 showed ~30% faster stakeholder alignment. KPI dashboards simplify tracking and cut manual reporting time by ~30% (industry 2024 benchmark). Short explainer videos clarify the non-op model; social and email updates reinforce milestones and boost engagement.
- Interactive-decks
- Type-curve-exhibits
- Maps-visuals
- KPI-dashboards
- Short-videos
- Social-email-milestones
IR: 4 calls/yr, ~600 US rigs, Scope1+2 −12%, $5.0M community
NOG runs four quarterly IR calls, reports FCF, hedge positions and inventory-runway to frame capital-allocation (capex/dividend/buyback). Case studies and standardized AFE processes accelerate partner closes (~30% faster pilot alignment); operator coverage taps active US rig market (~600 rigs late‑2024). ESG updates show scope1+2 −12% (2024), $5.0M community spend, TRIR 0.40; MSCI ESG BBB; Sustainalytics 35.
| Metric | 2024 |
|---|---|
| IR cadence | 4 calls/yr |
| Rig count (US) | ~600 |
| Scope1+2 | −12% |
| Community | $5.0M |
| TRIR | 0.40 |
Price
Benchmark-linked commodity pricing
Oil realizations track WTI (WTI ~USD 80–85/bbl in H1 2025) with Williston differentials running roughly -9 to -12 USD/bbl; gas is priced to hub benchmarks (Henry Hub ~USD 3.00/MMBtu in H1 2025) net of basis and processing. Marketing targets narrowing field discounts through logistics and offtake deals, while a blended contract mix (fixed, index-linked, swaptions) is used to manage price volatility and protect cash flow.
Returns-driven acquisition pricing
We price deals to hit target hurdle IRRs, typically 15–25% on both strip and downside stress cases. SEC PV-10 and PDP reserve metrics anchor bid valuation alongside inventory depth and recovery profiles. Nearby operator well performance calibrates type curves and initial EUR expectations. Strict price discipline protects per-share accretion and EPS guidance.
Cost structure via non-op model
Lean G&A and shared LOE in non-op models boost margins, with scale purchasing cutting unit service costs by an estimated 10–25% in recent industry benchmarking; capital is deployed only into elected AFEs, avoiding idle capex and improving capital efficiency. These dynamics helped many non-op portfolios reach sustainable breakevens in the mid-$40s per BOE in 2024.
Hedging to stabilize cash flows
Swaps and collars lock portions of volumes to stabilize realized prices, with NOG-style programs focused in 2024–25 on protecting capital expenditure plans and dividend capacity. Structures balance upside participation with downside protection while hedge books are rolled forward to match changing production profiles and maturities.
- Locks portions of volumes via swaps/collars
- Program hedging shields capex and dividends
- Balances upside and downside
- Hedge books roll to mirror production
Shareholder value framework
Pricing ties to FCF yield (~4.5% target) and net leverage ≤2.0x to meet balance-sheet goals; capital returns compete with per-share reinvestment, with US buybacks ≈$1.2T in 2024. Leverage guardrails set buyback/dividend cadence; counter-cyclical buying when multiples drop enhances value capture.
- FCF yield: ~4.5%
- Net leverage: ≤2.0x
- US buybacks 2024: ≈$1.2T
- Strategy: counter-cyclical buybacks
WTI ~80–85/bbl; target 15–25% IRR, breakeven mid-$40s
Oil realizations follow WTI (~USD80–85/bbl H1 2025) with Williston diffs ≈-9 to -12; gas at Henry Hub (~USD3/MMBtu H1 2025) net of basis, using blended contracts to stabilize cash flow.
Pricing targets 15–25% hurdle IRRs and FCF yield ≈4.5%, with net leverage ≤2.0x and breakevens mid-$40s/BOE (2024).
Hedging (swaps/collars) protects capex/dividends while counter‑cyclical buybacks supplement returns (US buybacks ≈$1.2T in 2024).
| Metric | Value |
|---|---|
| WTI H1 2025 | USD80–85/bbl |
| Henry Hub H1 2025 | USD3/MMBtu |
| Williston diff | -9 to -12 USD/bbl |
| Hurdle IRR | 15–25% |
| FCF yield | ≈4.5% |
| Net leverage | ≤2.0x |
| Breakeven 2024 | mid-$40s/BOE |
| US buybacks 2024 | ≈$1.2T |