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

🚀 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

𝐏𝐫𝐨𝐝𝐮𝐜𝐭𝐢𝐨𝐧 𝐋𝐨𝐠𝐠𝐢𝐧𝐠 𝐓𝐨𝐨𝐥𝐬 (𝐏𝐋𝐓𝐬): 𝐔𝐧𝐥𝐨𝐜𝐤𝐢𝐧𝐠 𝐖𝐞𝐥𝐥 𝐏𝐞𝐫𝐟𝐨𝐫𝐦𝐚𝐧𝐜𝐞 In the oil and gas sector, understanding well behavior is key to optimizing production. Production Logging Tools (PLTs) are specialized instruments used to assess downhole conditions, providing critical insights into fluid movement, reservoir performance, and well integrity. 𝐇𝐨𝐰 𝐏𝐋𝐓𝐬 𝐖𝐨𝐫𝐤: PLTs are run into the wellbore using wireline, slickline, or coiled tubing, depending on well conditions. These tools gather real-time data on various parameters, including: ✅ Flow Rate: Determines the contribution of each zone in a multi-zone well. ✅ Fluid Identification: Differentiates between oil, gas, and water phases. ✅ Pressure & Temperature: Helps evaluate reservoir conditions and diagnose anomalies. ✅ Flow Profile: Maps out how fluids move across different sections of the well. 𝐖𝐡𝐲 𝐀𝐫𝐞 𝐏𝐋𝐓𝐬 𝐈𝐦𝐩𝐨𝐫𝐭𝐚𝐧𝐭? 𝐏𝐋𝐓𝐬 𝐩𝐥𝐚𝐲 𝐚 𝐯𝐢𝐭𝐚𝐥 𝐫𝐨𝐥𝐞 𝐢𝐧 𝐩𝐫𝐨𝐝𝐮𝐜𝐭𝐢𝐨𝐧 𝐨𝐩𝐭𝐢𝐦𝐢𝐳𝐚𝐭𝐢𝐨𝐧 𝐚𝐧𝐝 𝐭𝐫𝐨𝐮𝐛𝐥𝐞𝐬𝐡𝐨𝐨𝐭𝐢𝐧𝐠 𝐰𝐞𝐥𝐥 𝐢𝐬𝐬𝐮𝐞𝐬 𝐛𝐲: 🔹 Identifying water or gas breakthrough, which can impact production efficiency. 🔹 Detecting crossflow between formations, preventing unwanted fluid movement. 🔹 Providing insights for artificial lift optimization and enhanced oil recovery (EOR) strategies. 🔹 Aiding in reservoir modeling and forecasting, ensuring long-term productivity. 𝐀𝐝𝐯𝐚𝐧𝐜𝐞𝐦𝐞𝐧𝐭𝐬 𝐢𝐧 𝐏𝐋𝐓 𝐓𝐞𝐜𝐡𝐧𝐨𝐥𝐨𝐠𝐲: Modern PLTs integrate high-resolution sensors, fiber optics, and advanced data analytics, offering operators real-time, high-accuracy insights to make faster, data-driven decisions. As technology evolves, PLTs continue to enhance well surveillance, enabling cost-effective and efficient production management. #OilAndGas #ProductionLogging #PLT #ReservoirManagement #WellOptimization #EnergyTechnology

Autonomous operations and semi-autonomous operations apply to all plants: paper pulp and steel mills, mines, chemical and pharmaceutical plants, refineries, power stations, and water works etc., not just for offshore platforms or remote oil fields. Autonomous operations mean the plant operations including maintenance inspection are automatic and run unattended for long periods of time. For an offshore or remote installation like an unmanned (normally not manned) oil & gas platform this means no visits by people for many months, only by exception. For other plans it means less time spent in the field and reduced crew at night and on weekends referred to as semi-autonomous operations. Shifts can be shortened from twelve to 8 hours. That is, autonomous operations solutions must be designed to coexist with human operators and technicians as humans cannot be replaced entirely. Autonomous operations go together with human supervision from a central location. The vision is less console operator intervention in the control room such as control loop mode changes, juggling setpoint changes for multiple interacting loops, and manual output changes. And less field operator intervention out in the plant such as reading mechanical gauges, grab sampling, and hand operating manual valves. As well as less maintenance technician inspection of equipment such as rounds with portable testers for vibration, leak detection, and corrosion etc. Solutions include multivariable Advanced Process Control (APC) to automate setpoint changes and State-Based Control (SBC) for procedural automation of startup, shutdown, and grade changes etc. Wireless sensor system to automate manual data collection with AI for real-time data interpretation. Wireless valve remote control of actuation deployed on manual valves. That is, not all solutions are for complete autonomous operations. Some solutions are deployed to enable remote operations from a central location of functions that cannot be fully automated – where central location may refer to the central control room (CCR) within the plant or a fleet management center on the other side of the world. Once data collection and valve actuation has been digitalized it doesn’t matter where the supervising human being sits. Software is only part of the solution. The control systems, sensors, actuators, and valves are best implemented as a tight end-to-end automation ecosystem. 🕮Read full essay for the recommendations to make rolling out autonomous operations easy: https://lnkd.in/grbBNEcu Like 👍 Comment 💬 Repost ↱ Click my photo then the bell to get updates 🔔