Recently retired from ConocoPhillips after 44 years having worked in the following E&P areas:• Chemical/process engineering and research• Reservoir engineering• Enhanced oil recovery• Drilling• Operations planning (Pre-Ops)• JV/Non Ops Asset Management• Engineering & Construction Management• Project Management and Sponsorship – onshore and offshore conventional O&G, plus 40 MMTA of LNG

Seconded to ExxonMobil as Project Manager for the LNG Plant portion of the Alaska LNG Project sponsored by ExxonMobil, COP, BP and AGDC. The proposed LNG Plant is to be located on the Kenai Peninsula in Alaska and consists of three 6.7 MTA trains using the APCI C3MR process. LNG is produced to two 240,000 m3 all concrete precast LNG tanks with an associated Marine Terminal containing 2 loading berths. The scope of worked included all Pre-FEED engineering activities including developing the technical data to support filing the FERC application. The Pre-FEED JV was dissolved in December 2016 due to weak market demand for LNG.

Represented the Project function at the corporate level and recommended functional sign-off for all capital projects progressing through the AFS, AFF and AFE gates, provided troubleshooting and consultancy of ongoing projects in Execution, and assisted in managing the global projects community resources via mob/demob and career progression. Also provided specific stewardship and accountability for corporate oversight of the projects within the Americas region (Alaska, Canada and L48).

Provide project management functional oversite and guidance for the Qatargas 3 (COP & QP) and Qatargas 4 (Shell & QP) integrated projects each of which are designed to produce 1.5 BCFD of raw gas that is transformed into 75,000 BPD of Condensate and LPG, 1,200 TPD of elemental sulfur, and 7.78 mtpa of LNG. The integrated project includes 3 offshore platforms in 50m of water with 11 development wells, two (2) 70km long 38-inch diameter sour wet-gas pipelines, a 5,000 m3 slug catcher, condensate separation, stabilization, and deodorization facilities, CO2 removal and sulfur recovery facilities, LPG recovery and fractionation facilities, and two (2) parallel 7.78 mtpa LNG mega-trains based on the APCI X-Hybrid process technology. Also built and managed project teams to execute various miscellaneous smaller projects like: the Jetty Boil-Off Gas recovery Project and LNG Berth #6.

Acted as Project Sponsor for the Bayu-Undan Gas Recycle Project, Bayu-Darwin Gas Pipeline Project, and Darwin LNG Project. The 1 BSCFD Gas Recycle Project was in the JPDA in the Timor Sea in 80m of water. The facilities consisted of a 1500 mt Wellhead Platform connected by a 7 km infield pipeline to a Central Processing Complex comprised of 2 8-pile SJPs with 26,000 mt of topsides producing stabilized condensate and LPGS that were separated and refrigerated on a multi-purpose FpSO. The Gas Export Project consists of a 503 km 26-inch subsea pipeline to Darwin and a 3.70 mtpa LNG plant on Wickham Point 4 km south of Darwin based on ConocoPhillips proprietary Optimized Cascade LNG Process.

Responsible for leading a group of 18 senior Conoco upstream engineering professionals who provide Project Development support for BD/CD and Technical Service support for Conoco’s BU’s. Global talent managment responsibility for corporate upstream Process Engineering, Pipeline Engineering, Facilities Engineering, and Development Engineering skills and expertise.

Responsible for all aspects of engineering/design, procurement, and construction for the Upstream portion of Venezuela Extra Heavy Oil Project (VEHOP) which was a JV (Petrozuata) between Conoco and Maraven (PDVSA). The upstream project consisted of a 200 km pipeline system and field facilities to produce 120,000 BPCD of 9.3o API bitumen. 47o API naphtha was used as diluent and sent to south from Jose to the field in a 20" pipeline and a 15-17o API blend of bitumen and naphtha will be sent north to Jose in a 36" pipeline. The field was the first to make extensive use of multi-phase meters and multi-phase pump technology.

Oversaw the preparation of the proforma EPC contracts for the Bitor MPE-2 project that eventually got shelved when Florida Power & Light could not get EPA approval to import Orimulsion.

Overall project management for a remote 27,500 BOPD arctic quality facility on the Russia tundra which included a million cubic meters of civil work, on-site potable water and sewage treatment, gas turbine power generation for VSD ESP operations, temporary and permanent living quarters, satellite communication systems, a 42-mile 12" ID above ground pipeline, and a remote pipeline terminal. Entire project was conducted in 30 months and over two winter construction periods. Manpower peaked at roughly 1000 during the winter construction periods. Field modules were engineered, procured and fabricated in Houston/Corpus, trial fitted, bagged and tagged, shipped to Russia and then reassembled by Russian labor.

Responsible for managing and oversight for Petroleum Technology (Geoscience, Reservoir, & Production), Drilling, Well Systems, & Operations Pre-Planning for the Heidrun Field development in Norway. The technical scope covered $1 billion of investment. Heidrun was the first field developed used a concrete TLP, and is located in 1050 feet of water right near the arctic circle. Provided partner and gov't interface on technical matters and co-chaired the Heidrun JV Technical Committee.

Managed all reservoir and production engineering performed by Conoco Norway Inc, including manpower planning, hiring and training of local staff. Managed all reservoir, production, and well systems work for the Heidrun field development. Chaired the Heidrun JV Technical Committee.

Managed Conoco Norway's equity interest in all fields operated by other parties. Scope included roughly 80,000 BOPD of net oil production and 30 MMSCFD of gas, $500 MM/yr of revenue, $100-200 MM/yr of CAPEX. Group was responsible for all JV administration (i.e., partner/gov't/operator interaction), reserve confirmation, concept selection/approval for new developments, all commercial negotiations, and validating all budgets and financial forecasts.

Responsible to the regional SVP for long term planning, technology transfer, capital budget administration, major project approval and metrics (economics), manpower allocation, screening new ventures/acquisitions/dispositions.

Led Conoco group which established a reservoir data base for all of Conoco's domestic reservoirs and screened them against technical and economic screening models which the team built/programmed. Worked with the Business Units to pursue viable EOR projects. Provided high level oversight for additional steamflood pilot operations in South Texas and commercial application/sales of Conoco's FAST process. Also provided technical support for other EOR processes (i.e., surfactant (low/high tension and caustic), miscible and immiscible (CO2, N2, HC), and polymer flooding). Worked on the 1984 EOR Study performed by the National Petroleum Council. Co-authored the Thermal Recovery portion.

Supervised all engineering aspects of Conoco's South Texas Tar Sands Project which involved the application of Conoco's patented FAST steamflood process in -2oAPI gravity, 11 wt % sulfur tar. Responsible for reservoir engineering, well design and operations, steam generation and distribution, all facilities design, procurement, installation and start-up, engineering support for day-to-day operations, performance analysis. Led group which evaluated coal/coke fired steam generators and performed the cost-benefit analysis which led Conoco to build the first fluidized bed combustion (FBC) unit ever used for oil-field steam generation. 3 SPE publications + 1 AAPG.

Areas of work included: coal gasification, coal gas purification and methanation - both laboratory and field proto-type plants. Process engineering support for conceptual screening studies relating to efficient use of remote natural gas. Processes studied included conversion to fuel and chemical grade methanal, urea, ammonia, hydrogen, electricity, LNG, and light syncrude via the Fischer-Trophes process (GTL = Gas–to-Liquids) both onshore and offshore on floating platforms/vessels. Research and engineering support for Conoco's Thermal Recovery operations in California, Texas. Oklahoma, and Louisiana. Knowledge base includes: Design, prediction, and optimization theory for steamflood, steam soak, and fireflood methods; in-situ coking and sand consolidation techniques; all aspects of steam generation including steam generator design, operation, stack gas clean-up, water treating, quality measurement, and steam splitting; flowline/insulation design; thermal well design, including prestressing casing, use of insulated tubulars, expansion joints, and thermal packers; observation well design and various other measurement techniques (tilt meters, CO and TDT logs, salinity monitoring, radioactive tracer usage, etc); quench systems for sensing and protecting fireflood producers; open and closed loop dilute systems; oil-in-water emulsions for minimizing viscosity; general viscosity reduction and measurement; subsidence/compaction phenomena; steam injection profile control and gravity over-ride inhibition; beam pump and PCP artificial lift; heavy oil refining (impact of sulfur, heavy metals, asphaltenes). Assisted in editing SPE Monograph 7.