Oil and Gas
| Well Type and Event Improvements | |||
|---|---|---|---|
| Application | Well Type or Event | Improvement | Value Added to Operator |
| Optimizing producing BHP | Producer | • Lower Fluid Level • Increased Production Rates |
• Reduced energy costs per barrel lifted • Increased daily revenue due to higher production rates |
| Evaluation of Artificial Lift Performance | Producer | • Extended Run-Life • Decreased Lifting Costs |
• Decreased lifetime costs for assets due to reduced well interventions • Decreased lifting costs |
| Optimized Reservoir Drawdown | Producer | • Increased Production Rates Without Effect on Ultimate Recovery | • Increased short-term revenue without decreasing long term value |
| Leak Detection | Producer or Injector | • Optimized Well Intervention Success • Verified Regulatory Compliance |
• Decreased workover costs due earlier found events and known causes • Reduced environmental damage and legal costs |
| Monitoring Stimulation Placement | Producer or Injector | • Improved Workover Results • Reduced Risk of Pumping Out of Zone • Reducing Volumes Used |
• Improved workover payout • Reduced risk of wasted expensive fluids • Decreasing cost of treatments |
| Monitoring Fluid Entry or exit points | Producer or Injector | • Knowledge of Zonal Contribution • Cross-Flow Knowledge • Decreased Water or Gas Production |
• Improved workover success rates decreasing cost of assets • Reduced lifting costs due removal of unwanted fluids • Increase revenue do to removal of flow restrictions |
| Near Wellbore Skin Damage, Gravel Pack Evaluation | Producer or Injector | • Increased Production Rates • Improved Intervention Results. |
• Increased daily revenue due to higher production rates • Improved workover success rates decreasing cost of assets |
| Flow Assurance | Producer or Injector | • Limit effects of scaling or hydrate formation that would reduce production /injection rates and recovery | • Decreased lifting costs and lifetime costs of assets due to better understanding of conditions |
| Reservoir Recovery Process Improvements | |||
|---|---|---|---|
| Application | Reservoir Recovery Process | Improvement | Value Added to Operator |
| Manage Reservoir Pressure | Primary Recovery | • Understand Reservoir Depletion • Understand Reservoir Extents • Better Understand Primary Recovery Mechanisms • Optimize Reservoir Withdrawal Rates • Limit Unwanted Fluid Production • Understand the Need for Smart Wells • Optimize Well Placements |
• Improve asset revenue through improved ultimate recovery by understanding primary recovery drive mechanisms and eliminating unnecessary reservoir voidage • Maximize short term revenue by optimizing production rates without effecting ultimate recovery • Reduce requirements for additional capital investments required for additional wells and replacing with Smart wells |
| Manage Areal and Vertical Sweep Efficiency | Secondary or Enhanced Recovery Projects | • Optimize Injection Rates • Improve Injection Profiles • Control Reservoir Pressure • Reduce By-Passed Oil • Improved Sweep Efficiency • Improved Success Rate for Workover Programs |
• Reduced asset ongoing capital investment costs through more successful workover programs, improved injection strategies, and optimum control of reservoir pressures • Optimize ultimate recovery resulting in maximum Asset Revenue through improved sweep efficiency and elimination of by-passed oil |
| Manage Comingled Reservoirs | Primary Recovery | • Change Commingled Zone Strategies • Understand the Need for Smart Wells • Revise Artificial Lift Plans • Understand Cross-Flow Effects |
• Increase value of asset by use of Smart Wells to decrease capital investments and improve short term production rates • Reduce capital investments in artificial lift systems thereby increasing lifetime value of assets • Increase lifetime value of assets by improved workover success |
| Optimize Secondary or Enhanced Recovery Projects | Secondary or Enhanced Recovery Projects | • Optimized Pattern Recovery Strategies • Reduce Equipment and Wells Required • Reduce the Need for Workovers • Improve Reservoir Depletion Strategies |
• Reduced asset lifetime Capital Investment through better understanding of pattern flood designs and need to revise well positions, plus reduced workover program requirements • Increased asset lifetime Revenue through improved flood performance |