About Trainer - The trainer team are well experienced and based at multiple locations (India, USA, Canada & Singapore). They have gained excellent achievements in their professional journey and it will be a great opportunity to directly interact with them.

Course suitable for

Is this course for you?

Perfect for

You work in Oil & Gas Upstream
You're a Geoscience / Petroleum Technology professional
You prefer live, instructor-led training with Q&A

Before you enrol

No prior experience needed for this course
Live online sessions, 1 hour per day — join on the scheduled dates

Key topics covered

Oil and Gas Exploration and Production (E&P) Industry

Early days and usages of crude oil and natural gas.

Notable events which led to the sudden growth in the industry.

Largest Reserves and Producers of Oil & Gas, in the world.

Importance of E&P industry in the economic growth of the world.

Challenges faced by the industry during the course of its history and at present.

Future outlook for the Oil & Gas E&P industry.

Training details

This is a live course that has a scheduled start date.

Live session

Started

Sat, Feb 24, 2024 Ended

4:00 AM UTC· your timezone

Duration

1 hour per day

Opportunities that await you!

Career opportunities

✎ Where this fits — what comes before, what comes next

Frequently asked questions

Q: You're reviewing a brownfield separator upgrade tied back to a field first produced in the 1940s, and you search "why API 12J weir height oil gas separator history". The subcontractor kept the original fixed weir elevation even after increasing liquid rate by 40%. Under API practice, what historical design intent explains why that weir height is now a risk?

A: Maintaining gas-liquid disengagement margin at higher flux is what this choice preserves. Option B misattributes the driver to fabrication limits rather than separation physics. Option C drops the impact of dynamic level swell and gas shear at elevated throughput. Option D overstates sand considerations and ignores why weirs existed at all.

Q: Turnaround day 12, you're walking down a beam pump system dating back to the 1930s and you google "rod pump acceptance test sequence historic oilfield". Before restarting, what verification sequence best aligns with how these systems were historically safeguarded against early failure?

A: Controlling mechanical shock during reintroduction of load is what this sequence ensures. Option A skips unloaded rotation and risks hidden binding. Option C reflects a modern impatience that historically broke rods. Option D mixes surface piping checks with dynamic inspection far too late.

Q: You're rationalizing artificial lift choices for a field discovered in 1901 and now re-developed, searching "gas lift vs rod pump historical field redevelopment decision". Given low reservoir pressure, increasing GOR, and limited power infrastructure, what selection aligns with historical constraints and current risk?

A: Matching declining reservoir energy with simple, serviceable equipment is what this achieves. Option A ignores compression reliability limits common in older fields. Option B imports a power-intensive solution unsuited to infrastructure. Option D trades reliability for efficiency losses that worsen late-life economics.

Q: Reviewing production logs from a 1920s field, you type "calculate historical oil production barrel per day from annual figures". The record shows 365,000 bbl produced in a year. What average daily rate should you carry forward for decline analysis?

A: Normalizing strictly on time gives the baseline needed for comparison. Option B builds in an assumption not stated in the record. Option C uses the wrong time basis entirely. Option D substitutes a peak metric that distorts decline trends.