The rise in unconventional resource exploration relies on strategically placed sensors to record critical information during multiple forms of testing and reservoir enhancement techniques. The accurate data gained during the testing phases are what ultimately lead to the best flow regime design and successful optimization of the resources. New completion design or reservoir stimulation techniques are also effectively evaluated using data acquisition, aiding the development, refinement, and implementation of these techniques. Subsequently, suspension of the sensors in wellbores without decreasing flow can be challenging when introducing new techniques or modifications. Additionally, these flow rate conditions can prevent the determination of production at the most economically advantageous time and rate. This paper examines difficulties associated with acquiring data that can exist because of new completion designs or exploratory methods tested as a means to optimize a resource's economic viability. Solutions offered by a new highexpansion hanger that can be used to meet these difficulties are also discussed. The tool has been proven to be a durable and flexible solution for an increasing array of completion and reservoir enhancement techniques for many styles and types of well testing under varying pressures and conditions. The tool is available in a wide range of pipe sizes and types, enabling positioning inside liner sizes of larger inside diameter (ID) than that of the uphole completion tubing string within the wellbore. The high-expansion design also provides the assembly a generous bypass flow area, which helps increase the accuracy of the data received during flowing events.Case histories are presented to illustrate the varying range of situations where the high-expansion hanger has been proven both a viable and valuable solution for reservoir analysis and optimization.
As exploration wells reach new depths and environments previously unexplored, the need for intervention services at higher temperature becomes a critical decision point for the entire drilling and completion process. Traditionally, the ability to set wellbore devices at elevated temperatures relied heavily on electric line services due to the higher temperature rating of explosive setting tools or surface powered electromechanical devices. This, of course, relied heavily on the availability and logistical expediency of units, tools, and personnel to avoid any nonproductive time, which could result in costly delays. An alternative would be using drill pipe; however, this could result in an excessive number of hours being added to the intervention process, increasing the overall costs to the developer. Due to these factors, companies continue to try to develop cost-effective intervention solutions while increasing reliability when operating in more hostile environments. Memory tools are fast becoming a favorable and more economic option.Battery operated electromechanical setting tools have been around for many years and continue to evolve. The latest generation of setting tools has allowed advanced memory and command logic to be incorporated, providing more flexibility in the intervention routine as well as a thorough understanding of the recorded downhole event. The tool also has the added feature of a flasking system, allowing a much greater operating envelope when exposed to high downhole temperatures. This makes the use of an alkaline battery powered setting device, deployable via a multitude of conveyance methods, a safer and more cost-effective method. This paper will review the new features and designed uses of this industry respected tool. Case histories with the device to complement intervention needs and operational planning convenience will be submitted to support the inherent value added to the oil and gas industry.
Through-tubing bridge plugs (TTBPs) enable the production of new zones by isolating abandoned zones without requiring a costly and time-consuming workover rig. Previously available hydraulic setting tools were not applicable to all types of well conditions and plugs, often because of extended toolstring length requirements, making them not suitable for wells with limited rigup height capability. A nonexplosive electromechanical setting tool can provide an easy-to-transport, flexible setting tool for all environments. An electrically controlled motor enables the effective setting of multiple sizes and types of TTBPs, not dependent on the environmental effects on downhole fluid required by hydraulic tools to facilitate the setting process. The tool uses rotational torque converted to linear pull tension and operates independently of downhole conditions, not requiring specialty fluid types or relying on the appropriate fluid availability. Because fluid is not required for operations, a shorter overall tool length is required compared to existing hydraulic or pneumatic tools. The ability to deploy shorter toolstring lengths means that the electromechanical setting tool can be used in a wider variety of scenarios, such as remote platforms or rigless environments. With the introduction of the electromechanical setting tool to operations, wells that might have been previously suspended because of the availability of a workover rig can now receive timely interventions, efficiently isolating noncontributing zones and enabling the perforation and production of contributing zones. Operators can benefit from rigless operations by accessing new zones at a lower cost and with a faster turnaround, enabling them to benefit from economically advantageous market conditions. The real-time feedback of the electromechanical tool also confirms that the plug has been set at the required tension using a slow and controlled setting method. This paper presents case histories to illustrate the advantages of the shorter rigup lengths enabled by the electromechanical setting tool; these advantages are made possible by pinpointing instances in which the hydrostatic setting tool methodology would not have allowed recompletion of producing zones. Job data from the electromechanical setting tool are used to illustrate that the slow, controlled set of the TTPBs was achieved within specifications of the plug design, which cannot be confirmed using hydrostatic setting tools. Cost savings and realized production gains are also highlighted in instances in which the electromechanical setting tool was used to increase asset return value.
As the number of mature wells that are no longer economically viable increases, so does the need for effective well abandonment processes that meet stringent environmental and regulatory conditions. Because of varying well configurations and types, a unique or more tailored engineering approach is required to meet plug and abandonment governmental requirements, as well as operator-specific objectives for varying well designs. Through proper planning and design, this method also decreases operational and health, safety, and environmental (HSE) risks for a variety of challenging scenarios. This paper presents case histories of the successful use of a single-trip abandonment approach that saves time for the producers by addressing specific well types by simplifying the abandonment process in an economical and flexible manner through engineering planning and shaped-charge performance design. The single-trip abandonment approach can drastically reduce associated costs common in well abandonment campaigns, including rig time and support services that are involved in making multiple trips in and out of the well. With an average rig rate of USD 500,000 per day for floaters, USD 100,000 per day for jackups, and USD 60,000 per day for barges (Rigzone 2015), any reduction in rig time exposure can be beneficial to the producer. By providing a method of successfully abandoning a well in one trip, as opposed to separate trips involving the cutting and removal of casing strings, the single-trip well abandonment approach allows producers to successfully plug and then spot cement in a combined action, permitting an expedited well abandonment process. Through extensive testing and development of both tool technology and shaped-charge design, the single-trip well abandonment approach has proven to be a versatile and an effective system for a variety of well abandonment scenarios. Providing flexibility in operational capabilities for abandoning a well, squeezing off zones, providing limited casing entry, and allowing annular cement squeezing for remedial work, the single-trip abandonment approach has proven to be reliable and efficient, particularly in operations in the AsiaPac region. Using the engineering aspects of advanced tubing-conveyed perforating (TCP) design and capabilities as a building block in the single-trip system allowed for the successful implementation of required abandonment procedures while also providing the capability to be deployed in a variety of casing sizes, weights, and wellbore conditions. This paper provides an in-depth study of the technical design, advanced modeling, multiconditional testing, and shaped-charge optimization of the systems for the single-trip abandonment approach. Additionally, the paper provides beneficial information that could be applied to well abandonment projects around the world.
Currently, oil and gas operators face a number of significant challenges, such as meeting increasing demand and using safe and environmentally responsible methods as well as minimizing costs while maximizing the profitability of highly complex operations. One solution is to achieve a more comprehensive understanding of assets by successfully integrating monitoring and active control systems. This led to the implementation of smart-well completions (i.e., interval control valves, interval control devices, subsurface safety valve systems, and fiber optic monitoring) (Rodriguez et al. 2013).Yet, some companies still resist this technology because of risk concerns, such as valve failures occurring or bypassed pay zones that warrant well intervention being necessary, which involves pipe perforation. When a control line or umbilical line is strapped to the outside of a well completion, risk is increased for the well intervention. In most instances, it is not possible to pinpoint the exact location of the line within a 360° span of the curvature of the tubing. This is because some completion designs without pre-planned indicators of line placement add to the challenges associated with control and data line moving during the running phase of the well completion. Without the ability to locate the line used for communication with downhole devices, the potential for damage exists resulting from conventional methods of explosive perforation. The development of a nondamaging perforation method provides a means to establish needed communication while helping avoid unrecoverable damage to an asset.
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