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Net debt ~USD 2.5B pre-merger; net debt/EBITDA ~1.8x; a 200bps rate rise adds ~USD 50M annual interest cost on floating facilities

Approximately 30-40% of debt was floating rate; 200bps increase compresses net income by ~USD 40-55M, ~8-12% EPS impact

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

Strait of Malacca (LNG tanker routing from PNG to Asian buyers) and Coral Sea/Torres Strait passage for equipment supply

Revenue primarily in USD (LNG contracts); PNG Kina exposure on local costs; minimal FX devaluation risk on revenue side

Operations concentrated in Papua New Guinea (~90% of revenue) plus Alaska and Middle East exploration; PNG Kina devaluation risk on opex

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.

ExxonMobil as operator of PNG LNG project represents non-substitutable operational dependency; operator controls ~70% of production decisions

Upstream oil and gas producer; no material cloud infrastructure dependency; operations are field-based and industrial, not cloud-native

SCADA/industrial control systems used for field operations; cloud termination would cause administrative disruption only, not production halt

Low API coupling risk; company uses industrial OT systems and standard petroleum engineering software (Halliburton, Schlumberger), not proprietary APIs

Not applicable; revenue from commodity hydrocarbon sales does not constitute an investment contract under Howey Test

High

Minimal GDPR/CCPA exposure; no consumer data collected; operations in PNG governed by local data laws; limited EU/California customer base

Low standalone antitrust risk; merger with Santos (2022) reviewed by ACCC and FIRB but approved; combined entity holds no dominant domestic market position

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

~80% transactional via spot and long-term LNG offtake contracts; ~20% quasi-recurring via multi-year oil-linked LNG sales agreements

Commodity sales of LNG, crude oil, and condensate; pricing linked to JCC (Japan Crude Cocktail) and Brent benchmarks

Oil-linked LNG contract pricing (JCC-indexed); stress scenario at USD 40/bbl Brent reduces revenue ~40%; breakeven ~USD 35/bbl at PNG LNG

Low standalone pricing power; price-taker in global LNG market; long-term contracts provide partial insulation but no ability to set prices

Upstream gross margin ~55-65% at USD 70/bbl Brent; highly sensitive to oil price; operating cost ~USD 8-12/boe at PNG LNG

No free-rider risk; LNG buyers under take-or-pay contracts; contract counterparties include Japanese utilities and Chinese NOCs with strong covenant structures

Revenue growth is capital-linear, not headcount-linear; doubling production requires major capex (new wells, trains) but headcount grows sublinearly ~20-30%

Highly capital-intensive; marginal cost of new LNG train ~USD 3-5B; once built, incremental operating cost low; classic high-fixed-cost upstream model

Not applicable; Oil Search operates no franchise network

At 10x scale, LNG buyer concentration risk increases; global LNG market depth sufficient but counterparty diversification becomes critical constraint

No network effects; hydrocarbon commodity business; value derived from resource base and infrastructure, not user scale

AI displacement risk low for core production; AI applicable to seismic interpretation and reservoir modeling, reducing exploration capex ~5-10% over time

Moderate-low recession resistance; LNG demand relatively sticky (utility contracts) but oil price crashes during recessions compress margins significantly

Asian LNG buyers: Japanese utilities (JERA, Osaka Gas), Chinese NOCs (Sinopec), Korean buyers representing ~60-70% of LNG offtake

Australian domestic gas market and oil/condensate sold to refinery customers; top-3 customers likely represent >50% of total revenue

["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 PNG LNG expansion (P'nyang field) and Alaska North Slope; legacy maintenance capex ~USD 300-400M/yr; growth capex episodic and lumpy

Oil Search was listed on ASX (OSH) and POMSoX; acquired by Santos in 2022; no SEC CIK as it was not a US-registered issuer

OSH (ASX) trading reflected PNG sovereign risk, oil price discount, and PNG LNG project execution risk; absorbed into Santos (STO.ASX) at ~0.6275 STO shares per OSH share