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Well Testing Operations Before and After Coiled Tubing Operations 🔎 Well testing operations integrated with coiled tubing (CT) are essential for ensuring well performance and safety. 1. Flow Back 2. Flow Test 3. Clean Up 4. Integrity Test Below is a detailed breakdown, including job procedures, equipment, and their functions. 1. Flow Back ⭐ Flow back is the process of allowing fluids or gas from the well to flow to the surface, typically after hydraulic fracturing, drilling, or completion operations. Job Procedure: 📝 - Before CT Operations: 1. Rig up flowback equipment. 2. Open the well and monitor flow conditions to ensure safe handling of fluids. 3. Allow the well to flow naturally or via artificial lift to remove wellbore fluids (e.g., completion or kill fluids). 4. Analyze flow rates and fluid composition for well productivity assessment. - After CT Operations: 1. Rig up flowback equipment post-CT operation. 2. Allow the well to flow to remove fluids or debris introduced during CT operations. 3. Monitor for signs of formation fluid recovery, debris, or gas breakthrough. Equipment and Function: 🛠️ • Flowback Manifold: Directs and controls flow from the well to the surface. • Sand Separator: Removes solid particles like proppant or debris to protect downstream equipment. • Gas Buster/Degasser: Separates gas from liquids to prevent pressure buildup in tanks. • Surge Tank: Collects flowback fluids and gas for temporary storage. 2. Flow Test ⭐ A flow test determines the well's production capability and reservoir characteristics by measuring flow rates, pressures, and fluid composition. Job Procedure: 📝 - Before CT Operations: 1. Rig up well testing equipment (test separator, manifolds, gauges). 2. Conduct initial wellhead pressure monitoring to ensure the well is ready for testing. 3. Gradually open the well to flow into the test separator while monitoring flow parameters. 4. Record pressure, temperature, and flow rates to establish baseline production characteristics. - After CT Operations: 1. Reconfigure well testing equipment if necessary. 2. Perform flow testing to evaluate the impact of CT interventions (e.g., stimulation, cleanout). 3. Monitor for improvement in production rates and compare with baseline data. Equipment and Function: 🛠️ • Test Separator: Separates oil, gas, and water for individual measurement. • Flow Meter: Accurately measures fluid and gas flow rates. • Pressure and Temperature Gauges: Monitor wellhead and downstream conditions. • Storage Tanks: Hold produced liquids for measurement or disposal. ⭐ Number 3 & 4 on comment Ready to take your well intervention to the next level? Share this post and let's inspire others. Let's connect on LinkedIn! Mohammad Fuad Anshori #uptimeoptimization #oilandgastechnology #wellservices #petroleumindustry #energyinnovation

A Casing Running Tool (CRT)TXGN is a crucial piece of equipment used in well completions and drilling operations. Its primary function is to facilitate the safe and efficient installation of casing strings into the wellbore. The CRT typically consists of a hydraulically operated mechanism that grips the casing securely and enables controlled lowering or lifting of the casing string into or out of the wellbore. The significance of a Casing Running Tool in well completions lies in several key aspects: 1. **Safety**: CRTs help ensure the safety of personnel and equipment by providing a controlled method for handling heavy casing strings, reducing the risk of accidents and injuries during casing installation. 2. **Efficiency**: By automating the casing running process, CRTs increase operational efficiency by reducing manual labor and minimizing downtime associated with casing installation. 3. **Precision**: CRTs enable precise positioning of casing strings within the wellbore, ensuring proper alignment and integrity of the wellbore structure. 4. **Versatility**: CRTs can be used in various wellbore conditions, including deviated or horizontal wells, making them versatile tools for a wide range of completion scenarios. 5. **Monitoring and Control**: Many modern CRTs are equipped with sensors and monitoring systems that provide real-time feedback on casing running operations, allowing operators to maintain control and make adjustments as needed. Overall, the Casing Running Tool plays a critical role in ensuring the success of well completions by providing a safe, efficient, and controlled method for installing casing strings into the wellbore.

#Well_Intervention? often referred to as well work, is any activity conducted on an oil or gas well either during its active or final production life. These activities aim to modify the well’s condition or structure, offer diagnostic assessments, or oversee the well’s production processes. What Are The Techniques Used in Well Intervention? Engineers have several methods available to them for performing the well intervention. These methods are created to guarantee that wells maintain their productivity and efficiency in the long run. 1. Coiled Tubing Operations Coiled tubing operation does not rely on traditional drill pipes. This method involves inserting a continuous coil of tubing, typically made of steel or composite material, wound onto a large spool, into the wellbore. 2. Wireline (Slickline and E-line) Oil and gas well engineers often use wirelines as a method of well intervention to perform various tasks. This method involves inserting a cable or wireline into the wellbore to deploy different types of equipment and tools downhole. 3. Snubbing Operations The technique of snubbing is a well intervention method that enables the execution of operations on pressurized wells without the need to kill the well, and it is useful for dealing with challenging situations like live well completions, well workovers, and plugging and abandonment. 4. Well Control During drilling operations, maintaining the pressure of the drilling mud, a fluid circulated through the wellbore to remove cuttings and stabilize it, is crucial to achieving well control. If the pressure of the formation exceeds the mud’s pressure, a kick can occur, potentially leading to a blowout if not controlled. Blowout preventers (BOPs), specialized equipment that can seal the wellbore and stop the fluid release, are used to prevent blowouts. 5. Subsea Well Intervention Subsea well intervention presents several challenges and requires thorough planning. These interventions are typically carried out using either light/medium intervention vessels or mobile offshore drilling units (MODUs) for more substantial tasks like snubbing and workover drilling rigs. What Is The Impact of Well Completion on Well Intervention Operations? Well-completion can significantly impact well intervention operations in various ways. For instance, the type of completion method, such as open-hole, cased hole, or perforated completion, can affect the ease and effectiveness of well intervention. Open-hole completion may provide better access to the reservoir and require less intervention to maintain productivity, while cased-hole completion may need more intervention due to potential blockages or other issues. The success of well intervention can be influenced by the completion’s condition, such as the quality of the cement bond. Poor cement bonding or equipment damage can create difficulty in accessing the target zone or stimulating the well.

Field Operations Engineer 🖤💀⚙️ This configuration looks good, what do you think? 🔥☕ Since coiled tubing is a versatile tool that finds numerous applications in the oil and gas industry, there are diverse applications of coiled tubing that help the drilling procedure to be done easier. Circulating, pumping, coiled tubing drilling, production, logging and perforating commonly apply coiled tubing. - Circulation Coiled tubing is a beneficial tool for circulation in well interventions due to its continuous length ability to navigate complex wellbores. In some cases, the flow of formation fluids in a well may be impeded by the weight of a hydrostatic head. To restore the flow, coiled tubing can be inserted into the wellbore allowing production to resume. - Pumping and Cleaning Another common application of coiled tubing is for pumping operations in oil and gas wells to deliver various fluids and treatments. It is employed in applications such as hydraulic fracturing, well stimulation, cementing, acidizing, and nitrogen purging. To initiate pumping, the coiled tubing is connected to a surface pumping unit or a dedicated pumping system. Fluids are then pumped down the coiled tubing string, which is inserted into the well. The continuous length of coiled tubing enables uninterrupted pumping, ensuring a consistent and controlled flow rate. - Coiled Tubing Drilling As the name conveys, coiled tubing can be employed for Coiled Tubing Drilling (CTD) operations that involve utilizing a coiled tubing string as a drill pipe to carry out drilling tasks in oil and gas wells. In Coiled Tubing Drilling, the coiled tubing is inserted into the well and equipped with a bottom hole assembly that comprises a drill bit. The coiled tubing is then rotated and pushed into the rock formation, enabling the drill bit to cut through the rock and establish a wellbore. - Logging and Perforating Coiled tubing is specifically employed in logging operations to lower specialized tools and instruments into the wellbore, enabling the collection of data for evaluating subsurface formations. These tools, including logging tools and sensors, are connected to the coiled tubing string and utilized to measure formation pressure, temperature, fluid composition, and rock properties. The acquired data aids in assessing reservoir characteristics and making informed decisions regarding production strategies. - Production Coiled tubing can be employed in production operations to support a range of activities to maximize well productivity. One prevalent application involves well stimulation, where fluids, chemicals, or proppants are injected through the coiled tubing string into the well. This process enhances the performance of the reservoir, leading to an increase in hydrocarbon production. #oilgas #wellservices #professionalexperiences #engineering #ecuador #petroleumengineer #wellintervention #engineer #work #moments #worksafe #workhard #IADC #IWCF #PetroleumServices

Main Components of Coiled Tubing and Their Functions Coiled tubing (CT) is a long, flexible pipe used for different jobs in oil and gas wells. CT can go deep into wells without taking it apart, which saves time. It has several main parts that work together to make it safe and effective for well operations. I will try to explains the key parts of coiled tubing and what each part does it. - Coiled Tubing Reel Function: The reel is the big drum that holds the coiled tubing. It is where the tubing is stored and unrolled. During work, the reel rotates to push the tubing into the well or pull it out. Importance: The reel keeps the coiled tubing organized and ready for quick use. It also controls how much tubing goes into the well. - Injector Head Function: The injector head pushes or pulls the tubing in and out of the well. It uses chains and gripping blocks to hold the tubing tight while moving it. Importance: This part provides the force to move the tubing against gravity or well pressure. It is strong and must hold the tubing firmly to prevent slipping. - Gooseneck Function: The gooseneck is a curved guide above the injector head. It bends the tubing from the reel and feeds it into the injector in a controlled way. Importance: The gooseneck keeps the tubing from kinking or getting damaged while it moves. It controls the angle and path of the tubing to avoid stress. - Control Cabin Function: This is the main control room where the operator manages all parts of the coiled tubing unit. The operator controls pressure, speed, and other settings from here. Importance: The control cabin allows safe and precise control over the operation. It helps avoid problems by monitoring key data like tubing force, depth, and pressure. - Power Pack Function: The power pack supplies the hydraulic power needed for the injector, reel, and other tools. It is often a diesel engine connected to hydraulic pumps. Importance: Without the power pack, the CT unit cannot operate. It supplies the force for moving tubing and running the tools downhole. - Blowout Preventer (BOP) Function: The BOP is a safety device that closes around the tubing to control well pressure. It prevents oil, gas, or fluids from escaping if there is a pressure surge. Importance: BOPs protect against blowouts, which are dangerous for people and the environment. They keep the operation safe under high-pressure conditions. - Stripper Function: The stripper seals around the tubing to prevent well fluids from escaping as the tubing goes in and out. It uses rubber elements to create a seal around the tubing. Importance: The stripper is essential for keeping a closed well system, even with moving tubing. It works with the BOP to control fluids and pressure. Each part of the coiled tubing system plays a vital role in the operation. From the reel to the BHA, all components work together to make sure the coiled tubing can perform safely and effectively. #CT #CoiledTubing #OilandGas #Petroleum

A liner hanger is a critical component used in oil and gas well completions to suspend a liner (a section of casing) from the casing string above it, rather than extending the liner all the way to the surface. This technique is widely used in wells to save costs and simplify operations. Here's a breakdown of the basics of liner hangers: 1. Purpose of a Liner Hanger Suspend Liners: Supports the liner within the casing without needing to extend it to the surface. Reduce Costs: Using liners instead of full casing strings reduces material and operational costs. Flexibility: Facilitates various well configurations, including multistage completions. Zonal Isolation: Works with cement to provide isolation between different well zones. 2. Types of Liner Hangers Mechanical Liner Hanger: Activated by mechanical tools or weight. Reliable in wells with simpler geometries. Hydraulic Liner Hanger: Activated by hydraulic pressure applied to the liner hanger tool. Preferred in horizontal or deviated wells where mechanical activation may be challenging. 3. Components of a Liner Hanger System Liner Hanger Body: The main structural component that connects to the liner. Slip Mechanism: Metal wedges that grip the inside of the casing wall to suspend the liner. Packer (Optional): Provides a seal between the liner and casing for zonal isolation. Running Tool: Used to lower the liner hanger and liner into the wellbore and activate the hanger. Tieback Assembly (Optional): Connects the liner to the surface casing later if needed. 4. Installation Process 1. Preparation: Assemble the liner, liner hanger, and running tool at the surface. 2. Run-in-Hole (RIH): Lower the assembly into the wellbore to the desired depth. 3. Set the Hanger: Mechanical Hanger: Apply weight or rotation to set slips against the casing wall. Hydraulic Hanger: Apply hydraulic pressure to set slips. 4. Cementing: Pump cement through the liner and into the annulus for zonal isolation. 5. Release Running Tool: Disconnect the running tool and retrieve it to the surface. 5. Advantages of Liner Hangers Cost-Effective: Reduces casing material and rig time. Efficient Cementing: Improves cement job quality by minimizing circulation losses. Flexibility: Adapts to complex well architectures, including horizontal and multilateral wells. Reduced Load on Casing: Lowers the weight and stress on the surface casing. 6. Common Challenges Tool Activation: Ensuring proper setting of the hanger in challenging well conditions. Zonal Isolation: Achieving a reliable seal, especially in highly deviated or horizontal wells. Well Conditions: Dealing with high temperatures, pressures, or corrosive environments.

good to know about CT components

Coiled tubing operation: technique used for well intervention without using traditional drill pipes. It employs a continuous coil of tubing, typically made of steel or composite material, wound onto a large spool and then inserted into the wellbore. This method allows for various tasks to be performed in the wellbore efficiently. Coil tubing is sometimes needed when the well completion and workover are performed. used for a wide range of tasks, including well cleanouts, acid stimulation, fracturing, cementing, logging, plug setting or retrieval, and stuck pipe prevention. The coiled tubing is typically deployed into the wellbore through a specialized injector head, which controls the speed and tension of the tubing as it is fed into the well. Once the desired depth is reached, various tools and equipment can be run through the coiled tubing to perform the required tasks. Application of Coiled Tubing 1. Circulation: beneficial tool for circulation in well interventions due to its continuous length ability to navigate complex wellbores. In some cases, the flow of formation fluids in a well may be impeded by the weight of a hydrostatic head. To restore the flow, coiled tubing can be inserted into the wellbore allowing production to resume. 2. Pumping : employed in applications such as hydraulic fracturing, well stimulation, cementing, acidizing, and nitrogen purging. To initiate pumping, the coiled tubing is connected to a surface pumping unit or a dedicated pumping system. Fluids are then pumped down the coiled tubing string, which is inserted into the well. The continuous length of coiled tubing enables uninterrupted pumping, ensuring a consistent and controlled flow rate. 3. Coiled Tubing Drilling(CTD) operations that involve utilizing a coiled tubing string as a drill pipe to carry out drilling tasks in oil and gas wells, coiled tubing is inserted into the well and equipped with a bottom hole assembly that comprises a drill bit. The coiled tubing is then rotated and pushed into the rock formation, enabling the drill bit to cut through the rock and establish a wellbore. 4. Logging and Perforating: is specifically employed in logging operations to lower specialized tools and instruments into the wellbore, enabling the collection of data for evaluating subsurface formations. These tools, including logging tools and sensors, are connected to the coiled tubing string and utilized to measure formation pressure, temperature, fluid composition, and rock properties. The acquired data aids in assessing reservoir characteristics and making informed decisions regarding production strategies. 5. Production operations: support a range of activities to maximize well productivity. One prevalent application involves well stimulation, where fluids, chemicals, or proppants are injected through the coiled tubing string into the well. This process enhances the performance of the reservoir, leading to an increase in hydrocarbon production. #coiledtubing

A Blowout Preventer (BOP) is a critical safety device used in drilling operations to prevent blowouts, which are uncontrolled releases of crude oil or natural gas from a well. Here are the main functions and operations of a BOP: Functions of a BOP: 1. Well Control: The primary function of a BOP is to control the well by sealing the wellbore and preventing the escape of fluids. 2. Pressure Regulation: It helps in maintaining the pressure within the wellbore, ensuring safe drilling operations. 3. Emergency Shutoff: In case of a kick (unexpected influx of formation fluids), the BOP can shut off the well to prevent a blowout. 4. Safety: Protects the rig crew and environment by preventing hazardous situations. Types of BOPs: 1. Annular BOP: Uses a rubber sealing element to close around the drill pipe, casing, or open hole. 2. Ram BOP: Uses steel rams to seal the wellbore. There are different types of rams, including: - Pipe Rams: Seal around the drill pipe. - Blind Rams: Seal the wellbore when no pipe is present. - Shear Rams: Cut through the drill pipe and seal the wellbore. Operations of a BOP: 1. Installation: BOPs are installed on top of the wellhead and are connected to the choke and kill lines. 2. Activation: BOPs can be activated manually or automatically using hydraulic or electric control systems. 3. Testing: Regular testing is conducted to ensure the BOP is functioning correctly and can handle the expected pressures. 4. Maintenance: Routine maintenance is essential to keep the BOP in good working condition and to replace worn-out parts. Components of a BOP Stack: - Annular Preventer: Positioned at the top of the BOP stack. - Ram Preventers: Positioned below the annular preventer, typically in multiple layers. - Choke and Kill Lines: Used to control the pressure and circulate fluids during well control operations. - Control Systems: Include hydraulic accumulators, control pods, and valves to operate the BOP. Understanding the role and operation of a BOP is crucial for ensuring safety and efficiency in drilling operations.

The RTTS packer is a versatile tool used in drilling well operations. Here are some key points about its operations and uses: 1. Purpose: - The RTTS packer is designed for testing, treating, and squeeze cementing operations in oil wells. - It can be run with a circulating valve assembly to facilitate fluid flow during operations. 2. Components: - The packer body includes: - A J-slot mechanism for setting and releasing the packer. - Mechanical slips to anchor the packer in the wellbore. - Packer elements for sealing the annulus. - Hydraulic slips for additional anchoring. 3. Operation: - The RTTS packer is typically run with a circulating valve below it. - During testing or treatment, the circulating valve can be opened by straight pull as needed. - A safety joint is placed above the packer to allow for releasing the work string if the packer becomes stuck during the operation. Remember that safety procedures and proper handling are crucial when using tools like the RTTS packer in well completion and intervention. Always follow industry best practices and guidelines! 🛢️🔧. ......... Setting an RTTS packer in a wellbore involves several steps. Let's break it down: 1. Running In: - The RTTS packer is part of the completion string (work string) that is lowered into the wellbore. - It is typically run with a circulating valve assembly below it. 2. Positioning: - The packer is positioned at the desired depth within the wellbore. - The J-slot mechanism on the packer body allows for setting and releasing. 3. Setting the Packer: - The packer is set by applying axial tension to the work string. - The J-slot mechanism engages, locking the packer in place. - Mechanical slips anchor the packer against the casing or wellbore wall. 4. Sealing the Annulus: - The packer elements (usually made of rubber or elastomer) expand radially against the casing. - This creates a seal, preventing fluid flow between the annulus (between casing and wellbore) and the tubing. 5. Testing and Treatment: - With the packer set, operators can perform pressure tests, treatments, or squeeze cementing operations. - The circulating valve below the packer allows fluid flow during these operations. 6. Releasing the Packer: - To retrieve the packer, the J-slot mechanism is rotated to disengage. - The packer slips are then released, allowing for retrieval. Remember, safety protocols and proper handling are critical during all wellbore operations. 🛢️🔧 .