Kick detection and well control in a closed wellbore

2011 ◽  
Vol 51 (1) ◽  
pp. 109 ◽  
Author(s):  
Steve Nas
Keyword(s):  
Control Process ◽  
Pressure Control ◽  
Control Device ◽  
Primary Objective ◽  
Pressure Management ◽  
Well Control ◽  
Managed Pressure Drilling ◽  
Drilling Operations ◽  
Control Procedures ◽  
Additional Level

Closing the wellbore at the top with a rotating control device (RCD) for some kinds of managed pressure drilling (MPD) operations raises a number of issues with regards to well control and kick detection. The wellbore is closed and the standard flow check of looking into the well is no longer possible. The use of a RCD provides drillers with an additional level of comfort because it is a pressure management device, but it doesn’t eliminate the need to have well control as a primary objective. In recent MPD operations, it has already been observed that well control procedures are relaxed as a result of managed pressure drilling. Is managed pressure drilling the same as primary well control, and how do we deal with kicks in managed pressure drilling operations? At what point in a well control process do we hand over from MPD to drillers’ well control, and who is responsible? This paper will present some of the issues that need to be considered when planning and conducting MPD operations. Early kick detection and annular pressure control are promoted as an essential part of MPD operations, but there can be confusion as to where the responsibility for well control lies. Does the responsibility remain with the drilling contractor and operator or with the provider of the MPD services. The paper provides some case studies where MPD and well control conflicted, causing a number of issues that in some cases led to the loss of wells.

Riser gas risk mitigation with advanced flow detection and managed pressure drilling technologies in deepwater operations in Australia

2014 ◽  
Vol 54 (1) ◽  
pp. 23
Author(s):  
Julmar Shaun Sadicon Toralde ◽  
Chad Henry Wuest ◽  
Robert DeGasperis
Keyword(s):  
Risk Mitigation ◽  
Control Device ◽  
Asia Pacific ◽  
Well Control ◽  
Alternative Approach ◽  
Managed Pressure Drilling ◽  
Drilling Operations ◽  
Drilling System ◽  
Flow Detection ◽  
And Control

The threat of riser gas in deepwater drilling operations is real. Studies show that gas kicks unintentionally entrained in oil-based mud in deepwater are unlikely to break out of solution until they are above the subsea blowout preventers (BOPs). The rig diverter is conventionally used to vent riser gas with minimal control and considerable risk and environmental impact involved. Reactive riser gas systems provide a riser gas handling (RGH) joint that is composed of a retrofitted annular BOP and a flow spool with hoses installed on top of the rig marine riser. A proactive, alternative approach to riser gas handling, called riser gas risk mitigation, is proposed by using managed pressure drilling (MPD) equipment. MPD involves the use of a rotating control device (RCD) to create a closed and pressurisable drilling system where flow out of the well is diverted to an automated MPD choke manifold with a high-resolution mass flow meter that increases the sensitivity and reaction time of the system to kicks, losses and other unwanted drilling events. Experiments and field deployments have shown that the deepwater MPD system can detect a gas influx before it dissolves in oil-based mud, allowing for management of the same using conventional well control methods. Since the MPD system has already closed the well in, automatic diversion and control of gas in the riser is also possible, if required. This paper presents experience gained from deepwater MPD operations in the Asia-Pacific to illustrate this, and possible deployment options in Australia are discussed.

Accurate Pressure Management of Parallel Choke Manifold

2013 ◽  
Vol 325-326 ◽  
pp. 1241-1244
Author(s):  
Zhong Xi Zhu ◽  
Ying Biao Liu ◽  
Zhao Fei Wang
Keyword(s):  
Laboratory Tests ◽  
Nonlinear Characteristic ◽  
Pressure Management ◽  
Pressure System ◽  
Well Control ◽  
Managed Pressure Drilling ◽  
Manifold System

The conventional valves used in the choke manifold for well control usually have intensely nonlinear characteristic of the match between pressure choking and vale opening. Therefore, it is difficult to achieve the precise choking pressure that is essential to the managed pressure drilling (MPD) through a single throttle within the scope of full opening. However, the parallel choke manifold proposed in this paper, i.e. a program of parallel throttling, can enhance the accurate choking wellhead backpressure for MPD. The fine linear choking principle and feasibility of the parallel choke manifold were analyzed in detail by calculating the resistance modulus of bypass valves. The formula calculated the resistance modulus of each valve under different working state. Furthermore, the laboratory tests shown the parallel throttle method can achieve the control of fine choking pressure by switching one or more valves in the branch pipes. Therefore, the proposed parallel choke manifold system can reduce the requirements for the linear capability of valves and provide some references to further study the surface fine choking pressure system for MPD.

Nitrogen-Based Back Pressure Unit Modernizes Managed Pressure Drilling Operations

2021 ◽  
Author(s):  
Wamidh Louayd Al-Hashmy
Keyword(s):  
Drilling Fluid ◽  
Pressure Control ◽  
Drill String ◽  
Back Pressure ◽  
Managed Pressure Drilling ◽  
Core Function ◽  
Wellbore Pressure ◽  
Drilling Operations ◽  
Pressure Unit ◽  
Static Conditions

Abstract Managed Pressure Drilling (MPD) solutions are no longer the anomaly to Operator strategies, but rather another tool in their belts. With this continual utilization, MPD is evolving to become compact, more effective and safer. The inventive use of a Nitrogen Backup Unit (NBU) has eliminated the reliance of MPD operations on sizable Auxiliary Pumps. The core function of MPD operations is maintaining the total wellbore pressure by manipulating surface applied back pressure. MPD relies on circulating fluid as back pressure is generated by restricting flow against its choke(s). While drilling, fluid circulation is a given; however, that is not the case during static conditions such as drill string connections. The NBU solves this issue by injecting a small volume of nitrogen into the MPD lines upstream of the choke at a pre-set pressure. This supplements the back pressure control at surface should additional pressure be needed after closing the choke or if pressure diminishes during long static periods. Prior to the NBU design, the only effective solution was an Auxiliary Pump setup. This solution doubles the choke manifold footprint, relies on mechanical maintenance, and requires additional dedicated personnel at times. Most critically, the Auxiliary Pump lags the operation minutes before each use and is therefore functioned before static conditions when possible. However, unplanned and sudden events are commonplace – such as Rig Pump failures. When drilling formations with narrow pressure margins, unsafe gases, or crucial hole instability pressure limits, a few minutes can result in considerable and costly outcomes. Once installed during initial rig-up, the NBU is capable of injecting nitrogen-sourced back pressure instantaneously at the literal click of a button – avoiding costly and sometimes hazardous conditions. The NBU modernizes MPD operations and renders the Auxiliary Pump setup outdated in many applications. This paper details this innovative implementation of maintaining wellbore pressure, highlights several field examples of the NBU maintaining back pressure at critical times and shows how the layout used minimizes the operational footprint.

The Integration of Managed Pressure Drilling MPD and Automated Well Control Technology

2021 ◽  
Author(s):  
Bryan Wade Atchison ◽  
Chad Wuest
Keyword(s):  
Control System ◽  
Pressure Control ◽  
Integrated System ◽  
Control Technology ◽  
Fully Integrated ◽  
Well Control ◽  
Managed Pressure Drilling ◽  
Blowout Preventer ◽  
Smart Technologies ◽  
Real Time Information

Abstract Digitalisation and automation can account for massive efficiencies in wells operations. Managed Pressure Drilling (MPD) and Automated Well Control are examples of "smart" technologies that can mitigate risks and costs associated with drilling wells. The Automated Well Control system was developed to monitor the well, identify an influx, take control of the rig equipment and shut in the well. MPD provides annular pressure control, real-time information of the well parameters and conditions downhole and very accurate and immediate influx detection. However, if a high intensity influx is taken that exceeds the pre-planned operational limits of the MPD package, then secondary well control is required. Therefore, a combination of Automated Well Control and MPD has been developed to deliver both pressure control and well control in a safe, efficient and less error-prone manner. On an MPD operation, the Automated Well Control system shuts-in the well as soon as it is required to do so. With Automated Well Control in MPD mode, the MPD system decides when to shut in and the Automated Well Control technology will immediately space out, stop the mud pumps and top-drive, and shut in the well using the pre-selected blowout preventer. This interface between the two systems mitigates drilling hazards using automation. The sensitivity of MPD, combined with Automated Well Control technology enables fast identification, decision making and reaction to well control events. Consequently, this fully integrated solution improves safety and operational efficiency. The MPD and Automated Well Control systems were integrated into a test rig and several tests were efficiently performed. The tool enabled immediate action in the event of influxes, providing a valuable solution for the industry. This paper briefly describes MPD and Automated Well Control and summarises the interface between the two technologies, detailing how the integrated system works on a rig. Moreover, rig trialling results and further developments are presented.

Kick Management Study on Automated Well Control for Managed Pressure Drilling in Long Wells

2018 ◽  
Author(s):  
Amare Leulseged ◽  
Sima A. Nepal ◽  
Dan Sui ◽  
Suranga C. H. Geekiyanage
Keyword(s):  
Surface Pressure ◽  
Flow Model ◽  
Transient Flow ◽  
Pressure Profile ◽  
Pressure Control ◽  
Control Procedure ◽  
Well Control ◽  
Managed Pressure Drilling ◽  
Drilling Technology ◽  
Advanced Drilling

In drilling operations, the downhole pressure (BHP) requires to be closely monitored and precisely managed to avoid potential drilling events harmful to personnel and environment. If the BHP is lower than the pore pressure, kick (amount of influx) from formation will enter the wellbore, which might result in (underground) blowout. If not properly managed, this could be more costly than surface blowouts [1]. Well control aims to stop and remove the influx and re-establish primary barriers. Managed Pressure Drilling (MPD) is an advanced drilling technology capable of precisely controlling annular pressure profile throughout the wellbore. In this study, a high fidelity transient flow model is used for simulating dynamic well control procedure in MPD to properly manage annular pressure during kick circulation after the kick is detected. In this work, an automated well control in MPD is simulated, where PID control algorithm is implemented by manipulating choke valve opening to dynamically regulate the BHP during kick circulation. The main aim is to investigate dynamic kick management with the use of different type of muds, water based mud (WBM) and oil based mud (OBM). For different mud systems, the well control performances for long extended reach wells are evaluated and compared. From simulations, it shows that the OBM is able to hide the influx to a large extent, than the WBM due to the much higher gas solubility of the OBM. In HPHT wells, the OBM is superior to the WBM with proper automatic surface pressure control in MPD operations. Using complicated dynamic flow model can provide more precisely surface pressure control for realtime dynamic kick management.

Multi-Phase Well Control Analysis During Managed Pressure Drilling Operations

2016 ◽  
Author(s):  
Z. Ma ◽  
A. Karimi Vajargah ◽  
A. Ambrus ◽  
P. Ashok ◽  
D. Chen ◽  
...  
Keyword(s):  
Control Analysis ◽  
Well Control ◽  
Managed Pressure Drilling ◽  
Drilling Operations ◽  
Multi Phase
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