Shenandoah outcome1 Jul 2025 19:40
Asked ChatGBT what the risk of disappointment is for a project such as Shenandoah, and am slightly alarmed by the answer I got. I saw it as a foregone conslusion that it will come in as expected:
The short answer: there is significant risk that Shenandoah’s flow rates underperform expectations — this is quite common in oil- and gas-field startups. Let’s break down why, plus some real-world examples of larger projects that failed or struggled after hitting production.
⸻
⚠️ Why fields often disappoint on flow rates
• Reservoir uncertainty
A Westwood Global Energy Group study of 70 fields found 50% failed to meet production expectations, typically because subsurface characteristics like reservoir volumes, pressures, connectivity, and rock quality were misestimated . Notably, 70% of fields with fewer than five appraisal wells underperformed, highlighting the importance of thorough appraisal ().
• Appraisal sophistication matters
Insufficient or shallow appraisal programs dramatically increase uncertainty—operators often “learn as they go,” drilling into production, sometimes with disastrous results ().
• High likelihood of underperformance
Statistically, about half of new fields underdeliver relative to expectations, even among well-studied assets .
⸻
Real-world “flops” and cautionary tales
1. Apsara Field (Cambodia)
• Developed by KrisEnergy (ex-Chevron acreage), launched production in late 2020–2021.
• Planned 7,500 bpd but peaked around 3,500 bpd, then averaged just 2,800 bpd.
• Underperformance led to company liquidation after ~300,000 barrels were produced .
2. Yme Field (North Sea, Norway)
• Discovered 1987, first produced mid-1990s, then abandoned in 2001.
• Multiple redevelopment attempts by Talisman (2008) failed due to structural issues. It never re-entered production under that scheme .
3. Kashagan (Kazakhstan)
• One of the world’s largest finds (~13 bn barrels), discovered 2000.
• Despite huge investment (~US $40 bn), start-up was plagued by leaks and technical setbacks.
• Initial production began ~2013 but was quickly stopped, pushing back full output and turning projects into multi-year debacles and write-downs .
4. Comparable patterns in mature fields
• Large, technologically “maxed-out” fields (e.g. Ghawar, Oman) have shown sharp declines despite aggressive secondary recovery — a reminder that technical limits and reservoir damage are real .
⸻
What these lessons mean for Shenandoah
1. Reservoir risk is real. Even large and well-appraised fields can deliver as much as 10–60% less initial output than expected .
2. Probability of disappointment is high. Data-driven benchmarking indicates ~50% chance of underperformance on flow rates.
3. Robust appraisal is critical. The fewer the appraisal wells and data, the greater the downside risk.
4. Bad outcomes can be extreme. Pr
Sign In
Follow the stocks
