There is a need in the industry to advance the technology in underreaming, specifically in operations where simultaneous drilling and underreaming take place. Underreaming hurdles have existed for several years that could not be overcome by a simple reliable mechanical apparatus to activate or deactivate the tools. Activating a tool on demand offers options and underreaming techniques that can enhance the way wells are drilled. Traditional underreamers are activated or deactivated by dropping a steel ball to the tool via the drillstring. The dropped ball creates a bore restriction in the underreamer, which only allows drilling fluid to pass. RFID (Radio Frequency Identification) activation offers several key advantages; it creates an option to increase the performance of the underreamer by allowing multiple activation or deactivation without restricting the ID of the tool. The operator may elect to underream only specific sections of the well where swelling formations cause stuck drillstrings, or allow full circulation in deactivated mode to clean out sections of the wellbore. RFID tools have a full bore which enables wireline to be run through the reamer. RFID allows for multiple tools to be run in the drill string and activated or deactivated on demand. Activation is controlled by pumping small tags through the bore of the tool. RFID tags transmit commands to the underreamer as they pass through the tool; an electronic reader embedded in the tool reads the command. All commands and other RFID controller events are stored into memory and may be downloaded after the job is complete. This paper discusses the benefits and value of RFID activated underreamers. The lab and field test results of the RFID controlled underreamer will be presented.
This paper describes the application of casing drilling technique for the top hole section in conductor sharing wells in a brown field, offshore Malaysia. Its objective is to describe the integration of the casing drilling technique and the conductor sharing design when used in conjunction. It is intended to share the challenges faced during the design and execution phases of the project, the solutions analyzed and applied; as well as the outcome and learnings. In this case study, the conductor sharing design makes it possible to maximize the well capacity of the offshore drilling platforms by accommodating multiple wells per drilling slot. The casing drilling technique is implemented to manage drilling risks related to wellbore stability, losses and shallow gas. The feasibility for combining the two technologies is evaluated during the planning stage by reviewing the documented previous industry experience of the two technologies, combined or separate; while local knowledge is analyzed to ensure all drilling factors are considered. Solutions to challenges such as wells interface inside the shared conductor, directional control, losses, cement design and placement techniques, well control, operational procedures and time and cost efficiency are analyzed. The execution results are analyzed by comparing design estimations and assumptions with field data and actual results. These data is translated then into recommendations and lessons learnt. The conclusions of this case study are presented as a set of design work, drilling practices and risk analyses processes and their results that can be replicated or considered in future wells design where conductor sharing and casing drilling are to be implemented together. While several individual studies of particular conductor sharing wells configurations, casing drilling and well construction techniques are available, the present work discusses one of the few applications to date where conductor sharing and directional casing drilling technologies are combined to address specific offshore challenges. The team considers of paramount importance that the knowledge obtained on this very specific combination of two technologies is documented and shared within industry professionals to provide reference for future applications.
A Brown field, offshore Malaysia, has been in production for over 30 years. The Brown field has low rock strength in shallow reservoirs, while the deeper reservoirs consist of stronger and stiffer formations. As a result, the completion for shallow reservoirs requires gravel pack treatment, whereas the deeper reservoirs can be completed without particular requirements of sand control.Big hole charges followed by mechanical surge are the preferred perforating technique for an optimum gravel pack. For consolidated formations, deep penetration charges, with a dynamic underbalance, are more suitable to maximize inflow. Historically, multi-zone completions in field wells are performed in stages: the deeper zone is perforated and conditioned first; followed by the upper interval, which is perforated, gravel packed, completed and connected to the lower section.This paper presents the combination of the two perforating techniques in one operation. It also discusses the candidate identification process, perforation design, formation damage analysis, execution and results. The gravel packs were performed successfully with a GP factor higher than predicted by simulations, and the initial production behavior suggests no evidence of adverse effect on formation damage even when the mechanical surge required for the big hole charges was done higher than conventionally.Considerable rig time savings were achieved by eliminating a Tubing Conveyed Perforations (TCP) run and clean out operation. The operation was performed in 60.8% of the time observed in a previous similar well. The combined perforating technique is suitable for cases where the reservoir properties are very well known.Based on the result of the world first combination of these techniques, continue supporting the implementation of this optimized solution in future wells is high recommended. Perforating StrategyTubing Conveyed Perforation (TCP) is the technology used for perforation in this field, both Dynamic Underbalanced Perforating (DUP) and Mechanical Surge Technique systems will be utilized on a dependent basis.
A Brown field has been in production for over 30 years. A redevelopment plan started in 2004 to revamp oil production under an Alliance partnership between an Oil & Gas Company Malaysia and Schlumberger. The mentioned Brown field is a multilayered reservoir where the UCS can vary from 1500 psi in the consolidated sand until less than 800 psi in the shallow zones. Based on a geomechics study and existing production history of the field, unconsolidated producer sands were identified and sand control methods were evaluated according to the degree of achieving the goals, and reducing risk, the result indicates that the Cased Hole Gravel Pack with Alternate Path System was preferential. Additional information was obtained in the latest campaign during the retrieval of gravel pack screens in 2 sand producing wells, which gave a better understanding of the failure mechanism in the previous gravel pack operations. The main changes in the design of sand control systems during 8 years includes adopting a perforating strategy of performing a mechanical backsurge, increasing shot density and charges with low debris, use of a 3-way sub tailpipe system to avoid problems associated with breaking flapper valves and debris accumulation, number of cup packers, size of screens, slurry concentration and back pressure applied during the treatment. Furthermore the evolution in the sand control management have showed benefits such as increasing the number of gravel pack zones per well, performing longer gravel packs, installing permanent downhole gauges and using bigger tubing. This paper presents as case study of the evolution and the impact of the sand management systems, showing the significant changes in the design and execution of gravel packs and describing the reasons for those changes. The impact is analyzed on the basis of formation damage, GP factor, execution, risks and results of the initial production.
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