Adaptive observer for kick detection and switched control for bottomhole pressure regulation and kick attenuation during managed pressure drilling

Managed pressure drilling (MPD) was developed as a group of technologies to more precisely control the annular pressure profile for which accuracy of the estimation of the bottomhole pressure is important. Particularly, under severe wave heaves in deepwater environments, the estimation based on static state pipe movement models can result in underestimation/overestimation of bottomhole pressures. The purpose of this study is to investigate the dynamic axial response of the drillstring with friction to applied heaving velocity, with particular interest to the effect at the bottomhole pressure. The paper presents an efficient and accurate method for solving the dynamic axial drillstring with friction and it allows it to be applied to heave velocity at the surface. The model that couples the pipe motion solves the full balance of mass and balance of momentum for pipe and annulus flow, considering the compressibility of the fluids, the elasticity of the system, and the dynamic motions of pipes and fluids. Also considered are surge pressures related to fluid column length below the moving pipe, compressibility of the formation, and axial elasticity of the moving string. Fluid properties are adjusted to reflect the effects of pressure and temperature on the fluids. The modeling takes into account the pipe elasticity under different combinations of heave and pipe velocities. Furthermore, the real-time torque and drag models are calibrated to actual hole conditions in real-time using survey, temperature, pressure, and downhole tool data to calculate friction factors in a wellbore. It has been observed that different conditions exist, some resulting in velocity reversal; thus causing surge or swab pressures. It has also been observed that heave amplitude has significant influence on bottomhole pressure. The different conditions observed for periodic or time function of displacements include (1) surface pipe velocity attributed to wave heave is in phase with the bottom movement of the string; (2) surface velocity of the pipe is out of phase with the bottom velocity of the pipe; (3) wave velocity and surface pipe velocity can be out of sync, and the bottom pipe velocity can be in phase with the surface velocity; and (4) wave velocity and surface pipe velocity can be out of sync, and the bottom pipe velocity can be out of phase with the surface velocity. The results of these calculations can be coupled to a real-time hydraulics model to determine a setpoint pressure for the MPD choke system. (SPE 173|005)

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Bottomhole Pressure Estimation and ℒ1 Adaptive Control in Managed Pressure Drilling System

IFAC Proceedings Volumes ◽

10.3182/20120531-2-no-4020.00039 ◽

2012 ◽

Vol 45 (8) ◽

pp. 128-133 ◽

Cited By ~ 1

Author(s):

Zhiyuan Li ◽

Naira Hovakimyan ◽

Glenn-Ole Kaasa

Keyword(s):

Adaptive Control ◽

Managed Pressure Drilling ◽

Drilling System ◽

Pressure Estimation ◽

Bottomhole Pressure

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Geomechanics in Partnership – A Holistic Approach to Solving Drilling Challenges

10.2118/206211-ms ◽

2021 ◽

Author(s):

Mohammed Omer ◽

Tosin Odunlami ◽

Carlos Iturrious

Keyword(s):

Middle East ◽

Fractured Reservoirs ◽

Holistic Approach ◽

Wellbore Stability ◽

Naturally Fractured Reservoirs ◽

Skin Damage ◽

Lost Circulation ◽

Managed Pressure Drilling ◽

Bottomhole Pressure

Abstract With rising energy demand, operators in the Middle East are now focusing on developing unconventional resources. To optimize hydraulic fracture stimulation, most of these deep gas wells are required to be drilled laterally and in the direction of the minimum horizontal stress. However, this poses an increased risk of stuck pipe due to hole instability, differential sticking and skin damage due to high overbalance pressures, which makes drilling these wells challenging and costly. Another major challenge in the Middle East is lost circulation due to natural fractures in carbonate reservoirs. Lost circulation currently accounts for loss of approximately $850-900 million USD per year globally across the industry (Marinescu 2014). This paper presents a case study where a holistic approach; combining geomechanics and drilling technologies were employed to address the drilling challenges specific to unconventional and naturally fractured reservoirs. Ultimately, this approach helped the client to mitigate stuck pipe issues, while proposing a physics/engineering-basedmethodology to reduce losses by sealing fractures, hence providing a roadmap to optimized drilling and mitigation of hazards with associated Non-Productive Time (NPT). The paper demonstrates a holistic approach, combining wellbore stability analysis, managed pressure drilling (MPD) and proposes a novel physics/engineering-based methodology for addressing lost circulation challenges. A 1-D wellbore stability model is initially developed to determine the safe operating downhole pressure limits and to effectively assess the drilling risks associated with the planned wellbore orientation. By accurately determining the required bottomhole pressure to prevent wellbore stability problems, managed pressure drilling technology can be implemented to provide improved drilling hazard mitigation by enabling reduced overbalance pressures, constant bottomhole pressure, and faster reaction time by instantaneously adjusting downhole pressures. A bi-particulate bio-degradable system is used as a lost circulation material (LCM). The bigger size cylindrical particles flowing at a pre-defined rate will form a bridge or a plug across the fracture aperture, providing mechanical stability and the smaller spherical particles will seal the gaps in the bridge there by providing an effective sealing of the fracture opening. From experience, implementing these methodologies and technologies in isolation has not provided satisfactory results. This indicates that a partnership which leverages the strengths of the individual disciplines from the early planning stages is necessary to effectively address the drilling challenges posed by unconventional and naturally fractured reservoirs. For the case study highlighted in this paper, the well was drilled to TD in a timely manner, while maintaining the integrity of the hole, hence confirming the viability of this approach. In addition, the physics and engineering design workflow for bi-particulate bio-degradable LCM demonstrates how it can be effectively deployed to mitigate lost circulation without skin damage to the formation

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Adaptive observer-based switched control for electropneumatic clutch actuator with position sensor

IFAC Proceedings Volumes ◽

10.3182/20110828-6-it-1002.00019 ◽

2011 ◽

Vol 44 (1) ◽

pp. 4791-4796 ◽

Cited By ~ 3

Author(s):

Hege Langjord ◽

Glenn-Ole Kaasa ◽

Tor Arne Johansen

Keyword(s):

Adaptive Observer ◽

Position Sensor ◽

Switched Control

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Design and Experimental Validation of Nonlinear Infinite-Dimensional Adaptive Observer in Automated Managed Pressure Drilling

Journal of Dynamic Systems Measurement and Control ◽

10.1115/1.4036553 ◽

2017 ◽

Vol 139 (11) ◽

Cited By ~ 6

Author(s):

Agus Hasan ◽

Lars Imsland ◽

Espen Hauge

Keyword(s):

Flow Rate ◽

Drilling Fluid ◽

Drill String ◽

Adaptive Observer ◽

Well Control ◽

Infinite Dimensional ◽

Parameter Estimations ◽

Managed Pressure Drilling ◽

Process Measurements ◽

Available Information

Utilizing flow rate and pressure data in and out of the fluid circulation loop provides a driller with real-time trends for early detection of well-control problems that impact the drilling efficiency. Due to limited number of sensors and time delay in processing and measurements, the flow rate and pressure along the annulus and drill string need to be estimated. This paper presents state and parameter estimations for infinite-dimensional models used in automated managed pressure drilling (MPD). The objective is to monitor the key process variables associated with process safety by designing a nonlinear adaptive observer that use the available information coming from the continuous-time online process measurements at the outlet of the well. The adaptive observer consists of a copy of the infinite-dimensional model plus output injection terms where the gain is computed analytically in terms of the Bessel function of the first kind. The design is tested using field data from a drilling commissioning test by Statoil ASA, Stavanger, Norway. The results show that the nonlinear adaptive observer estimates the flow rate and pressure of the drilling fluid accurately.

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Successful Implementation of Managed Pressure Drilling and Managed Pressure Cementing Techniques in Fractured Carbonate Formation Prone to Total Lost Circulation in Far North Region

10.2118/208508-ms ◽

2021 ◽

Author(s):

Zhanna Kazakbayeva ◽

Almas Kaidarov ◽

Andrey Magda ◽

Fuad Aliyev ◽

Harshad Patil ◽

...

Keyword(s):

Real Time ◽

Successful Implementation ◽

Integrity Test ◽

Lost Circulation ◽

Far North ◽

Carbonate Formation ◽

Managed Pressure Drilling ◽

Geological Conditions ◽

Minor Losses ◽

Bottomhole Pressure

Abstract Drilling reservoir section in the oilfield located in Far North region is challenged with high risks of mud losses ranging from relatively minor losses to severe lost circulation. Numerous attempts to cure losses with traditional methods have been inefficient and unsuccessful. This paper describes implementation of Managed Pressure Drilling (MPD) and Managed Pressure Cementing (MPC) techniques to drill 6-1/8″ hole section, run and cement 5″ liner managing bottomhole pressure and overcoming wellbore construction challenges. Application of MPD technique enabled drilling 6-1/8″ hole section with statically underbalanced mud holding constant bottom hole pressure both in static and dynamic conditions. The drilling window uncertainty made it difficult to plan for the correct mud weight (MW) to drill the section. The MW and MPD design were chosen after risk assessment and based on the decisions from drilling operator. Coriolis flowmeter proved to be essential in deciphering minor losses and allowed quick response to changing conditions. Upon reaching target depth, the well was displaced to heavier mud in MPD mode prior to open hole logging and MPC. MPD techniques allowed the client to drill thru fractured formation without losses or gains in just a couple of days as compared to the months of drilling time the wells usually took to mitigate wellbore problems, such as total losses, kicks, differential sticking, etc. This job helped the client to save time and reduce well construction costs while optimizing drilling performance. Conventional cementing was not feasible in previous wells because of risks of losses, which were eliminated with MPC technique: bottomhole pressure (BHP) was kept below expected loss zones that provided necessary height of cement and a good barrier required to complete and produce the well. Successful zonal isolation applying MPC technique was confirmed by cement bond log and casing integrity test. Throughout the project, real-time data transmission was available to the client and engineering support team in town. This provided pro-active monitoring and real-time process optimization in response to wellbore changes. MPD techniques helped the client to drill the well in record time with the lowest possible mud weight consequently reducing mud requirements. The MPD system allowed obtaining pertinent reservoir data, such as pore pressure and fracture pressure gradients in uncertain geological conditions.

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Drilling the Point Pleasant-Utica Shale Fractured Formation During the COVID-19 Pandemic Utilizing CBHP MPD with a PMCD Contingency

10.2118/208436-ms ◽

2021 ◽

Author(s):

Sagar Nauduri ◽

Ahmed Shimi ◽

Gildas Guefack ◽

Martyn Parker

Keyword(s):

Safety Culture ◽

Service Provider ◽

Loss Mitigation ◽

Utica Shale ◽

Physical Conditions ◽

Managed Pressure Drilling ◽

Productive Time ◽

Target Depth ◽

Bottomhole Pressure ◽

Significant Factors

Abstract Drilling the Point Pleasant-Utica formation in the Appalachian Basin has posed challenges to most operators, especially in Western Pennsylvania. A recent well drilled in this region demonstrated that with proper buy-in from the Operator, Constant Bottomhole Pressure (CBHP) Managed Pressure Drilling (MPD) could be the answer when planned and executed correctly. This paper drives the point that MPD is more than simply dropping chokes on location. Prior to drilling the well, the Operator initiated the communication very early with the MPD service provider and created an avenue to reduce the projected mud weight and develop a detailed CBHP MPD plan with a Pressurized Mudcap Drilling (PMCD) contingency. The anticipated challenges on this well were: High-pressure gas fractures, formation instability/shale breakout, severe/total loss of returns, inability to reach Target Depth, and casing/cementing issues. The Operator took time and worked with the new MPD service provider to carefully design and plan a new well (referred to as ‘Y1’ in this document), which helped execute the MPD part of the project within 30 days. In contrast, the MPD execution on a previous well (referred to as ‘X2’ in this document) with the older MPD service provider took more than 90 days. MPD execution on the new MPD well included dynamic influx management and loss mitigation, and understanding of the petro-physical conditions to reach the target. The significant factors that helped drill this well safely with a low Non-Productive Time (NPT) are excellent safety culture, communication, high quality and well-maintained MPD equipment, and a very knowledgeable and highly experienced MPD team. This project was finished within half of the budgeted Authorization for Expenditure (AFE), setting milestones in this region for this Operator.

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