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About this Training
Integrated Production Modelling (IPM) is a powerful methodology that connects the reservoir, wells, and surface network into a unified model to analyze and optimize production performance. This intensive training course provides participants with the knowledge and practical skills to build, calibrate, and troubleshoot IPM models using industry-standard Petroleum Experts (Petex) tools — PROSPER, GAP, and MBAL.
Over four days, participants will work through realistic field-based exercises, covering every stage from well performance analysis and gas-lift design to network optimization and production forecasting. The course emphasizes applied learning, guiding participants to configure well, network, and reservoir models, link them dynamically, and interpret the results to support production decisions.
By the end of the program, participants will gain the confidence to construct complete integrated models, perform scenario-based optimization, and interpret model outputs to enhance field productivity. The course also introduces advanced features such as water injection modelling, SmartField concepts, and history matching techniques — ensuring participants are equipped with both operational and analytical competence for modern field development workflows.
Q1. What is Integrated Production Modelling (IPM)?
Integrated Production Modelling (IPM) is a systems-based approach that links reservoir performance, well behaviour, and surface network facilities into a single, connected model. Instead of analysing these components separately, IPM evaluates how changes in one part of the system affect overall field production. It is widely used for production forecasting, optimization, and decision-making across the life of an oil or gas field, from early development to late-life operations.
Q2. Why is Integrated Production Modelling important in field development and operations?
IPM is important because oil and gas production systems are highly interdependent. Reservoir deliverability, artificial lift performance, and surface constraints all influence actual production. IPM allows engineers to identify bottlenecks, test operating scenarios, and forecast realistic production outcomes. This integrated view reduces uncertainty, improves capital allocation, and supports operational decisions such as lift optimization, debottlenecking, and production planning.
Q3. How does Integrated Production Modelling differ from standalone well or reservoir modelling?
Standalone models analyze individual components in isolation, such as a single well or reservoir tank. IPM differs by coupling all components dynamically, allowing pressure, rate, and constraint interactions to be captured across the full system. For example, a well may appear capable of higher production in isolation, but IPM can reveal surface facility or network limitations that restrict flow. This makes IPM more realistic for operational and forecasting purposes.
Q4. What are the main components of an Integrated Production Model?
An integrated production model typically includes three core components:
Reservoir model (e.g., material balance or simplified reservoir representation)
Well models (covering inflow, tubing performance, and artificial lift systems)
Surface network model (pipelines, manifolds, separators, and constraints)
These components are linked so that changes in pressure, flow, or operating strategy propagate through the entire production system.
Q5. What are the common challenges when building and using IPM models?
Common challenges include data quality issues, model convergence problems, and maintaining consistency between reservoir, well, and surface assumptions. History matching integrated models can also be complex, as mismatches may originate from multiple system elements. Additionally, IPM models require careful calibration and regular updates to remain representative of actual field conditions, especially in mature or highly constrained assets.
Q6. How is Integrated Production Modelling used for production optimization?
IPM supports production optimization by evaluating scenarios such as artificial lift changes, gas-lift allocation, choke settings, facility upgrades, or water injection strategies. By simulating the entire system, engineers can identify the most effective way to increase production without violating constraints. IPM is particularly useful for prioritizing interventions and understanding trade-offs between wells competing for shared surface or lift-gas resources.
Q7. What role does Integrated Production Modelling play in forecasting and field planning?
IPM is widely used for short-, medium-, and long-term production forecasting. By linking reservoir depletion behaviour with surface and operational constraints, IPM produces more realistic forecasts than reservoir-only methods. It is commonly applied in field development planning, annual business planning, and evaluation of operating strategies, helping stakeholders understand expected production under different technical and operational scenarios.
Q8. What are the future trends in Integrated Production Modelling?
Future trends in IPM include increased automation, real-time data integration, and closer coupling with digital oilfield and SmartField concepts. Models are increasingly used alongside surveillance data to support near-real-time decision-making. There is also a growing focus on uncertainty analysis, low-pressure and late-life asset management, and integrating IPM with energy transition considerations such as efficiency optimization and emissions-aware operations.