As a Senior Drilling Engineer on the Tuscaloosa Wells Team he was accountable for the planning, execution and delivery of HTHP gas wells in the Judge Digby and Port Hudson fields within the Tuscaloosa Trend which is located Northwest of Baton Rouge. The Team delivered best-in-class performance on several wells, successfully drilled depleted reservoirs with drilling differentials in excess of 13,000-psi, delivered BP’s first successful reverse cemented production liner which resulted in improved gas recovery and he also implemented a successful wellbore breathing (ballooning) mitigation plan. Total depth for wells in these fields range from 18,000-ft to 23,000-ft with bottom hole temperatures in excess of 425°F and bottom hole pressures in excess of 18,000-psi.

While assigned to the Arkoma Wells Team as a Senior Drilling Engineer he was accountable for the development and execution of the Bromide Exploration Program which was driven by field revitalization efforts within a mature asset. The revitalization program was initiated as a result of 3-D seismic interpretation and resulted in the need for “cost conscious” designer wells in what has long been known as “crooked-hole country”. The surface section of these wells is air/mist drilled to approximately 5,000-ft and directional operations are then conducted in an oil-base mud system within formations ranging in unconfined strengths from 20-ksi to 55-ksi. The wells reached total depth of 13,000-ft to 16,000-ft with step-outs of 1,200-ft to 3,500-ft.

While a Senior Drilling Engineer on the Mad Dog Wells Delivery Team he was accountable for the design, execution and delivery of sustainable high-rate oil wells in the Gulf of Mexico’s Southern Green Canyon. The Mad Dog Field is situated in water depths of 4,400-ft to 5,900-ft along the flank of the Sigsby Escarpment. Key drilling risks include shallow hazards, salt exit, mobile tar, wellbore instability, highly fractured shales along the graben structure, over-pressured formations, depleted intervals and attaining step-outs in excess of 10,000-ft. Operational risks include annular pressure build-up, vortex induced vibration, riser clashing, simultaneous operations and logistics issues. <see http://en.wikipedia.org/wiki/Mad_Dog_(oil_platform)>