With the increase of automation and process control requirements, a good real-time grasp of the drilling fluid rheology has repeatedly been flagged as a key requirement. Unfortunately, drilling fluid rheology is still mostly measured manually and reported only twice a day. Fluctuations in fluid composition and rheology due to wellbore/fluid interaction and temperature/shear/solids effects are generally missed. This paper describes the field implementation and testing of an inline-design pipe rheometer that operates autonomously to continuously measure rheological properties of the drilling fluid in the rig's mud tanks. This data can be used to monitor the stability or indicate changes in these drilling fluids. The system employs a progressive cavity pump to draw drilling fluid from the mud tank and propel it, at varying controlled rates, through two different sizes of pipe. Differential pressure transducers are used to measure the pressure drop over a fixed length in each size of pipe, and this data, along with flow rate, is used to calculate fluid viscosity. All components are installed within a standard ISO shipping container for ease of transport and deployment at the wellsite. It is positioned next to the mud tanks where it continuously samples and measures the drilling fluid. Field test results of the system are presented. The system was operated autonomously on location in Saudi Arabia for an entire drill stage (3.5 days) of 5-7/8" section for gas drilling. In this section, oil based mud was used and measured by the system. The system was controlled remotely via WiFi connection. During the test period, manual viscosity and density measurements were also taken using the Fann-35 and mud balance methods. Subsequent comparison shows excellent agreement between the automated and manual measurements.
The open hole clad technology based on high performance solid expandable tubular is an innovative technology developed rapidly in recent years. It is focus on solving difficult problems that weak and complex formation and severe drilling loses which cannot be effectively plugged or controlled. Especially in shale gas drilling, with that the formation pressure system is more complex and more difficulty to predict accurately, the severe drilling loses and diverse well-bore structure design difficulties are more common. It is urgent to apply this technology to deal with multiple down-hole complex situations and optimize the well-bore structure in shale gas reservoir. This paper studies the long open hole clad technology based on high performance solid expandable tubular in shale gas reservoir by using the methods of theoretical research and field trials. According to the characteristics of shale gas reservoirs, we firstly systematically studied the technical principle, tool structure design and construction process of the open hole clad technology. Then, aiming at improving the ground bearing capacity of CX~ LS formation of shale gas wells of H-3 and H-4, we carried out the open hole clad technology field experiment and analyzed the effect. The research results show that: (1) By optimizing the tool structure and construction process, the open hole clad technology can effectively deal with the risks and challenges brought by severe drilling loses on the safe drilling in shale gas reservoirs. (2) H-3 and H-4 shale gas wells have successfully created conditions for safe drilling in the target formation of LMX group by using open hole clad technology to preventively seal the CX~LS formation with low ground bearing capacity. The ability to seal complex formations in shale gas reservoir using long open hole clad technology based on high performance solid expandable tubular can be deployed economically in shale gas reservoir with complex formation or severe drilling loses.
This paper discusses the designing and field application of a polymer resin-based cement system that enhances the final cement properties in terms of compressive strength and cement bond to the casing along-with minimizing the occurrence of casing-to-casing annulus (CCA) pressure during the life cycle of the well. Several experimental studies were applied to this polymer resin-based cement system including rheology, thickening time test, free fluid test, compressive strength test, etc. The results showed that the polymer resin-based cement has improved compressive strength, ductility, and enhanced shear bond strength. Which, as a result, helps to provide a dependable barrier that would help to prevent future sustained casing pressure (SCP). Besides, the cement slurry was designed with a controlled and engineered rheology. This was done by controlling the amount of the resin and cross-linker into the cement slurry in order to achieve the target density as well as to avoid a sudden increase in the final slurry viscosity that could result in mixing difficulties at the field. Moreover, the field deployment of this system on a 13 3/8-in casing second stage tail slurry has been discussed.
This paper introduces the implementation of hydro-efflux hammer as an effective rate of penetration (ROP) enhancement tool. In the test well, the target formations are mainly composed of dolomite, limestone and carbonate with hard and abrasive characteristics. In addition, the carvings caused by the unstable shale formation in the upper section result in an increased mud weight, and associated drilling difficulties and low penetration rate. The conventional drilling techniques including mud motor have not been effective in this scenario. By implementing a 9-inch hydro-efflux hammer to drilling across the given formations, a significant ROP enhancement was observed. The deployment was planned based on quantitative analysis of formation characteristics, a study on the correlation between the tool's performance parameters and formation anti-drillability parameters, and the well design. The rotary percussion drilling parameters, bottomhole assembly (BHA) and bit selection are optimized through impact resistance and bit aggressiveness analysis. The result showed an ROP enhancement of over 47% compared with the offset average, providing an effective alternative for similar applications.
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