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For ultra-deep horizontal wells in Tahe Oilfield in China, the solid expandable tubular (SET) technology was applied in the buildup section to isolate unstable mud stone with clays above the pay zone. This technology satisfies the requirements of geological water avoidance, and a larger hole size is adopted in the pay zone. This paper proposed a finite element dynamic model to analyze the expansion of the SET, and the impacts of the following factors on the expansion force required for the expandable tubular were analyzed: yield strength of the tubular material, solid tubular expansion ratio, the coefficient of friction between the expansion cone and the tubular, the angle of the expansion cone, movements velocity of the expansion cone, and DLS (dogleg severity). The calculation results indicate that a higher expansion ratio, a higher yield strength, and a higher friction coefficient of the SET result in a larger expansion force to different degrees, whereas the other factors have little effect on the expansion force. The dynamic expansion force calculation model established in this paper is consistent with the actual conditions, and the simulation calculation results can be applied to provide theoretical guidance for SET expansion operations.
For ultra-deep horizontal wells in Tahe Oilfield in China, the solid expandable tubular (SET) technology was applied in the buildup section to isolate unstable mud stone with clays above the pay zone. This technology satisfies the requirements of geological water avoidance, and a larger hole size is adopted in the pay zone. This paper proposed a finite element dynamic model to analyze the expansion of the SET, and the impacts of the following factors on the expansion force required for the expandable tubular were analyzed: yield strength of the tubular material, solid tubular expansion ratio, the coefficient of friction between the expansion cone and the tubular, the angle of the expansion cone, movements velocity of the expansion cone, and DLS (dogleg severity). The calculation results indicate that a higher expansion ratio, a higher yield strength, and a higher friction coefficient of the SET result in a larger expansion force to different degrees, whereas the other factors have little effect on the expansion force. The dynamic expansion force calculation model established in this paper is consistent with the actual conditions, and the simulation calculation results can be applied to provide theoretical guidance for SET expansion operations.
Solid Expandable liners have been used extensively over the past 10 years for drilling liners, but rarely as production liners, much less in high risk environments where the expandable liner becomes differentially stuck as soon as it reaches the end of the horizontal hole section. This environment requires the liner to be cemented and expanded in one of the most (if not the most) difficult well conditions it can be subjected. The expandable liners discussed in this paper so far have shown positive field status as production liners. When an expandable liner, that is not differentially stuck, is expanded using a swage it typically "shrinks" in length as it expands in diameter as part of material balance physics. This shrinkage is typically 4 to 6%. That is, if a 1,000 ft liner is expanded 5% in diameter, the expanded length would be reduced to ~950 ft. To compensate for this shrinkage, an additional length of liner is run to ensure that the final length of liner required is delivered. However, when the expandable liner becomes differentially stuck or can not move along the length of the wellbore during expansion, it can not gain the material for its growth in diameter from the liner's length. Therefore, the material is sacrificed within the liner's wall and its connectors. This environment is considered one of the most strenuous a solid expandable liner can be subjected to during expansion. Combining insightful engineering with a stringent qualification regime of the expandable system and the tubulars and connectors that it utilizes, solid expandable production liners can be installed that will service these types of complex wells. While extensive engineering and lab testing of an expandable system is critical, the ultimate testing is in multiple field applications to best develop effective reservoir sweeping of a mature field. Several case histories of field installations will be reviewed. The installation, zonal isolation, and tubular performance of these liners will be evaluated and reviewed using downhole tubular inspection logs, observed installation phenomenon, and performance over time. This empirical data will give the potential end users fundamental knowledge and good case history information on how to best qualify and use solid expandable liners for the ultimate benefit of gaining more oil production and reducing overall well cost. Introduction It is necessary to have a basic knowledge of how solid expandable openhole liners are installed to extract a firm understanding of the information in this paper. While this paper reviews the basics, a host of technical papers and articles expound on the fundamentals of solid expandable liner installation. (Filippov 1999; Dupal 2000; Dupal 2001; Zhou 2004; Furlow 2000) With this foundation of understanding, an explanation of the wellbore environment of these complex wells will be provided. An investigation of the openhole production liner system qualification process will highlight the critical factors that significantly reduce operational risks. This paper probes several factors, specific to the wells of a major operator in Saudi Arabia, prior to and within the installation process that also reduce the end user's risk. Finally, an in-depth study of these several case histories will be examined to provide a deeper understanding through this situational analysis.
Traditionally, solid expandable liners have been run without any centralizers due to the perceived risk involved, since typical centralizers would impose extra restrictions on the pipe body, which would require additional force to expand. Also, the centralizers may break during running in hole, which would lead to a possible stuck liner, and consequently, be a major problem of liner expansion. It's also important to realize that there is a limited running clearance if conventional centralizers are utilized. This puts a lot of constraints on the type and availability of possible centralizers. As a result, some residual mud may remain on the low side of the hole during cementing operations, since it is not possible to rotate the expandable liner while cementing, nor reciprocate the liner after reaching setting depth to avoid possible damage of the expandable casing's connection protection sleeves across the prevous 7 in. casing shoe or window exit. Consequently, the cement bond between the expanded casing and the formation would be limited and long-term isolation may be less than required.Recently, an innovative ceramic centralizer was evaluated and implemented in the field. The ceramic centralizer consists of three individual pads affixed to the expandable casing 120 degrees offset to each other, with three centralizers equally spaced out along the middle part of the 38 ft expandable casing joint. The pad itself is made of carbon fiber ceramic composite material that is characterized by strong toughness. Once bonded to the base pipe it is not possible to remove it even with 180,000 lbs of force. It has a lower friction factor than casing, and is corrosion resistant. After tailoring the pad design to suit a 5½ in. expandable liner, such centralizers on cemented expandable liners were successfully run in five wells without any problem. The acquired ultrasonic image tool (USIT) log demonstrated that the cement bond with such centralizers was substantially better than the case without the use of any centralization.
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