FIELD |
PROJECT DESCRIPTION |
| Maydan Mahzam |
Gas lift design was investigated and gas requirements estimated to determine when gas compression would be required for the field. An Integrated Production Model was constructed which examined the impact of the gathering system on the total production system performance. A surveillance program was recommended and training established to achieve production efficiencies predicted. |
| Prudhoe Bay |
An Integrated Production Model was available but individual well flow streams were not measured. To optimise production and reservoir management, a production allocation tool was developed using Open Server to allocate production volumes to wells. |
| East Area Gas Project Ubit, Utue, Mfem, Isobo - Nigeria |
Gas utilisation optimisation project. An Integrated Production Model provided directions for development and utilization of produced gas in the East Area of Offshore Nigerian oil and gas fields. |
| EIU - Etim, Inang, Utue, (Edop, Asasa) - Nigeria |
Evaluate areal production impact of safety/environmental modifications to these fields. Additional capital development opportunities for upside production and reserve recovery were investigated. Data validation tools were constructed to reduce uncertainty in the project. |
| Harmattan, Alberta |
Review of wells acquired in a property swap. This highly depleted reservoir was experiencing rapid decline in well productivity and flow stability. The main factors influencing performance were liquid hold-up and excessive friction in the tubing. Recommendations included compression reconfiguration, tubing replacements and evaluation of horizontal wells for stimulation and clean out. |
| Lugos, France |
A complete reservoir/production review of this field was required to develop an optimisation strategy after the acquisition of the field from a major multinational. The analysis concluded that numerous opportunities existed to increase oil productivity including reperforation, recompletion, water shut-offs, high volume lift. As a result, the need for further drilling was diminished. A few attractive infill locations were identified. |
| Brooks, Alberta |
The Operator’s existing optimisation program was reviewed and enhancements were proposed. A statistical review was made on the long term success of well intervention operations and criteria for increasing the success ratios and decreasing the economic risk were defined. Recommendations included: downhole pump production - reliability balancing; screening criteria for high volume lift installation; surveillance programs to monitor performance changes; criteria for water shut-off candidate selection including a production logging program. |
| Green Canyon, Gulf of Mexico |
This optimisation project using integrated production modelling derived from the complexity of this: 14 reservoir, 24 well development. Successful modelling of the reservoir to separators identified significant (15%) increases in productivity from surface system balancing and potential increases from gas lift addition. Other recommendations addressed well failures, sand production recompletion strategy. |
| North Weyburn Midale Pool |
This field optimisation evaluation concluded that a waterflood should be implemented to increase ultimate recovery from 8 to 22% of OOIP. Recommendation for well conversion, artificial lift installation, water injection facilities and fluid handling were included. |
| Tatagwa, Midale Pool |
A detailed review of the reservoir and production performance of this mature field using analytical methods and statistical tools, such as OFM. Recommended drilling four horizontal producers, seven injectors and the installation of injection facilities for an incremental recovery of around 7% |
| Ferrier Brewster and Ferrier Banff |
A Pools Integrated Production Models defined the optimum development strategy to maximize operators competitive gas off-take and recovery, and to define budget items required to do so. |
| Countess-Makepeace |
Developed an integrated production model using FORGAS including 66 wells (35 dual completions); 100 separate low pressure, low permeability gas pools (Glauconite, Viking, etc.); and five separate pipeline legs, including a field booster compressor facility. Identified opportunities for capturing additional reserves in a competitive drainage location. Identified a major bottleneck at one of the dehydrators. Examined debottlenecking via pipeline looping, installation of additional field compression, upgrading plant compression, and adding wellsite compression. Assessed impact of aggressive developing drilling program on the optimised gas gathering system and provided production forecasts for various development options |
| Waterton |
Review of completion history and well performance of a deep, highly depleted, gas condensate field in fractured carbonates. Analysed pressure surveys and liquid loading issues. Recommended a reduction in wellhead pressures with additional compression, surface system modifications and debottlenecking. Also recommended larger tubing; annular or casing flow for some of the better wells to increase offtake and ultimate recovery. Subsequent study looked at High Volume Artificial Lift options for recovery of condensate and/or to increase gas production from wells with blocked inflow or excessive liquid loading. |
| SE Saskatchewan |
Evaluated strategies for optimising oil production operations with particular emphasis on high volume water handling strategies. The main factor affecting profitability was the ability to handle large amounts of water production. Both high pressure (i.e. surface pumps) and low pressure systems were evaluated in the analysis. Recommendations included a shift to high pressure systems, improved water cut determinations to better identify individual producing well characteristics, improved separation efficiency, and the need to evaluate water mitigation technologies. The need for a reservoir depletion strategy was also determined to be a necessary component to the overall economics of these high water cut pools. |
