Why Oil Prices and Geopolitics Matter Less to Suncor Canadian Oilsands Than Ever

Suncor explained that oil prices and geopolitics now have a limited impact on its business because its fully integrated model — from oil sands to upgrading, refining, and marketing — naturally offsets price volatility across the value chain. With a low-$40 WTI breakeven, record utilization, and strong downstream cash flow, Suncor generates stable free cash flow and shareholder returns even when oil prices fall or geopolitical headlines intensify.

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Why the Canadian Deep Basin Still Matters

The Canada Deep Basin has evolved into a low-decline, infrastructure-backed cash engine where operators prioritize optimization, cost compression, and free cash flow over volume growth. For companies like Whitecap and Tourmaline, it provides inventory depth and strategic flexibility—supporting steady production and margins while higher-return growth capital flows elsewhere.

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Brazos Midstream’s Sundance II: From August 2025 Announcement to Early-2026 Execution

Brazos Midstream’s Sundance II project moved from a high-profile August 2025 state-backed announcement to on-the-ground execution in early 2026, with new interconnect infrastructure quietly registered in Martin County. The combination shows Brazos isn’t just adding processing capacity — it’s building the connective plumbing needed to reliably move growing Permian associated gas volumes for the long term.

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Continental Resources — Nobles White Pad

Continental Resources’ Nobles White pad in Midland County is a fully permitted, factory-style shale development, with standardized horizontal wells, centralized surface infrastructure, and both well and facility approvals completed in advance of execution. With regulatory risk removed and permitting sequenced intentionally, the project now simply awaits drilling and completion to move efficiently from inventory to production.

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A Wildcat a Grade A Permian Drilling Program — Diamondback Energy, Reagan County, Texas

Diamondback Energy executed a tightly concentrated, factory-style drilling program in Reagan County, combining single-section pad development, uniform horizontal well design, and a disciplined drilling cadence. From batch permitting to post-completion facility air permitting, the project reflects Grade A Permian execution focused on repeatability, efficiency, and production readiness rather than exploratory risk.

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Oklahoma Drilling Rig Update — rig count increased from 43 to 46

Oklahoma’s rig count increased week over week, driven entirely by a five-rig gain in the Cana Woodford, which now stands at 22 rigs and is clearly absorbing capital from other in-state plays. Declines in the Granite Wash and Ardmore Woodford reinforce that this is targeted concentration, not broad-based growth, with activity led by repeat operators like Validus Energy, Continental Resources, and Mewbourne using established contractors.

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Devon + Coterra Merger — Executive Takeaways (Feb 2, 2026)

The Devon–Coterra merger creates a $58B, >1.6 MMBOE/d large-cap shale leader anchored by a dominant Delaware Basin position, deep sub-$40/bbl inventory, and a balanced oil-gas portfolio built for durability rather than growth. With $1B of run-rate synergies, disciplined reinvestment (<50%), and strong gas leverage to LNG and power demand, the combined company is positioned to deliver resilient free cash flow and accelerated shareholder returns through the cycle.

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Devon Energy & Coterra Energy Merge to Create a Premier Large-Cap Shale Operator

Devon Energy’s all-stock merger with Coterra Energy creates a premier large-cap shale operator anchored by a dominant core-of-core position in the Delaware Basin, delivering more than 10 years of high-quality inventory and resilient free cash flow. The combination unlocks $1 billion of annual pre-tax synergies while reinforcing capital discipline, balance-sheet strength, and shareholder returns through the cycle.

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Exxon’s Permian Factory Model in Action:RICHARDS-GRISHAM Lease

Exxon’s RICHARDS-GRISHAM lease demonstrates a true Permian factory model, with tightly batched permits, standardized well designs, predictable drilling cadence, and infrastructure timed precisely to move from execution to production. With identical geology, block position, and development logic, the adjacent EPLEY-GLASSCOCK lease is expected to follow the same repeatable manufacturing approach—making future activity a matter of scheduling, not subsurface risk.

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