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One of the main challenges in the well intervention in offshore brown fields prone to sand production is both subsurface sand handling and also surface sand handling during the flow back and well cleaning. The field of interest is located offshore in East Malaysia. The field had been producing for almost three decades and is prone to sand production with no capabilities of surface sand handling. This paper describes the integrated solution to address sand production on both surface and subsurface, targeting sand production from the unconsolidated reservoirs but also from well clean up before and after well intervention. In order to provide a cost effective solution for the new potential layer below the existing gravel pack zone, through tubing gravel pack technique was chosen as the sand control technique. This enabled the new zone to be produced in the optimum draw down without the risk of having sand production at surface. However prior to that, the rathole for the potential new layer had to be cleaned up using coil tubing. The sand and debris from this cleanout had to be circulated out to surface and needed to be separated before being disposed properly onshore. A cyclonic desander was temporarily installed on surface to achieve this. As a result, the integrated system provided overall solutions where downhole sand control was achieved and the cleanout fluid was free from solids to ensure no cascaded damages to the existing process facilities.The system permitted to execute two wells cleanups, one through tubing gravel pack while complying with the very strict sand content limitations -particle size less than 45 microns and not more than 15pptb. The newly introduced technologies proved to be fit-for-purpose and robust, complying with sand content limitation as well as with all the other constrains.The General description in term of operations and installation of such system as well as lessons learned and recommendations have been outlined in the paper that can be used as a reference for similar applications in the near future.
One of the main challenges in the well intervention in offshore brown fields prone to sand production is both subsurface sand handling and also surface sand handling during the flow back and well cleaning. The field of interest is located offshore in East Malaysia. The field had been producing for almost three decades and is prone to sand production with no capabilities of surface sand handling. This paper describes the integrated solution to address sand production on both surface and subsurface, targeting sand production from the unconsolidated reservoirs but also from well clean up before and after well intervention. In order to provide a cost effective solution for the new potential layer below the existing gravel pack zone, through tubing gravel pack technique was chosen as the sand control technique. This enabled the new zone to be produced in the optimum draw down without the risk of having sand production at surface. However prior to that, the rathole for the potential new layer had to be cleaned up using coil tubing. The sand and debris from this cleanout had to be circulated out to surface and needed to be separated before being disposed properly onshore. A cyclonic desander was temporarily installed on surface to achieve this. As a result, the integrated system provided overall solutions where downhole sand control was achieved and the cleanout fluid was free from solids to ensure no cascaded damages to the existing process facilities.The system permitted to execute two wells cleanups, one through tubing gravel pack while complying with the very strict sand content limitations -particle size less than 45 microns and not more than 15pptb. The newly introduced technologies proved to be fit-for-purpose and robust, complying with sand content limitation as well as with all the other constrains.The General description in term of operations and installation of such system as well as lessons learned and recommendations have been outlined in the paper that can be used as a reference for similar applications in the near future.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractIn remedial situations, it is often desirable to place a large diameter screen inside of a liner or failed screen section and place gravel in the small annular space. In some situations, this will allow continued optimum production from the wellbore without the need for a costly sidetrack.In preparation for some remedial work in the North Sea, a laboratory investigation of important parameters involved with low viscosity gravel packing with small annular clearances was undertaken. Initial laboratory testing had indicated that the extremely tight clearance between the screen and the casing (approximately 0.27 inches radial clearance) caused sufficient change in the flow dynamics for premature bridging to occur even when standard water packing guidelines were followed. To alleviate this problem, further testing was performed to determine how standard practices could be modified to meet the challenge. This study included both circulating gravel packs and gravel packs conducted with no return flow. A variety of wellbore deviations, flow rates, sand concentrations, and washpipe diameters were tried to determine the relative importance of these variables.The results of these tests, a look at how these results fit with current concepts of through tubing gravel pack completions, and guidelines to assist in the design of through tubing gravel packs are presented.
This paper presents a detailed case history showing the practical use of monobore and vent-screen completions to produce from reservoirs that are marginally commercial. Marginal well completions can become a viable economic possibility through (1) advancements using monobore and vent-screen completions, (2) innovative application of sand control products, and (3) 3-D modeling.The three-part completion strategy presented below shows that a sand-control fracture treatment can be economically efficient in marginal wells that would not have historically justified such completion.Perform the completion process without a rig on location. All elements of the strategy must have this element as a primary consideration.Plan and prepare for the delivery of the completion in a manner that is practical, economic, and timely, so that job quality and safety are not compromised.Integrate new and existing technologies to create a fresh approach to provide economic solutions for both sand control and stimulation of the well. Introduction Work described in this paper was conducted in a mature West Cameron field (in the Gulf of Mexico) with existing completions and newly drilled secondary targets consisting primarily of gas formations. The hydrocarbons are located in fault-trap reservoirs and are pressurized and produced by a water-drive mechanism. The traditional completion strategies for wells that justify a fracture-stimulation job, rather than a water pack or extension pack, employ a rig and production tubing. The rig is used to make up the drillpipe to deploy perforating guns, screen and blank assembly, and stimulation treatment. Coiled tubing, electric line (e-line), and wireline can be used as alternate methods to perforate the well, deploy the screens, and clean up the wellbore following a stimulation treatment. Using a completion strategy that does not require the use of a rig can have a significant impact on the overall cost of the project, and it also eliminates the need for drillpipe.[1] To save time and cost, preparations can be made before the stimulation vessel arrives on location. Modeling of the formation and predicting the response to a treatment have made advances in the last few years with the 3-D models employed. If the operator can predict the formation response, the cleanup effort for a well that has screened out can be reduced significantly. Also, optimization of the stimulation treatment design can take place days in advance of the actual treatment, saving valuable time at location with a stimulation vessel. A surface iron package rigged up and tested on location before stimulation vessel arrival also reduces the time a stimulation vessel is on location. Fluid selection is critical to reducing cost and performing a successful stimulation treatment. Environmentally friendly stimulation fluids reduce the time and cost necessary to handle the reclamation of fluids following the treatment for disposal (Fig. 1). Vent-screen technology was introduced in the late 1980s and is now a commonly accepted completion strategy. Vent-screen assemblies consist of (1) a primary production screen long enough to cover the perforations, (2) a length of blank spacer pipe, and (3) a short upper section of screen, bull-plugged on top (Fig. 2).[2]Vent screens have seen common failures in the past in highly deviated wells or wells in which production rate is maximized for economic reasons. Surface modification agents (SMA) have been developed to address the failures previously experienced.[3]Additionally, predicting and modeling vent-screen completions through both field experience and laboratory experiments have increased the success of vent-screen completions to a level comparable to that associated with any sand control/stimulation treatment strategy.
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