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

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.

Drilling Statically Underbalanced Gas Well with Managed-Pressure Drilling to Target Depth Safely and Efficiently

2013 ◽  
Author(s):  
Agustinus Krisboa ◽  
Yoshua P. Iskandar ◽  
Fikri Irawan ◽  
Ardia Karnugroho ◽  
Julmar Shaun Toralde
Keyword(s):  
Gas Well ◽  
Managed Pressure Drilling ◽  
Target Depth

Elastic Pipe Control and Compensation for Managed Pressure Drilling Under Sea Wave Heave Conditions

2015 ◽  
Vol 138 (1) ◽  
Author(s):  
Robello Samuel ◽  
Randy Lovorn
Keyword(s):  
Real Time ◽  
Wave Velocity ◽  
Pressure Profile ◽  
Accurate Method ◽  
Surface Velocity ◽  
Static State ◽  
Managed Pressure Drilling ◽  
Downhole Tool ◽  
Drag Models ◽  
Bottomhole Pressure

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)

Geomechanics in Partnership – A Holistic Approach to Solving Drilling Challenges

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

Use of glass bubbles in low-density fluids, Tambun field drilling program, Indonesia

2012 ◽  
Vol 52 (1) ◽  
pp. 253
Author(s):  
Melvin Devadass
Keyword(s):  
Risk Mitigation ◽  
Carbonate Reservoir ◽  
Drilling Fluids ◽  
Low Density ◽  
Lost Circulation ◽  
Oil Reserves ◽  
Novel Approach ◽  
Managed Pressure Drilling ◽  
Drilling Conditions ◽  
Productive Time

The Tambun Field in Indonesia was initially developed in the 1990s to exploit oil reserves from the Baturaja Formation (BRF). Since the initial drilling program, reservoir pressure in the field has steadily declined from more than 2,600 psia to less than 1,970 psia resulting in severe circulation losses and an increase in non-productive time (NPT) during drilling and completion programs. The use of hollow glass microspheres, commonly known as glass bubbles—a low density additive (LDA)—in ultra-low density drilling fluids (< 0.9 g/cc) is a novel approach in addressing this issue. A seven-well managed pressure drilling and completion exercise was undertaken by P.T. Pertamina EP Jawa region in the first half of 2010 under challenging drilling conditions in this low-pressure, high-permeability carbonate reservoir. The glass bubble mud system was selected because it would reduce or eliminate lost circulation and stuck pipe problems, reduce formation damage, eliminate the need for post drilling stimulation and give early analysis of reservoir behaviour and production rates. This paper describes the front-end engineering design, project management, risk mitigation, detailed engineering and design, operational results and lessons learnt from this project.

Managed-Pressure Cementing Implemented in an Exploratory Ultradeepwater Well

2021 ◽  
Vol 73 (05) ◽  
pp. 66-67
Author(s):  
Chris Carpenter
Keyword(s):  
Service Provider ◽  
Base Case ◽  
Pressure System ◽  
Offshore Technology ◽  
Planning And Design ◽  
Specific Objective ◽  
Managed Pressure Drilling ◽  
Zonal Isolation ◽  
Secondary Objective ◽  
Fracture Gradient

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 30481, “Successful Managed-Pressure Cementing on an Exploratory Well Operation in Ultradeep Waters of Mexico,” by Raul Bermudez, Juan Jose Ferro, and Cyril Szakolczai, Total, et al., prepared for the 2020 Offshore Technology Conference, originally scheduled to be held in Houston, 4–7 May. The paper has not been peer reviewed. Copyright 2020 Offshore Technology Conference. Reproduced by permission. The focus of the complete paper is the planning and execution of an ultradeepwater managed-pressure-cementing (MPC) job in the Gulf of Mexico. From the onset of planning, the base case was to integrate a managed-pressure system into the drilling program to mitigate predicted pore-pressure (PP) uncertainty, pressure ramp increase, and narrow PP/fracture-gradient (FG) window operations, including drilling, tripping, and running casing. Although MPC was not originally in the scope of work, it was required because of the tight drilling window and was successfully executed. Introduction The well is in Mexican waters at a depth of 10,748 ft. Given the exploratory nature of the well, a pressure ramp was predicted that would demand an excessive number of casing strings if a conventional approach were used. During the drilling phase—taking advantage of the ability to adjust the bottomhole pressure instantaneously—dynamic PP tests were performed to conclude that the expected pressure ramp was not aggressive but was leading to a narrow window that would not allow conventional cementing of the 13⅜-in. casing. Strategic planning and close collaboration between the operator’s engineering and operations teams, the cementing service provider, the managed-pressure-drilling (MPD) consultant, and the MPD service provider team was required. The uncertainty about the actual size of the hole led to an even more challenging MPC engineering analysis. The result of this cementing job was a success with no fluid losses, resulting in good zonal isolation. The specific objective for the MPC application was to set a 13⅜-in. casing to isolate the critical formation and safely continue drilling further stages of the well with an improved leakoff test at the shoe. Planning and design of the MPC application is detailed in the complete paper. This job represented the greatest water depth, and first from a drillship, for an MPC job performed by both operator and MPD service provider. In addition to performing a critical cementing operation using the managed-pressure approach, reaching well-construction objectives using MPD also was achieved while avoiding the use of a contingency liner, which saved significant expense. The base case was to integrate an MPD system into the drilling program to assist with PP uncertainty, pressure-ramp increase, and narrow PP/FG window operations, including drilling and tripping. The main objective for using the managed-pressure system during cementing was to ensure that the equivalent mud weight (EMW) at both total depth (TD) and the previous casing shoe did not fall below set limits throughout the job. The secondary objective was to reduce or eliminate losses during this process.

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

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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