Blade Energy Partners, Ltd. | 08. Selected Projects Details
Blade Energy Partners
Home > Geosciences & Reservoir Engineering > Selected Projects Details
Selected Projects Details

Blade has relentlessly pursued a mission of expanding the frontiers of technology in all phases of exploration and production. That mission remains the steadfast goal of tomorrow.

Please click on an Asset below to view our extensive range of selected projects worldwide.
Region
Asset
Study
North AmericaTight ReservoirPetrophysical Analysis
North AmericaClastic & Carbonate Gas PlaysGeophysical Imaging Project
North AmericaHeavy Oil FieldProduct Optimization
North AmericaHeavy Oil FieldThermal Simulation to Improve Recovery
South AmericaOil Field StudiesIntegrated Field Development
North SeaOffshore Platform FlareDebottlenecking Emergency Relief System
North AfricaOil Fields under a complex Production Sharing ContractField Development and Value Management
North AfricaOffshore Platform ComplexFacilities Debottlenecking and Optimization
West AfricaOffshore Oil WellsRobust Guidelines for Sand-Free Production
West AfricaOil FieldField Development Plan and Implementation
West SiberiaOil Fields PortfolioReservoir Valuation of Underbalanced Drilling (UBD)
Far EastEarly Stage Gas Complex OptimizationIntegrated Field Development & Asset Value Maximization
Far EastLNG StrategyExtending Life of Major LNG Plant


South America: Oil Field Studies
Integrated Field Development
Blade’s integrated geosciences and engineering field redevelopment study resulted in the identification of a satellite structure and a plan to drill 40 additional wells for a mature field in Argentina. The study area contained 400 wells with 40 years of production history from multiple reservoirs.

The project team consisted of geoscientists, production, reservoir and facilities engineers, and business analysts. The team produced a final optimized field development and surveillance plan after evaluating numerous development scenarios including gas injection, infill drilling, horizontal wells, plug back, pump optimization, additional water injection, EOR, and pipeline and compressor efficiency improvements.
Return to Top

North America: Heavy Oil Field
Thermal simulation to Improve Recovery
Blade constructed a reservoir simulation model for large, heavy oil field using Computer Modeling Group’s thermal simulator STARS. The model included over 300 wells and was history matched for 45 years. Prediction runs were made to determine the strategy to maximize recovery. Strategies evaluated included placement of new horizontal wells, placement and utilization of new vertical wells, cyclic vs. continuous steam injection, steam injection parameters and volume, and bypassed oil exploitation. Results yielded the ultimate recovery factors used for reserve certifications.
Return to Top

Far East: LNG Strategy
Extending Life of Major LNG Plant
Blade optimized the deliverability from a complex of producing gas fields by identifying economic mix of workover program, infill drilling, and future facility expansion projects. The study determined the optimum order in which new gas fields should be developed to continue to meet LNG contractual obligations. The recommended development plan extended the life of the LNG plant over 2 years. Blade’s optimization technology determined the best sources for meeting future LNG demand and saved 40% of future capital investment.
Return to Top

North Africa: Oil Fields under a complex Production Sharing Contract
Field Development and Value Management
Blade designed a robust production strategy, capital investment schedule, and operating plan for major onshore sandstone fields with over 100 wells in North Africa. The study determined a prioritized sequence of future development projects and marketing opportunities to maximize long-term profitability. The proposed strategy improved client’s share of Net Present Value (NPV) by 15% and increased production entitlement by 8 million barrels.
Return to Top

Far East: Early Stage Gas Complex Optimization
Integrated Field Development and Asset Value Maximization
Blade improved the NPV by more than US$300 million for a highly heterogeneous 12-field offshore gas complex with over 70 reservoirs of varying fluid properties. The integrated geosciences, engineering, and business team optimized the sequence of fields, scheduling of platforms, number of wells and drilling program, and timing of booster compression to maximize value of the asset over the 20-year contract life. Uncertainties in reserve base and capital cost were considered to ensure commercial robustness of the development plan under the production sharing contract.
Return to Top

North America: Heavy Oil Field
Production Optimization
Blade optimized steam generation, steam allocation, and cyclic stimulation schedule for a large, thermal recovery heavy oil field in California to increase overall production by more than 10% over prior estimates, despite cogeneration unit downtime. The study determined the steaming schedule and cycle length for 1,200 wells during outage of major steam cogeneration unit. A real-time production optimization framework was custom built for the asset.
Return to Top

North Sea: Offshore Platform Flare
Debottlenecking Emergency Relief System
A large offshore oil platform had problems with the emergency relief system. Part of the gas produced from the platform was reinjected into the reservoir and part was compressed into the sales pipeline for domestic sales onshore. When either the sales gas compressors or the reinjection compressors tripped, the flare became a problem. The radiation was too hot causing production rate reduction and liquid carryover was a possibility. The radiation levels were measured, the process was modeled. A dynamic simulation of the flare system was built. A multi-solution approach was implemented to solve the problem, including modifying the flare knockout drum piping, replacing the flare tip, and installing shielding.
Return to Top

North Africa: Offshore Platform Complex
Facilities Debottlenecking and Optimization
Offshore platform complex, with primary and secondary separation, crude stabilizer, and gas reinjection, had tower flooding problems and poor stream time. Our facilities experts ran performance tests, built process simulation models, implemented tower radiation scanning, identified problems, set up new operating procedures, and trained all rotating shift personnel in proper operations.

In another field, three processing platforms were scheduled for replacement. Analysis of the entire field, future reservoir requirements, and excess capacity available in existing pipelines and platforms, including pipeline modeling and platform facility debottlenecking, resulted in recommendation to shut down these three platforms and divert production to other existing platforms. Minor debottlenecking, platform expansion, and additional pipelines resulted in a safer, more streamlined and robust operation, with significant cost savings.
Return to Top

West Siberia: Oil Fields Portfolio
Reservoir Valuation of Underbalanced Drilling (UBD)
A comprehensive pre-screening study was undertaken by Blade on a large portfolio of mature fields with multiple formations to identify top candidates for UBD. The selection process was based on reservoir and drilling value and overall implementation risks. This is one of the largest UBD pre-screening efforts in the world.

Detailed reservoir valuation studies were also undertaken on selected fields to quantify the expected improvement in productivity and recovery from UBD through combination special core laboratory tests, stochastic modeling, statistical updating, and reservoir simulations.

The study results estimated over 50% improvements in well productivity through UBD.

Return to Top

West Africa: Offshore Oil Wells
Robust Guidelines for Sand-Free Production
Blade developed and applied its fundamental PREDICT tool to determine stable, maximum sand-free rates for offshore oil wells. The Client prior to the PREDICT tool, relied on rules of thumb and field experience for drawdown pressure guidelines.

PREDICT models the interaction between pressure drawdown and rock cohesion, taking into account the water cut. It considers the flux in the completions and utilizes a failure criterion based on the nonlinear Mohr-Coulomb constitutive theory and Biot’s stress solutions.

This allowed the operator to increase field production and eliminate constraints imposed by prior arbitrary drawdown guidelines.
Return to Top

North America: Clastic and Carbonate Gas Plays
Geophysical Imaging Project
3D seismic acquisition designs based upon proprietary Monte Carlo simulation analysis of existing seismic data. Evaluated and advised on award of seismic acquisition contract, managed overall acquisition process and provided continuous on site Quality Assurance.

Evaluated and advised on award of 3D seismic Pre-Stack Time Migration (PreSTM) and inversion processing contracts, managed and provided Quality Assurance of all facets of seismic processing through inversion for rock properties. Jointly with client interpreters evaluated Pre-STM and inversion volumes for delineation of gas producing sands and unconventional shale gas plays.

This collaborative geophysical project resulted in improved well results as measured by drilling success rates and well production volumes, in addition to minimizing drilling hazards.
Return to Top

North America: Tight Reservoir
Petrophysical Analysis
A rigorous petrophysical assessment was performed on the Narraway, Ojay and Chinook-Ridge field wells located in Alberta and British Columbia, Canada. The reservoir is tight sand with bands of coal and some shale stringers throughout the zone of interest. The analysis used data from wireline conventional logs, conventional and sidewall core data, lithology/mud log descriptions and perforation intervals. Initial well-test results as well as 100-day test results were provided at the end of the study to determine if the predictive models accurately identified well performance ranking.

Proprietary matrix-inversion petrophysical modeling and other predictive petrophysical techniques were used to predict lithology, porosity, porosity type and saturation to determine if this approach can be used to estimate well performance and predict zones that may contribute to flow into the wellbore.

A summary by zone was calculated from the predictive results and a porosity thickness by zone was compared to the 100-day cums provided by the client. The graph shows how the predictive petrophysical results compare with actual production history. The client continues to use the predictive models to determine what wells and zones to complete or to abandon with a high degree of confidence.
Return to Top

West Africa: Oil Field
Field Development Plan and Implementation
We carried out a fully integrated reservoir characterization and engineering study covering all aspects of a full field development plan including well completion design, pipelines and surface facilities. The reservoir characterization effort included: Petrophysical analysis for several wells, re-interpretation of 3-D seismic survey and integrating it with log analysis. A Petrel geological model was then created using all available data including core data. The original oil in place was estimated using this fine detailed model.

A comprehensive production engineering study was performed to identify and confirm the reasons for low productivity of existing wells. The study indicated that most of the well productivity problems were due to poor cement jobs and formation damage during drilling.



The geological model was also, up-scaled for reservoir simulation to model reservoir performance simulator to arrive at a high quality reserve estimate and a production profile. Three cases were run: a base case, an upside case, and a downside case, to bracket the likely outcomes. Based on this work, a field development plan was developed including the production outlook, well completion strategy, facilities and operating cost, and planned evacuation alternatives. This phase included cost estimation and drilling and facilities tie in.
The next step was to package this cost effective and economically viable field development plan with supporting data and engage a third party reserve evaluation company to estimate proved, probable and possible reserves for the field.

The field development, implementation and start up plan was prepared and presented to the Nigerian Government authorities for their approval. Currently the field is producing as predicted from our work.
Return to Top

footer divider
HOME divider ACCOUNT HOLDERS divider CONTACT US divider LINKS
copyright divider
© 2017 Blade Energy Partners Website powered by Synectics