Following the successful merger of William M Cobb & Associates and Haas Engineering I now work for Haas & Cobb Petroleum Consultants where I provide services on:- Reservoir modelling- Field Evaluations- CCUS Modelling- Gas Storage- Modelling of mineral extraction from brine (Bromine, Lithium, Uranium)- Waterflood design and optimisation- Reserve assessment and limited reserve audits- Horizontal well development, use and control of injection profile in horizontal injectors

Providing services on:- CCUS Modelling- Modelling of mineral extraction from brine (Bromine, Lithium, Uranium)- Horizontal well development, use and control of injection profile in horizontal injectors- Waterflood design and optimisation- Reserve assessment and limited reserve audits- Reservoir modelling- Field Evaluations

• Carry out economic analysis of our project and other operator properties for potential A&D.• Carry out reservoir simulation studies on the pilot project and full field development.• Reserve analysis and reporting.• Incorporate new data and design an optimised phased development of the field.- Investigate development strategies and innovative well designs to maximise development value.- Look at automation and remote monitoring to improve long term value.• Worked with the other senior executives and Venture Capital fund to put together the company and project.

• Working with the CEO & CFO to arrange finance for field purchases and development opportunities. • Identify and evaluate oil properties which are not on the market but that are well suited to Glori’s AERO technology. Prepare production & reserve analysis and value properties. Present findings to Corporate Executive committee and to the board.• Carry out reservoir and economic evaluation/valuation of oil properties Glori is interested in on the public market and prepare bid documentation for the Board of Directors. • Responsible for global AERO project reservoir screening and project performance analysis. • Worked with Operating Companies management prior to implementing AERO to ensure field, well and production data was in a state that production benefits could be accurately measured and quantified.• Brown/greenfield development & waterflood planning using classical reservoir engineering techniques & reservoir simulation to optimize the design and apply AERO to add production and reserves in existing US fields operated or developed by Glori Holdings.• Recommend innovative new technologies to improve production or efficiency of operated properties. • Played key role in off market acquisition of $45 million of assets. • Identified old neglected field with up to 100 MMbo of bypassed resource that could be acquired for less than $5 mill and have an estimated value of more than $1bn.

• Providing consulting services on:- Field optimisation. - EOR Project benefit analysis.- Reserve estimation and economic analysis.Goal of providing innovative EOR technologies to improve production of flooded fields by more than 20% above base decline within 12 months and subsequently increasing reserves valuation.

• Global responsibility for Powerwave Project screening, planning implementation and analysis. • Worked with Operating Companies management prior to implementing Powerwave optimization to ensure field, well and production data and was in such a state that production benefits could be accurately measured and quantified.• Developed analysis methods to accurately determine the production impact of Powerwave optimization.• Developed Stimulation methodology and procedures to maximize the benefit of our pulsed injection process for well stimulation applications. Devised program module that allowed the Wavefront operators real time control during Powerwave stimulation optimization.• Responsible for all Powerwave marketing material. Developed detailed case histories – typical incremental oil production gains from Powerwave injection optimization was between 30 and 100% within 12 month of Powerwave deployment.• Developed strategic sales approach resulting in tool deployment growing from 3 systems when I joined to over 250 contracted systems in Jun-2011.

• Ranked among BP’s top 1% of Reservoir Engineers in Canada in the March 2008 Staff Grading.• Completely overhauled and managed the NEBC Area Team Reserve bookings and was commended by the President of BP Canada.• Acted as consultant to the Arctic team on Reservoir Engineering and Reserve issues for their internally high profile exploration efforts.• Developed a method for screening development strategies and determining economic value and required export capacities for BP acerage.

• Manage the base reservoir team based in Dorset and responsible for all base production issues.• Technical Authority for production forecasting, the Group Financial Outlook reporting and the Long Term Plan production figures. Developed improved production forecasting system that was typically accurate to within ±0.3%.• Developed a new way of calculating the production split between the different production leases on the field and got this accepted by the revenue office, saving an approximate $1.5 million per year in tax.• Devised and supervised the development of a new well test analysis, production allocation and loss management system in order to improve the tracking and minimisation of well and plant losses.• Introduced two of the eight BP common processes to Wytch Farm - the Base Management common process (BMcp) and the Production Efficiency Improvement common process (PEIcp).• Led the Wytch Farm optimisation project that delivered an annualised average production increase of 1,600 bopd, 1.5 MMbbl reserves and generating over 35 million dollars of incremental revenue in 2005 alone with a budget of $1.5 million.• Managed a pilot project for improved waterflood management that quantified the value of water injected in different injectors and hence we were able to improve the waterflood performance and justify drilling of new injectors.• Developed the annual Field Development Report including assessment of reserves.

• On a 1-year secondment from BP Alaska to further develop Pulsed Injection technology. Developed Guidelines for future tool development required to grow the company and gain access to higher cost operating environments.• Directly supervised research group, design engineers and field staff, in total around 15 people• Responsible for all data analysis pertaining to Pressure Pulse Technology and co-wrote two technical papers on the use of PPT technology for enhanced oil recovery in heavy oil• Develop monitoring and stimulation products and market new EOR technology to the Major Canadian and International Oil Companies• Develop effective business processes for a rapidly growing high technology company

• Led the multidisciplinary Niakuk team in a reservoir study to identify reservoir mechanisms and identify future potential for reserves and production growth.One of the major findings of the study was identifying performance discrepancies within the field caused by poor cementing practices, leading to a loss of over 4 mmstb recovery in one well alone.

• Won 2001 Helios Award Commendation in the Performance Category for “Updip Zone 4 Miscible Gas Injection Project”• Led multidisciplinary team to sanction of the Eileen West End Miscible Gas Project – the first MI project to be sanctioned by bp in Alaska since 1995.• Led multidisciplinary team in identifying the need for and developing a major change in the EWE reservoir management strategy. The team achieved partner alignment and approval to implement the strategy. As a result, field deliverability increased by over 5,000 bopd (25% of field production) over a 6-12 month period with no incremental spend.

• Won BP Chairman’s Award for “Innovative and Green Method of Cuttings Disposal is Giving Production Benefits at Wytch Farm” which benefitted the environment, increased production and saved more than $15,000/day during drilling.• Won BPA Technology Award for the use of Fibre-Optic for production logging of an oil well.• Won BPA Technology Award for the intelligent flow control for a multilateral well.• Won BPA Technology Award for the world’s first Extended Reach Multilateral well with a novel, low cost and effective flow control completion (1M-15SP).• Proposed innovative design for the 1M-17SP well, generating a cost saving to the Asset of $4 million.• Led multidisciplinary team in a key reservoir study developing an infill drilling programme delivering 6 Mbopd in 2000 and 8 MMstb reserves at <$2.30/bbl.• Received very positive comments from my team on my leadership, technical and interpersonal skills from upwards feedback exercise.

• Responsible for Reservoir input to the world leading ERD project at Wytch Farm. o Came up with idea for open hole side-track at 8.7 km step-out which increased NPV10 by £13 million. o Proposed and developed extension to ERD programme combining producer and injector drilling with well site separation facilities yielding reserves increase of 20 mmstb.• Devised and developed option for commingling of sea water and prod. water increasing field voidage by 15% with an associated production benefit of 2,500 bopd.• Lead Asset Representative for BPX Non Conventional Well (NCW) Performance Prediction Technology Project, responsible for developing scope, budget and value of project items with Project Manager.

• Developed sector models for satellite discoveries and successfully coupled them to the full field model to form new improved basis for key field decline nomination. Achieved partner buy-in to new approach.• Devised and led work programme to understand well performance and review remedial actions.• Managed Reservoir Engineering interface with the seven partners.

• Devised and developed improved method for evaluating field interactions within the transportation system using ECLIPSE Reservoir Coupling, completely changing the planned tie-in point after showing that 100 MMscf/d only resulted in 5 MMscf/d incremental sales. Changing the tie-in point reduced the loss from 95% to an average of less than 8%. A beneficial side-effect was to achieve greatly improved forecasting.• Led the Reservoir Engineering work with building a new reservoir model for West Sole following 3D seismic which identified several previously unidentified infill drilling opportunities. The results from this work resulted in reserves additions of 79 Bscf and a 20% increase in field deliverability.• Developed comprehensive reservoir surveillance programme for the West Sole field aimed at capturing key reservoir data to improve model predictions.• Responsible for reserve assessment and booking.

• Responsible for completion design, planning and offshore supervision of well service and completion operations on the Gyda Oil field.• Carried out completion design for BP Norway's first Extended Reach Drilling well

• Planning, logistics and offshore supervision of open/cased hole logging and well testing. Offshore quick-look log interpretations. Final onshore analysis and reporting.• Design, planning and analysis of reservoir surveillance work (TDT/PDK-100, PLT, Spinner & PBU surveys).• Initiated various cost efficiency measures - Set up an incentive contract with our logging contractor. - evaluated/negotiated new logging contract, which resulted in 400,000 USD/year savings.• Proposed and gained management approval for innovative pressure data gathering. Large cost savings realised through purchase of Echometer equipment and development of interpretation techniques to improve the accuracy of calculated reservoir pressure to ±40 psi.• Researched, planned and supervised a successful asphaltene chemical clean-out on Gyda.

• Performed production reporting & operational duties on Ula platform. Designed & implemented offshore trials of corrosion inhibitors. Suggested modifications to chemical injection system which improved reliability and reduced consumption.• Headed an offshore task group on thermal insulation and trace heating of pipework which led to reduced inspection and maintenance costs.

Researched and formulated plans to increase production from the Valhall field based on their problem with chalk failure. Devised detailed operations procedures for each well on the field to maximize the safe draw-down rate for each well. Production was subsequently increased by approximately 10 000 stb/d (around 8% of total field production).