While working on a mature field, the production rate had declined after primary depletion.

I needed to evaluate options to sustain and improve recovery.

Described primary recovery as natural reservoir pressure drive and secondary recovery as artificially maintaining pressure using water or gas injection, highlighting mechanisms, equipment, and typical recovery increments.

The team selected a water‑flood project, increasing recovery by ~15% over the next three years.

Assigned to plan drilling for an offshore HPHT well with 15,000 psi and 350 °F bottom‑hole temperature.

Select a drilling fluid that ensures wellbore stability, mud‑cake integrity, and equipment safety.

Evaluated fluid density, rheology, thermal stability, inhibition properties, and environmental compliance; chose a synthetic oil‑based mud with high thermal stability and appropriate weighting agents.

The well was drilled without lost circulation incidents and stayed within torque‑drag limits, completing ahead of schedule.

A sudden drop in oil rate was observed in a joint‑venture field affecting multiple partners.

Lead a cross‑functional team (reservoir, drilling, facilities) to diagnose and remediate the issue within two weeks.

Organized daily briefings, assigned root‑cause analysis tasks, coordinated data sharing, and implemented a temporary choke‑adjustment while designing a long‑term solution.

Identified a scaling issue in the surface pipeline, cleaned it, and increased production by 12% within the target timeframe, earning commendation from senior management.

During a workover, a pressure gauge malfunctioned, giving an inaccurate low‑pressure reading.

Ensure crew safety, verify actual pressure, and prevent a blowout.

Immediately halted operations, initiated a manual pressure check, evacuated non‑essential personnel, and consulted the HSE team to perform a well‑control drill before resuming.

The true pressure was 1.8 times higher than indicated; corrective actions prevented a potential incident, and the incident report led to revised gauge maintenance procedures.

Tasked with planning a new onshore drilling pad in a region with strict water‑use regulations.

Develop a compliance strategy that meets local, state, and federal environmental standards.

Conducted baseline environmental impact assessments, engaged with regulators early, designed closed‑loop mud‑system to minimize discharge, and prepared a spill‑prevention plan.

Project received all permits on schedule, with zero environmental incidents during the first year of operation.

Leading the design phase of a new offshore processing platform.

Facilitate a Hazard and Operability (HAZOP) study to identify potential process deviations.

Assembled a multidisciplinary HAZOP team, defined nodes, used guide words to explore deviations, documented findings, assigned risk rankings, and developed mitigation actions with clear responsibilities and timelines.

Identified 18 high‑risk scenarios; mitigation measures reduced projected incident frequency by 40%, and the study was approved by the client’s safety audit.