Papua New Guinea (PNG) represents one of the world's most geographically demanding and logistically constrained operating environments. While the country boasts an exceptional historical exploration success rate of 48% for new field wildcats, the immense logistical burden makes exploration and production exceptionally expensive.
The geological setting of PNG—comprising rugged fold belts and remote foreland basins—forces operators to rely almost entirely on heavy-lift helicopter support for onshore seismic acquisition and drilling operations. Consequently, 2D seismic acquisition costs frequently exceed $200,000 per kilometer, and onshore highland exploration wells routinely cost in excess of $100 million each. This stands in stark contrast to analogue basins like the Alaska North Slope, where mature infrastructure allows onshore wells to be drilled for less than $30 million.
The crown jewel of the nation’s energy sector is the $19 billion PNG LNG project operated by ExxonMobil. The project, which commenced production in 2014 and relies on gas sourced from the Hides, Angore, Juha, and Kutubu fields, has been wildly successful, allowing the consortium to fully retire its $16 billion bank-financed debt six months ahead of schedule. Repsol also engaged in significant exploration activities within the region. However, due to the exorbitant operating costs, shifting capital allocation strategies, and a dry well exploration campaign, Repsol was forced to record severe pre-tax impairments of $786 million in 2019, which included write-downs on exploration and development assets across PNG, Vietnam, and Brazil. The nation's second major project, Papua LNG, has also faced severe delays, with cost estimates rising from $10 billion to $18 billion and FID continually pushed back to 2025.
| Exploration Metric | Papua New Guinea (Papuan Basin) | Alaska (North Slope) |
| Geological Setting | Fold Belt & Foreland Basin | Fold Belt & Foreland Basin |
| Discovered Volume | ~5 billion BOE (89% gas) | ~37 billion BOE (78% oil) |
| Average Well Cost (Onshore) | >$100 million per well | <$30 million per well |
| Average Seismic Cost | 2D >$200k/km | Standard 2D & 3D (cost efficient) |
| Infrastructure Access | Requires entirely new infrastructure | Open access pipeline (TAPS) |
Executing tubular running services in PNG requires meticulous planning to account for extreme weight restrictions and the modular assembly required for helicopter transport to remote highland drill sites. Between 2015 and 2019, regional management teams successfully executed a new country entry into PNG. The work performed involved managing complex multicultural teams as the sole American expatriate, forecasting business, and running P&L in a severely depressed market. Despite the high costs and market downturns that forced operators like Repsol to take impairments, the service sector reorganized its commercial department structure and strategy to better align with client objectives, ultimately growing sales from $41 million to $50 million across 17 APAC countries, leading 270 team members through the downturn.