null

null

null

null

null

null

null

null

null

Net debt ~$1.4B as of 2024; Net Debt/EBITDA ~3.5x; 20% rate rise adds ~$28M annual interest expense given floating-rate exposure

Approximately 60-70% of debt is floating-rate; 20% rate increase on ~$1.4B debt adds roughly $25-30M annual interest burden, compressing EBITDA margin by ~5pp

High intensity; OPEC+ supply decisions and Russia-Ukraine conflict drive price volatility.

Persian Gulf (rig mobilization/crew logistics) and Strait of Hormuz (West Africa/Middle East client access) are top two chokepoints

Top markets: Middle East (USD-pegged, minimal FX risk), West Africa (NGN/XOF devaluation risk high), Southeast Asia (moderate IDR/MYR volatility)

Operates across Middle East, West Africa, Southeast Asia, and Latin America; USD-denominated contracts largely hedge sovereign currency devaluation exposure

High intensity; commodities: Crude Oil, Natural Gas, Coal, Refined Petroleum Products, Uranium, Steel (equipment); geopolitical: OPEC+ supply decisions and Russia-Ukraine conflict drive price volatility.

Keppel and Cosco shipyards represent critical non-substitutable rig construction/repair capacity; no single vendor exceeds 30% but switching costs are very high

Asset-heavy offshore drilling services; cloud infrastructure termination is operationally negligible; mission-critical systems are rig-based and self-contained

Secondary IT systems (ERP, back-office) use cloud but are non-critical to revenue generation; 30-day termination manageable via migration or alternate provider

Minimal API coupling risk; operations driven by proprietary rig equipment and OEM software (NOV, Schlumberger); no significant third-party API dependency

Revenue from day-rate drilling contracts for oil majors; clearly qualifies as service revenue, not a security; Howey Test risk index is effectively zero

High

Limited GDPR/CCPA exposure; primary data is operational/drilling telemetry, not consumer PII; some EU crew HR data requires GDPR compliance, low overall risk

Low antitrust risk; jackup rig market fragmented among Valaris, Shelf Drilling, Arabian Drilling; Borr holds ~5-7% global jackup fleet share

High burden; regimes: EPA, FERC, DOE, CFTC, OSHA, SEC; Accelerating emissions mandates and methane rules threaten capex economics.

~85-90% recurring via multi-year day-rate contracts (avg duration 1-3 years); ~10-15% transactional (mobilization fees, short-term spot contracts)

Day-rate drilling services charged per operating day (~$90,000-$160,000/day per rig); 22 premium jackup rigs generating contracted utilization-based revenue

Day-rate pricing tied to oil price cycle and rig scarcity; current market supports $100K-$160K/day; stress scenario: oil at $50/bbl compresses rates 20-30%

Moderate-to-high in current upcycle; premium jackup scarcity and long lead times for newbuilds give Borr negotiating leverage; rated 7/10 pricing power

Target EBITDA margin 40-50%; gross margin on day-rate contracts approximately 50-60% before SG&A and D&A at current utilization (~95%)

No free-rider leakage; contracts are bilateral and capital-intensive; early termination clauses protect revenue; churn risk low but oil price-correlated

Revenue growth is asset-linear not headcount-linear; adding a rig requires ~120 crew but incremental corporate headcount is minimal; sublinear corporate scaling

Marginal revenue growth driven by rig activation and day-rate escalation, not headcount; doubling revenue requires ~doubling rig fleet, not doubling corporate staff

Not applicable; Borr operates as a direct asset owner/operator, not a franchise model

At 10x scale (~220 rigs), jackup market saturation likely; current CAC low via tender processes; contract win rates ~30-40% on bids; scale economics plateau

No meaningful network effects; drilling services are non-networked; competitive advantage from fleet quality, HSE reputation, and operator relationships only

AI displacement risk low; offshore drilling requires physical human presence; AI assists with predictive maintenance and drilling optimization but cannot displace rigs

Tier 3 (cyclical); heavily correlated to oil capex spending; 2020 downturn caused 30-40% day-rate compression and utilization collapse; not recession-resistant

National oil companies (Saudi Aramco, ADNOC, QatarEnergy) and international oil majors (TotalEnergies, Shell); top 3 clients likely represent 50-60% of revenue

Independent E&P operators in West Africa and Southeast Asia; higher concentration risk segment with shorter contract durations and higher churn probability

["11-0000 Management Occupations", "13-0000 Business and Financial Operations Occupations", "15-0000 Computer and Mathematical Occupations", "17-0000 Architecture and Engineering Occupations", "19-0000 Life, Physical, and Social Science Occupations", "23-0000 Legal Occupations", "41-0000 Sales and Related Occupations", "43-0000 Office and Administrative Support Occupations", "47-0000 Construction and Extraction Occupations", "49-0000 Installation, Maintenance, and Repair Occupations", "53-0000 Transportation and Material Moving Occupations"]

0.33 (HIL — ~33% of characteristic roles agent-automatable)

Capital allocated to rig upgrades and maintenance (~$50-80M/yr); no major newbuild program; reallocation from legacy capex to operational efficiency rather than fleet expansion

CIK 0001716947; regulatory (BSEE, NORSOK, IMO) and commodity (Brent crude) exposure interact to compress margins when oil falls below $60/bbl and compliance costs are fixed

BORR (NYSE); trading at ~4-6x EV/EBITDA, discount reflects jackup cycle peak fears and leverage; geopolitical risk in Middle East concentration partially unpriced