Production Optimization Methods for Field Operators

For Nigeria's Project 3M bopd, instead of defaulting to: -Drilling more wells -Increasing interventions Operators should first ask: -Are we operating at optimal network conditions? -Which wells are constraining the system? -Can selective shut-ins or choke optimisation unlock hidden capacity? Today, during our retreat, I shared a case example with my colleagues from a project on integrated production system modelling (IPSM) I did over 10 years ago. Here, four oil wells were producing into a common manifold and one of the wells was shut in and "unexpectedly", total production increased by almost a thousand barrels per day? This appeared counterintuitive at first glance. How can producing from fewer wells result in higher output? This is where integrated production system modelling and analytics come in. With the right tools and expertise, operators can: -Diagnose system constraints -Simulate alternative operating scenarios -Unlock production without additional CAPEX When multiple wells produce into a shared system, they don’t operate independently. They interact through flowlines and manifolds. Each additional well contributes to system backpressure, which in turn increases flowing wellhead pressure and reduces drawdown. By shutting in one well, the system experiences: -Reduced backpressure, -Increased drawdown for the remaining wells. -Improved flow conditions This of course leads to increased production. In many assets, especially where infrastructure is constrained, one poorly performing or high-backpressure well can penalise the entire network/system. This is the reason why CypherCrescent Limited recommend integrated production system modeling as a foundational option before well intervention and drilling. It is interesting that most of the operators in Africa still do not prioritize integrated production system modelling before well intervention decisions are made. I’m a strong advocate of well intervention but before we intervene, we must first get the fundamentals right through proper system housekeeping

Using Node Analysis to Troubleshoot Low-Producing Wells One of the most common mistakes in production optimization is assuming that every low-producing well has a reservoir problem. In reality, the bottleneck may exist anywhere between the reservoir and the surface facilities. This is where Node Analysis becomes a powerful diagnostic tool. Rather than guessing, engineers can systematically identify where production is being restricted and focus on the right solution. Where Can Production Be Lost? A well’s performance depends on three major systems: 🪨 Reservoir (Inflow) ⚙ Wellbore (Flow Path) 🏭 Surface Facilities (Outflow) A restriction in any one of these systems can reduce production. Reservoir Bottlenecks Common indicators include: 📉 Reservoir pressure depletion 📉 Weak inflow performance 📉 Reduced deliverability Possible solutions: ✅ Pressure maintenance ✅ Water injection ✅ Gas injection ✅ Stimulation treatments Wellbore Bottlenecks Many wells suffer from restrictions inside the well itself. Examples include: ⚠ Scale deposition ⚠ Wax buildup ⚠ Tubing restrictions ⚠ High friction losses Potential solutions: ✅ Cleanout operations ✅ Chemical treatments ✅ Tubing optimization ✅ Scale and wax removal Surface Bottlenecks Sometimes the reservoir and wellbore perform well, but surface facilities limit production. Examples include: 🏭 High separator pressure 🏭 Choke restrictions 🏭 Flowline constraints 🏭 Facility capacity limitations Solutions may include: ✅ Reducing backpressure ✅ Optimizing choke settings ✅ Upgrading facilities Artificial Lift Problems Artificial lift systems can also become production bottlenecks. Common issues include: ⚙ ESP inefficiency ⚙ Incorrect gas lift design ⚙ Equipment wear ⚙ Poor operating conditions Optimization often results in significant production gains without any reservoir intervention. Why Node Analysis Works Node Analysis combines: 📈 Reservoir inflow performance (IPR) 📈 Wellbore and surface outflow performance (VLP) By finding the operating point and evaluating system constraints, engineers can identify the largest restriction in the production system. A Real Lesson Many production problems are not reservoir problems. A well producing below target may simply be suffering from excessive backpressure, poor lift performance, or tubing restrictions. Fixing the wrong problem wastes time and money. Finding the true bottleneck creates value. Key Takeaway ⭐ Node Analysis identifies production bottlenecks. ⭐ Not every low-rate well has a reservoir problem. ⭐ Reservoir, wellbore, and surface systems must all be evaluated. ⭐ The best optimization target is usually the largest restriction in the system. #PetroleumEngineering #ProductionEngineering #NodeAnalysis #ProductionOptimization #ArtificialLift #WellPerformance #ReservoirEngineering #IPR #VLP #OilAndGas #PetroleumEngineer #HydrocarbonProduction #EnergyIndustry #FieldDevelopment

🚀 Unlocking Efficiency with Digital Twins in Sucker Rod Pumping (SRP) 🛢️⚙️ In today’s oilfield, data collection alone is no longer enough. The real value comes from transforming operational data into predictive, actionable intelligence that drives production, reliability, and cost efficiency. This is where Digital Twin technology becomes a true game changer. A Digital Twin is not just a visualization tool—it is a dynamic, real-time virtual replica of the physical well and its sucker rod pumping (SRP) system, continuously fed by live field data from SCADA, sensors, historians, and production systems. It allows operators to move from reactive decisions to proactive optimization. 🔍 What Digital Twins Enable: 📡 Real-Time Monitoring Continuous surveillance of pump performance, load conditions, fluid levels, and well behavior—allowing faster and smarter operational decisions. 🛠️ Predictive Maintenance Anticipate failures before they happen by identifying wear patterns, rod stress issues, pump inefficiencies, and equipment degradation. ⚙️ Stroke & Speed Optimization Optimize stroke length and strokes per minute (SPM) based on reservoir response and pump conditions to maximize production efficiency. 🚨 Early Anomaly Detection Rapid identification of issues such as gas interference, fluid pound, pump-off conditions, tubing leaks, and rod string failures. 📈 Accurate Production Forecasting Simulation models improve forecasting accuracy and support production planning with stronger confidence. 📊 Full Lifecycle Performance Analytics Track equipment health, operational efficiency, and long-term asset performance to improve decision-making across the entire asset lifecycle. Making Digital Twins successful at scale requires more than software—it requires deep domain expertise, strong OT/IT integration, and reliable digital infrastructure. This is how digital transformation moves from concept to measurable field results. 💡 Real Example: A Digital Twin detects decreasing pump efficiency and identifies increasing gas interference in a producing well. Using modeled scenarios, the system recommends: 🔹 Lowering the pump setting depth 🔹 Adjusting the SPM (Strokes Per Minute) The result? ✅ Restored production ✅ Improved pump fillage ✅ Reduced operational risk ✅ Avoided premature pump failure ✅ Lower intervention costs That’s the power of predictive operations. Whether you're optimizing artificial lift systems or scaling a broader Digital Oilfield strategy, Digital Twins are becoming essential for operational excellence. 👀 Check out the diagram and let me know: How are you applying Digital Twins in your operations today? #DigitalTwin #ArtificialLift #SuckerRodPumping #OilAndGas #DigitalOilfield #ProductionOptimization #SCADA #FieldAutomation #OT #Industry40 #Automation #PredictiveMaintenance #ArtificialLiftOptimization

Shrinking resource pools, fewer recoverable barrels, inflation, and expanding regulation are compressing margins and challenging the ability of traditional PDP assets to sustain legacy balance sheets. As decline curves steepen, it is essential for PDP to transition from passive cash flow to actively optimized assets. Enhanced oil recovery efforts such as waterfloods, gas injection, and chemical EOR extend reservoir life by improving sweep efficiency, wettability, and reservoir conductivity, ultimately increasing recovery rather than merely pursuing new volumes. At the well level, proper lift optimization is crucial for maintaining value. Maximizing production involves: - Optimizing pumping efficiency and wellbore drawdown through disciplined fluid-level surveillance. - Routinely shooting fluid levels and adjusting stroke length and strokes per minute to align lift capacity with reservoir inflow. - Matching lift to production to minimize gas interference, reduce mechanical stress, and stabilize rates and volumes. In addition to conventional rod lift, evaluating alternative artificial lift methods is vital. Gas lift can reduce lifting costs in higher GOR wells, ESPs can unlock higher-rate opportunities where power economics permit, plunger lift enhances liquid unloading in gassy wells, PCPs manage viscous fluids and solids, and jet pumps provide flexibility in deviated or sand-prone wells. Selecting the appropriate system requires balancing CAPEX, OPEX, reliability, and reservoir behavior. While commodity price cycles may influence industry growth, they remain uncontrollable. Overcoming the challenges of declining production involves cost discipline, recovery optimization, and technical execution extracting more barrels per well at lower lifting costs over extended lifespans. Through EOR, lift optimization, and intelligent artificial lift selection, PDP assets can continue to support balance sheets despite structural industry headwinds. 4cast ComboCurve Enverus Alfonso Peccatiello Arthur R. Daniel Berry Benjamin Mooney Preston Page Philip Reed Calvin Holt William R. #oilgas #LinkedIn #networking #finance #definitelyAI #AI #energy