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Download Now | Well completion program #drilling_manual_books_library The well completion refers to the lowermost part of a well that consists of tubulars and downhole equipment. Its primary purpose is to enable the safe and effective production of oil or gas from the well. The completion serves various objectives, including connecting the reservoir to the production tubing, providing a conduit for well stimulation fluids, protecting the well from sand or fines production, isolating productive zones from non-producing zones, isolating oil-producing zones from areas with high gas-oil ratio (GOR) and high watercut zones in oil reservoirs, isolating gas-producing zones from high gas-liquid ratio (GLR) zones in gas reservoirs, and providing a means to measure changes in reservoir conditions such as pressure, saturation, and rate through well tests, cased-hole logs, and production logs. Download Well completion program from our telegram books library link: https://lnkd.in/dUzTzemr Download Free Books: https://lnkd.in/dgnyhW2Q Watch Learning Videos: https://bit.ly/3pKS5dd #well_completion

SIMPLE OVERVIEW ABOUT WELL TESTING DEFINITION: 1.What is Well Testing? Well Test is the operation to obtain measurements of factors relating to production of oil, gas and water. 2. What is the objective of Well Testing? ▪ Conduct the testing in a safe and efficient manner ▪ Determine the nature of the formation fluids ▪ Measure reservoir pressure and temperature as accurately as possible ▪ Determine reservoir transmissibility (kh product) and skin damage ▪ Determine well productivity (and/or injectivity) ▪ Determine formation characteristics ▪ Evaluate boundary effects. • Reservior Description : to provide information about the reservior/ well for production • Reservior Evaluation : to determine the well parameters if satisfactory for production • Reservior Management: to give accurate parameters to make continued flow from the reservior. 3. What are different types of Well Test? ▪ Drill stem Tests: A drillstem test is performed during the drilling phase of the well. A drillstem test is: • Usually a temporary well completion. • Either open hole or cased hole. ▪ Cleanup Tests A cleanup test is performed on wells after they have been drilled, completed, and are ready to be placed on production. The purpose of a cleanup test is to: • o Flow the well at a controlled rate. • o Measure & dispose of cushion and rat-hole fluids. • o Measure & record a chronological log of events & production parameters. • o Establish & record a stabilized rate. • o Shut in well at end of cleanup for a short buildup. ▪ Production Well Tests Production well tests are performed periodically throughout the life of the well to: • o Establish the well’s potential. • o Gauge the well’s performance over the life of the reservoir. • o Use collected data in managing and optimizing the reservoir’s production. ▪ Long Term Tests • o A long-term test is performed to obtain the maximum amount of test data possible from a reservoir. • o An LTT is performed prior to the final design of the process facilities and the completion of the delineation wells throughout the reservoir. #WellTesting #OilandGas #WellTestingdefinition #typesofwelltest

For oilfield Engineers out there! Let us know about the warning signs of kick. In the oil and gas industry, understanding kick warning signs is crucial for maintaining well control and ensuring safety during drilling operations. A kick occurs when formation fluids enter the wellbore, potentially leading to dangerous situations if not identified and managed promptly. What Are Kick Warning Signs? Kick warning signs indicate that a well may be going underbalanced or that the safety margin is reducing. They serve as early indicators to prevent hazardous situations. Key Warning Signs: 1. Increasing ROP (Rate of Penetration): Indicates decreasing formation strength. 2. Higher Torque/Drag: Suggests formation pressure is increasing. 3. Changes in Cuttings: Increased size or quantity may point to unstable formation. 4. Gas Levels: Rising background gas or connection gas levels. 5. Temperature Increase: Indicates proximity to high-pressure zones. 6. Decreasing Shale Density: Suggests an increase in formation fluid pressure. Ignoring these signs can lead to severe consequences, such as wellbore instability or blowouts. Steps to Take: Flow Check: Confirm if the well is flowing unexpectedly. Circulate Bottoms Up: Remove any influx and regain control. Increase Mud Weight: Restore overbalance and maintain well stability. Understanding these indicators and taking timely action can save lives, reduce costs, and prevent environmental hazards. Stay vigilant, stay safe! #KickWarningSigns #WellControl #OilAndGas #DrillingSafety #FormationPressure #MudWeight #DrillingOperations #SafetyFirst #WellIntegrity #PressureManagement #OilfieldSafety #EnergyIndustry #DrillingInsights #OilfieldOperations #PreventiveMeasures

IOGP show effect of Gas Migration during Bullheading operations Always use Max flow rate and Hivis sweeps ahead brine during bullheading Hi GOR wells meanwhile consider others parameters ( Frac and burst limit) plus surface equipment limitation !

Well Control Incident Lesson Sharing #24-12: Undetected fluid swap during bullheading operation led to hydrocarbon migration to surface This case is an example of undetected fluid swap during bullheading operation due to lower BH rates and consequent hydrocarbon migration that led to a well control event. This event took place during the plug and abandon of a cased hole reservoir; the plan was to scrape the casing above perforations, set a cement retainer above perforation, squeeze cement below cement retainer, displace the well to mud, set whipstock and sidetrack the well. During tripping out the clean out BHA, the team observed gains on TT and decided to perform a bullhead to pump back fluid that might have entered the well. The well was stabilized, and operation continued. During displacement of brine with mud, dark brine was observed at the shaker as well as indication of gas breaking out. The displacement was suspended, the riser gas handler (slimline annular) closed, and riser degassed before operation continued. With thanks to the contributing company and members of the WCI Subcommittee. For all IOGP WCI lesson sharings go to https://lnkd.in/ekYJRKsh #wellcontrol #drilling #oilindustry

A blowout is the uncontrolled release of crude oil and/or natural gas from an oil well or gas well after pressure control systems have failed. Modern wells have blowout preventers intended to prevent such an occurrence. An accidental spark during a blowout can lead to a catastrophic oil or gas fire. A blowout begins as a Kick (entry of subsurface formation fluids into the wellbore). What distinguishes a kick from a blowout is that a kick can be controlled while a blowout is uncontrollable. We have already discussed two of the defenses against kicks when we discussed drilling fluids when we listed the objectives of the drilling fluid: *. control formation pore pressures to assure desired well control (apply hydrostatic and hydrodynamic pressures in excess of the formation pore pressures to prevent fluids from entering the wellbore). *. deposit an impermeable filter cake onto the wellbore walls to further prevent fluids from permeable formations from entering the wellbore.

#️⃣PART #️⃣5 #️⃣PRODUCTION 🔵Well production refers to the amount of fluid a well can produce or inject per unit of pressure difference between the wellbore and the reservoir. 🔵A well's productivity is influenced by a number of factors, including: ⚪The size of the reservoir ⚪ The quality of the rock ⚪ The well's design. 🔵Companies study well productivity to determine a well's profitability and to make decisions about drilling and production. 🔵Some ways to increase well production include: Drilling deeper, Adding a storage tank, Adding a secondary well, and Reducing water use. 🔵A gas lift system can also be used to increase well production. This system injects gas into the well casing to help lift liquids to the surface.

🛢️Did you know over 60% of oil can stay trapped in a reservoir even after drilling? 🛢️ Here’s how advanced recovery methods are unlocking that hidden potential… Oil recovery is far more than just drilling a hole in the ground. To bring oil to the surface, two key conditions must be met: 1️⃣ A clear pathway that connects the oil in the reservoir to the surface. 2️⃣ Sufficient energy in the reservoir to drive the oil upward. Without these, much of the oil remains trapped in the reservoir, making further development uneconomical. Even when both conditions are satisfied, it’s impossible to recover all of the displaceable oil. Oil reservoirs can be complex, often containing gas caps, aquifers, or both. Crude oil resides within tiny pores and fractures in the rock, and these formations vary significantly in size, shape, and connectivity. Drilling a well into these formations requires precision. For example, puncturing the limestone dome in the wrong spot can result in the extraction of only gas or saltwater.🌊 Primary Recovery In the early stages, natural pressure in the reservoir forces oil to the surface—this is known as primary recovery. Gaseous fuels or natural gas within the reservoir help maintain this pressure. When the conditions are right, a simple arrangement of valves, known as the Christmas tree, at the wellhead is enough to connect the well to a pipeline network for processing. Secondary Recovery However, as the well’s pressure declines over time, primary recovery methods alone become insufficient. That’s when secondary recovery techniques are applied. In these methods, water or gas is injected into the reservoir to maintain pressure, forcing the remaining oil to the surface. These advanced processes are crucial for maximizing the amount of oil extracted and ensuring the long-term viability of the reservoir.💧⚙️ Don't forget to follow me for more posts like this every other day on Linkedin. https://lnkd.in/eyAFhmPD #OilRecovery #EnhancedOilRecovery #OilExtraction #ReservoirEngineering #PrimaryRecovery #SecondaryRecovery #EnergyIndustry #OilAndGasTechnology

Flowing Material Balance (FMB) Tool: The Flowing Material Balance (FMB) is an analytical method that allows reservoir engineers to estimate key reservoir parameters without requiring well shut-in. By analyzing production data, including only oil rates (qo) and flowing wellhead pressure (FWHP) or flowing bottom hole pressure (FBHP), engineers can approximate: -- Original Oil-in-Place (OOIP): The total volume of oil initially present in the reservoir. -- Average Reservoir Pressure (Pavg): The average pressure within the reservoir. -- Permeability (K). -- Drainage Area (A): The area of the reservoir that contributes to production from a well. -- Oil Recovery Factor (RF): The proportion of the OOIP that can be recovered. This technique provides valuable insights into reservoir performance and can be used to optimize production strategies #Link_to_download_the_file: https://lnkd.in/eYTNmWqX #petroleumengineering #reservoirengineering #oilgas