The Experts below are selected from a list of 240 Experts worldwide ranked by ideXlab platform
David Reed - One of the best experts on this subject based on the ideXlab platform.
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Shallow geohazard risk mitigation: A Drilling Contractor's perspective
Journal of Petroleum Technology, 2003Co-Authors: David ReedAbstract:Introduction of the Offshore Installations Regulations 1992 and the Offshore Installations and Wells Regulations 1996 to offshore operations in the U.K North Sea require risks related to Drilling wells be kept as low as reasonably practicable (ALARP). The responsibility of the rig owner is to identify safety-critical elements associated with the rig and ensure that these risks are maintained to within ALARP principles. Additionally, the rig owner is responsible for well-related safety-critical elements. The full-length paper details how a Drilling Contractor has implemented a shallow geohazard review process to mitigate shallow geohazard risks.
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Shallow Geohazard Risk Mitigation; A Drilling Contractor's Perspective
All Days, 2002Co-Authors: David ReedAbstract:Abstract The introduction of the Offshore Installations (Safety Case) Regulations 1992 and the Offshore Installations and Wells (Design and Construction, etc) Regulations 1996 to offshore operations in the UK North Sea require risks related to the Drilling of wells to be kept As Low As Reasonably Practicable (ALARP). The responsibility of the rig owner in this regime is to identify safety critical elements associated with the rig and ensure that these risks are maintained to within ALARP principles. This responsibility also recognises that wellbores attached to the rig may also present a threat to the installation and those onboard. Additionally, the rig owner must take into account well-related safety critical elements. By using examples, this paper examines why and how a Drilling Contractor has implemented a Shallow Geohazard Review process in order to mitigate shallow geohazard risks. This paper reviews the operator - geotechnical Contractor relationship and identifies where Drilling Contractor involvement has strengthened the risk analysis process. Finally, this paper summarises the positive outcomes of this process as well as challenges the Drilling and geotechnical Contractors to bridge the information gap. Introduction Geohazards encountered whilst Drilling top-hole sections of a wellbore are varied and may include, shallow gas, shallow water flows, gas hydrates, mud volcanoes, faulting, and boulders. Although this paper relates to shallow gas geohazards, it could be equally applicable to other shallow geohazards, which may induce uncontrolled well flow. Due to their shallow nature and limited formation strength, those top-hole shallow events, that can cause the well to flow, cannot be closed in and killed by normal circulation methods. The options for maintaining well control once a flow occurs are restricted (during both riserless Drilling and Drilling with a riser plus diverter system.) Immediately the rig is in a condition of emergency. Therefore, shallow geohazards can present some of the most hazardous situations to a mobile Drilling rig. One solution to avert such situations is to identify and avoid shallow geohazards of whatever nature wherever practical. During August 2000, two Santa Fe rigs experienced uncontrolled shallow gas blowouts, which had the potential for serious rig and personnel damage. In both cases, no one was injured and the rigs concerned did not sustain damage. Both blowouts occurred from jack-up Drilling units whilst undertaking riserless operations in geographically diverse regions. The incidents were reviewed externally by the operator and internally within Santa Fe. The first incident occurred in the North Sea whilst Drilling 26" size hole, with return to seabed. The first indication of the event was the observation of a plume in the sea around the rig. The visual estimation was an ariel extent of 500 m around the rig. After the initial high volume escape of gas, the well continued to percolate gas at an intermittent rate until after cement was pumped. There was also evidence of breaching away from the wellbore though at no time did this affect the stability of the legs. The rig was moved off location after the initial blowout. A high-resolution survey was undertaken of the area. A considerable period of time elapsed before the rig could be moved back to a shallow gas-free location nearby. The second incident occurred in the Gulf of Thailand whilst Drilling in the 9 5/8" conductor casing. A shallow gas flow was encountered at 803' MDBRT. The flow was stopped within one hour with kill weight mud and plugged two days later after pumping cement. The well was abandoned by cutting the casing below seabed and setting further cement plugs. The reviews covered all aspects of well design and Drilling operations and the conclusions were similar.
Mutsuo Fukushima - One of the best experts on this subject based on the ideXlab platform.
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Challenges of an offshore Drilling Contractor-Requirements and responses-
Journal of the Japanese Association for Petroleum Technology, 2007Co-Authors: Mutsuo FukushimaAbstract:Recent heavy rise in oil price had impacted oil companies of the world. Then afterward, they expanded and influenced service businesses and service Contractors, such as offshore Drilling Contractors, living among the oil companies.Japan Drilling Company, JDC, as one of the offshore Drilling Contractors, also experienced recent abrupt changes of business environment. Although the environment is generally recognized favorable for them, it also forces them significant challenges and risks. Their severe battle for survival in such cyclical market can be seen now.In this paper, brief descriptions of the recent offshore Drilling and rig market are presented, then, as an example, JDC's situations and strategies in such market environment are explained.
Iversen Alexander - One of the best experts on this subject based on the ideXlab platform.
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Identifying and evaluating high risk areas and challenges on marine Drilling riser system in relation to deepwater problems
University of Stavanger Norway, 2012Co-Authors: Iversen AlexanderAbstract:Master's thesis in Offshore technologyThe main concerns during Drilling operations are riser integrity and maintaining well control. This thesis has mainly been focusing on the problems and challenges faced with the marine riser system to illuminate high risk areas related to riser integrity. A marine riser system consists generally of four main elements; the upper marine riser package, riser joints, lower marine riser package, and the blowout preventer, each playing an important part in the marine riser system. The marine riser function is to supports and guide the auxiliary lines used to control the well, and connect and provide for fluid communication between the Drilling vessel and the wellhead. Failure to the marine riser is related to technical problems associated with old design and lack of correct operating procedure and maintenance method. Elements like the telescopic joint haven’t change the design since the 1960’s and are exposed to problems like unplanned discharge caused of premature war to the packer element. Problems with the telescopic joint are not unique there are also experienced failure with tensioner system, flex joint and blowout preventer. Studies show that blowout preventer failure cases the longest downtime and most expensive repairs. Over 50% of blowout preventer failures are related to the control system and are caused by failure to the hydraulic components. Exploration activity forces the Drilling Contractor further out and into deeper water depths, like the Gulf of Mexico or outside the Coast of Brazil. Greater water depths challenge the riser system on many places. Deepwater operations means harsher environment and problems in the forms of large waves, strong currents and increased pressure from the water column, all affecting the operations and riser pipe in several ways. The environmental issues causes the riser to fail due to increased tensile load, vortex induced vibrations, environmentally induced cracks and increased corrosion attacks. The increased tensile load on the riser pipe place importance on the top tension capacity of the rig and the riser pipe wall thickness. Moving into deeper ground, many rigs reach their tension capacity and must use buoyancy modules to provide sufficient tension to the riser. Many of the problems could be addressed using simple solution, like implementing correct maintenance program or address the issues in the design phase. But economical impetus holds the development back. Solutions like redesign of the telescopic joint and blowout preventer is advised by operators, but some of the solution are proven to be economical unprofitable
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Identifying and evaluating high risk areas and challenges on marine Drilling riser system in relation to deepwater problems
University of Stavanger Norway, 2012Co-Authors: Iversen AlexanderAbstract:The main concerns during Drilling operations are riser integrity and maintaining well control. This thesis has mainly been focusing on the problems and challenges faced with the marine riser system to illuminate high risk areas related to riser integrity. A marine riser system consists generally of four main elements; the upper marine riser package, riser joints, lower marine riser package, and the blowout preventer, each playing an important part in the marine riser system. The marine riser function is to supports and guide the auxiliary lines used to control the well, and connect and provide for fluid communication between the Drilling vessel and the wellhead. Failure to the marine riser is related to technical problems associated with old design and lack of correct operating procedure and maintenance method. Elements like the telescopic joint haven’t change the design since the 1960’s and are exposed to problems like unplanned discharge caused of premature war to the packer element. Problems with the telescopic joint are not unique there are also experienced failure with tensioner system, flex joint and blowout preventer. Studies show that blowout preventer failure cases the longest downtime and most expensive repairs. Over 50% of blowout preventer failures are related to the control system and are caused by failure to the hydraulic components. Exploration activity forces the Drilling Contractor further out and into deeper water depths, like the Gulf of Mexico or outside the Coast of Brazil. Greater water depths challenge the riser system on many places. Deepwater operations means harsher environment and problems in the forms of large waves, strong currents and increased pressure from the water column, all affecting the operations and riser pipe in several ways. The environmental issues causes the riser to fail due to increased tensile load, vortex induced vibrations, environmentally induced cracks and increased corrosion attacks. The increased tensile load on the riser pipe place importance on the top tension capacity of the rig and the riser pipe wall thickness. Moving into deeper ground, many rigs reach their tension capacity and must use buoyancy modules to provide sufficient tension to the riser. Many of the problems could be addressed using simple solution, like implementing correct maintenance program or address the issues in the design phase. But economical impetus holds the development back. Solutions like redesign of the telescopic joint and blowout preventer is advised by operators, but some of the solution are proven to be economical unprofitable
Adam Wilson - One of the best experts on this subject based on the ideXlab platform.
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Use of Managed-Pressure Drilling Requires Adjustments To Bridge Gap to Well Control
Journal of Petroleum Technology, 2018Co-Authors: Adam WilsonAbstract:This article, written by Special Publications Editor Adam Wilson, contains highlights of paper IADC/SPE 178810, “Bridging the Gap Between MPD and Well Control,” by Thiago Pinheiro da Silva, Landon Hollman, SPE, Gustavo Puerto Corredor, and Patrick Brand, SPE, Blade Energy Partners, prepared for the 2016 IADC/SPE Drilling Conference and Exhibition, Fort Worth, Texas, USA, 1–3 March. The paper has not been peer reviewed. Managed-pressure Drilling (MPD) challenges the conventional Drilling paradigm, along with Drilling-Contractor and operator policies and standards. Conventional Drilling practices for connections, flow checks, tripping, and well control have been long understood and standardized both onshore and offshore. The addition of an MPD system to a Drilling operation, inclusive of the recommended practices, requires bridging the gap between conventional policies and standards and those of MPD. Introduction Often, an MPD bridging document that supplements the standard Drilling-Contractor and operator bridging document is seen as an operational requirement. The Drilling Contractor remains responsible for well control and well monitoring. The driller will continue to monitor the well at all times, using standard operating procedures while observing key Drilling parameters. The MPD system provides enhanced well-control-event-detection methods in addition to standard downhole-event-detection methods. In addition, it allows rapid and accurate control of bottomhole pressure (BHP), but it does not replace standard Drilling-Contractor or operator procedures during well-control events. Depending on the MPD-system avail-ability and capabilities and the actual well conditions, most operators use several MPD techniques on the same well. The techniques may include conventional Drilling with riser-gas-handling capabilities, dual-gradient dynamic-mud-cap Drilling, pressurized-mud-cap Drilling, floating-mud-cap Drilling, or applied-surface-backpressure MPD. All of these fall into the group of techniques now referred to in the industry as MPD. Depending on the technique used, the mud density might be statically overbalanced, meaning that the hydrostatic pressure alone exceeds the highest formation pore pressure exposed, or it might be statically underbalanced, meaning that hydrostatic pressure alone may be less than the highest formation pore pressure exposed and the well is kept overbalanced by applying backpressure at surface. Well-established corporate policies have guided conventional Drilling practices with respect to operational issues such as kick-indicator response, frequency of equipment testing, fingerprinting, and proactive kick-minimization techniques. Although MPD serves the same purpose as conventional Drilling—to drill a section safely overbalanced—its use requires procedures that deviate from established policies. Barriers Conventional Drilling. For conventional Drilling techniques, a minimum of two independent and tested barriers must be in place at all times. Upon failure of a barrier, normal operations must cease and not resume until a two-barrier position has been restored.
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Collaborative Approach to Implementation Helps Realize Benefits of Drilling Automation
Journal of Petroleum Technology, 2017Co-Authors: Adam WilsonAbstract:This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 184695, “Development to Delivery—A Collaborative Approach to Implementing Drilling Automation,” by Riaz Israel, SPE, Julian Farthing, SPE, and Hamish Walker, BP; Rodrigo Gallo Covarrubias and Jason Bryant, Schlumberger; and Christian Vahle, KCA Deutag Drilling, prepared for the 2017 SPE/IADC Drilling Conference and Exhibition, The Hague, 14–16 March. The paper has not been peer reviewed. The application of automated technologies to the process of well construction is emerging as key to improving the overall efficiency of Drilling performance. Though not yet mainstream, several recent applications have demonstrated that technology maturity is no longer the limiting factor in accelerating implementation and realizing the benefits of automation. This paper describes a collaborative effort between an operator, a Drilling Contractor, and a service company to introduce specific aspects of automated technology to a major Drilling operation. Project Context and Technology Business Drivers In 2012, the company began developing a giant gas greenfield that required nearly 300 wells to be drilled. Among the many challenges on a project of this magnitude was the need to drive well-construction costs down. An important aspect of well-construction cost is the time spent Drilling, which is largely influenced by the slow rate of penetration (ROP) prevalent in the field because of the high rock strength. In order to deliver the performance enhancements required, the company set up an integrated hard-rock Drilling team. In addition to the objective of increasing ROP, several other aspects of the technology made it attractive. These include that Automation presents a systematic approach to improve consistency of performance across multiple rigs and wells. Automation can supplement the competency and capacity of drillers. Automation Project Goals In early 2014, the company agreed on a plan to bring this technology to the field in collaboration with the project’s major Drilling Contractor and Drilling service provider (DSP), the supplier of the Drilling automation technology. Additionally, because the Drilling rig was recognized as a major component of the technology delivery, the company engaged in focused discussions to build alignment with the main Drilling Contractor to ensure that the right resources were available throughout the project. Finally, the DSP and the Drilling Contractor implemented a bilateral agreement that covered the scope of work and protected each party’s contribution to the project. With all this in place, the project deliverables were defined as follows: Complete three open-loop field trials of the DSP’s ROP-optimization software, and evaluate the opportunities and areas for improvement. Design, build, and test an interface between the DSP’s automation system and the Drilling Contractor’s Drilling control system. Install the DSP’s Drilling automation systems and interface with operator-designated Drilling rigs. Complete three closed-loop field trials of the DSP’s Drilling automation systems, and evaluate the opportunities and areas for improvement.
Judy Feder - One of the best experts on this subject based on the ideXlab platform.
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Real-Time Analytics Improves Process Safety in a Drilling-Contractor Operations Center
Journal of Petroleum Technology, 2019Co-Authors: Judy FederAbstract:This article, written by JPT Technology Editor Judy Feder, contains highlights of paper OTC 28824, “Operational and Safety Improvements of Applying Real-Time Analytics in a Drilling-Contractor RTOC,” by A.L.F. Madaleno, S.L.S. Neto, L.A. dos Santos, and C.A.L. de Oliveira, QGOG Constellation, prepared for the 2018 Offshore Technology Conference, Houston, 30 April–3 May. The paper has not been peer reviewed. Copyright 2018 Offshore Technology Conference. Reproduced by permission. Digitally enabled collaboration between operators and service companies is driving significant improvements in process safety in the upstream oil and gas industry. However, Drilling Contractors generally have been considered only the owners of the systems that generate part of the surface Drilling data and, as such, have not been engaged in the development of real-time analytics tools. The role of a real-time operations center (RTOC) with a Drilling Contractor is itself a new factor. This paper explains how an ultradeepwater Drilling Contractor is applying real-time analytics and machine learning to leverage its RTOC to improve process safety and performance. Introduction The increasing availability of digital Drilling data and the emergence of reliable communication between offshore rigs and well operators’ offices enabled a proliferation of RTOCs in the 2000s, spawning a collaborative environment between well operators and service companies that enabled enhanced support and optimized use of expert resources to improve process safety and operational efficiency. Drilling Contractors generally were not engaged in developing the real-time analytics tools for the RTOCs. One consequence is that the majority of RTOC software solutions are only appropriate for wellsite information transfer standard markup language (WITSML) data visualization, or they feature embedded tools for well operators and service companies focused on Drilling efficiencies but the data and models they use are not accessible to the rig operators. Essential aspects of process safety and operational performance, such as procedural discipline and critical equipment health, can be addressed by Drilling Contractors in real time if appropriate resources are in place. The Contractor’s RTOC has enhanced process safety and surveillance after moving to an approach in which Drilling engineers, assisted by software developers with robust experience in real-time data analytics, began writing automated operation-identification and problem-detection algorithms. The cooperative work allowed the creation of tools adapted to the company’s needs and provided a streamlined process to implement, customize, and repair these tools over time. During the planning phase, it was agreed that initial developments should be grouped into six important dimensions that strongly influence the overall process safety and operational performance of the rig. The Contractor applied real-time analytics and machine learning to identify and alert RTOC engineers of abnormal situations automatically. The detection of the abnormal situations by RTOC engineers and the comparison of the standard by which various Drilling crews react to them feeds a lessons-learned data base, which, in turn, sustains the procedural advancement initiatives, ensuring continuous improvement.
