Halliburton is the world's second-largest oilfield services company — providing drilling, completion, stimulation and evaluation services to oil and gas producers globally. Unlike integrated majors, Halliburton's revenues are earned from the activity of oil companies exploring and developing fields — making the US rig count the primary timing signal, lagging Brent by 6–18 months.

The Rig Count as Lagged Signal

Oil producers increase drilling activity 6–18 months after Brent prices rise sustainably above $70–80/bbl — first assessing sustainability, then planning, then contracting services. This lag means Halliburton's recovery follows Brent's recovery. Investors who enter as the rig count bottoms can capture the services cycle uplift.

North American Completions: The Core Market

Halliburton is the leading completion services provider in North America — pumping fracturing fluids, deploying perforating guns on shale wells. When shale producers add fracturing crews, Halliburton's pricing escalates rapidly.

International Recovery: The Next Growth Phase

International markets represent approximately 45% of revenues. International oilfield spending — driven by Middle Eastern national oil companies — tends to lag North American activity by 1–2 years, providing a second wave of growth.

Technology Leadership in Completion Tools

Halliburton's iCruise rotary steerable system, Zeus electric fracturing fleet and Prodigi autonomous fracturing platform command premium pricing and win contracts from cost-conscious operators prioritising production optimisation.

Key Risks

Shale operator capital discipline — if operators choose to return cash rather than grow production — limits rig count recovery even at high oil prices. Downhole technology competition from Baker Hughes and SLB is intense.

Cycle Performance Summary

Aker BP is Norway's largest pure-play oil producer — operating exclusively on the Norwegian Continental Shelf with no downstream or renewable energy activities. This pure-play concentration makes it the highest-beta Brent cycle expression among large-cap Oslo Børs energy companies — when Brent crashes, Aker BP falls furthest; when it recovers, Aker BP rises most.

Why Brent Drives Aker BP

Aker BP produces approximately 420,000 barrels of oil equivalent per day from Norwegian fields including Johan Sverdrup, Valhall and Ula. Unlike Equinor (which has renewables, gas trading and downstream operations), Aker BP is 100% Norwegian upstream oil — making its earnings a near-direct function of the Brent price. At $50/barrel, Aker BP earns modest cash flow. At $100+/barrel, it generates exceptional free cash flow and pays large special dividends.

Norway's unique 78% upstream tax regime means Aker BP effectively has 78% of its capex funded by Norwegian taxpayers at low oil prices — reducing the effective cost of staying invested through cycles and enabling aggressive development even at cycle lows.

The 2015–2022 Cycle: +388% in 87 Months

Brent fell below $50/barrel in March 2015 as Saudi Arabia defended market share. Aker BP (then Det norske oljeselskap, before merging with BP Norway) fell to NOK 80. The discovery and development of Johan Sverdrup — one of the world's largest oil fields — combined with the Brent recovery, lifted Aker BP to NOK 390 by June 2022. A gain of 388% in 87 months, outperforming Equinor (+196%) and Subsea 7 (+130%) substantially.

Aker BP vs. Equinor

Aker BP's +388% dramatically outperformed Equinor's +196% over overlapping Brent cycles. The reasons: Aker BP is a pure-play operator with no renewables dilution, Johan Sverdrup came onstream and ramped up during the cycle, and Aker BP's smaller size creates more earnings leverage per barrel of oil price increase than Equinor's massive diversified portfolio.

Key Risks

Aker BP's main risks are Norwegian Continental Shelf depletion (its fields will eventually decline), the Aker ASA controlling ownership structure, and pure-play oil exposure in an energy transition environment. Its 100% Norwegian focus reduces geopolitical risk but creates concentration.

Cycle Performance Summary