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Most of the wells in the Dzheitune (Lam) field in the Caspian Sea were completed with dual tubing. Depletion in reservoir pressure caused formation failure in the A sand reservoir, and wells producing from this formation began to produce sand. Field examples presented in the complete paper describe principles of data acquisition with a sand-detection tool when run in combination with a production logging string and results of logging in slightly deviated wells completed with sand screens. Comparison of multiphase-inflow profiles with sources of sand production showed that most sand was produced through eroded intervals in the sand screens. Most Lam wells were completed with 9.625-in.
- Asia > Turkmenistan > Caspian Sea (0.26)
- North America > United States > Wyoming > Campbell County (0.25)
- Asia > Turkmenistan > Caspian Sea > Cheleken Contract Area > Block 2 > Lam Field > Zone 7 Formation (0.99)
- Asia > Turkmenistan > Caspian Sea > Cheleken Contract Area > Block 2 > Lam Field > Zone 6 Formation (0.99)
- Asia > Turkmenistan > Caspian Sea > Cheleken Contract Area > Block 2 > Lam Field > Zone 5 Formation (0.99)
- Asia > Turkmenistan > Caspian Sea > Cheleken Contract Area > Block 2 > Lam Field > Zone 4 Formation (0.99)
Abstract The purpose of production logging is to describe the flowing characteristics of a well, however, it is only in the simpler well and fluid configurations that conventional measurement technology is in general adequate. In addition, the challenge of obtaining useful measurements is further complicated by the rapid advancement of completion technology resulting in increasingly complex well configurations. As a part of a Norwegian research program new technology is being developed with the objective of improving the diagnostic capability of production logging in especially horizontal wells. Sensor developments include a downhole sand detection tool and an ultrasonic flowmeter. Complimentary developments in the field of high temperature electronics are improving tool reliability and extending the capability of downhole instrumentation to deeper (hotter) reservoirs. This paper describes the technology taken into use and reviews laboratory and field experience. Introduction Production logging attempts, from bottomhole measurements, to describe the flowing characteristics of a well. Well problems can thus be diagnosed/repaired and reservoir management is assisted. However in general it is only in the simpler well and fluid configurations that conventional production logging measurement technology is adequate. This reflects that developments in production logging have not kept pace with completion technology which in contrast is resulting in increasingly complex well configurations and associated bottomhole flowing conditions. A program of production logging tool development is in progress also as a part of a Norwegian research program in well technology. The production logging developments include new sensor technology for sand detection, flow metering and fluid compositional measurements, high temperature electronic design and integration with complementary systems such as the well tractor. This paper reviews those developments that have reached field testing including a downhole sand detector, an ultrasonic flowmeter and high temperature electronics. Sand production problems can represent a limiting factor for well and field production potentials. Identifying sand producing zones and measuring their production characteristics can assist in choosing the correct sand control strategy. A downhole sand detection tool has been developed based on established surface sand detection technology. The tool is in use in the North Sea and Middle East. For multiphase flow in highly deviated and horizontal wells the simple designs of contemporary flow metering devices are generally insufficient to provide an adequate description of the fluid flow. In addition, due to their mechanical nature flowmeters often prove to be unreliable in the harsh bottomhole environment. A solid state ultrasonic flowmeter is under development based on medical doppler velocimetry which potentially can provide an improved description of the flow velocities. Field testing has proven the viability of using the technique downhole The most recent prototype tool makes multiple velocity measurements across the wellbore cross section. As oil exploration drills deeper, reservoir temperatures are increasing and HPHT wells are planned with bottomhole temperatures as high as 230 C. Conventional high temperature production logging tool technology is normally rated to a maximum operating temperature of 175 C and for a limited period of time. As a part of an advanced production logging tool development, high temperature electronic circuits are being developed to replace conventional logging tool electronics. Laboratory testing indicates reliable high temperature operation is achievable at 230 C. The resulting downhole electronics are very compact, taking as little as 1/20th of the space of conventional electronics. P. 793
- North America > United States (0.68)
- Europe > Norway > North Sea (0.34)
- Europe > United Kingdom > North Sea (0.25)
- (2 more...)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 050 > Block 34/10 > Gullfaks Field > Statfjord Group (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 050 > Block 34/10 > Gullfaks Field > Lunde Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 050 > Block 34/10 > Gullfaks Field > Lista Formation (0.99)
- (2 more...)
Abstract An ultrasonic tool has been developed for MWD applications that simultaneously performs real-time bore-hole caliper measurements and real-time gas influx detection The caliper determines the ovalness of the hole with a high degree of accuracy and excellent vertical resolution. These measurements are transmitted to the surface and also used to compensate LWD measurements. Furthermore, with early and accurate real-time caliper measurements, bore-hole instability can be detected. Real-time gas influx detection insures early and reliable gas kick detection and should provide a considerable improvement in drilling rig safety. The new tool is particularly useful for avoiding problems associated with shallow gas formation problems associated with shallow gas formation where response time for kick detection is critical. Introduction During drilling local changes in bore-hole shape or diameter are common, especially in a highly deviated hole. Without proper reaming, the drill string can become stuck resulting in added expense and the loss of valuable rig time. When monitoring the hole size during drilling, key-seats and other geometrical discontinuities are easily detected. So, correct and timely decisions about hole reaming can be made, reducing the occurrence of stuck pipe. Another advantage of the real-time caliper is the early detection of bore-hole instability. This caliper helps the driller make the proper decision such as either reaming the critical zone, changing the flow rate to reduce hole erosion, or modifying the string RPM to reduce shocks with the formation. Thick mud cake can build up with time in front of permeable formations, adversely effecting most permeable formations, adversely effecting most logging measurements. Furthermore, its removal might be necessary to insure the proper formation seal with the cement. Comparisons between caliper logs obtained in real-time and while tripping indicate the location of mud cake buildup. Such detection is critical as this thick cake may appear in front of pay zones. Anyway, a real-time caliper log becomes a necessary quality control enhancement now that logging while drilling has become common practice. practice. The other purpose of the new tool is the down-hole detection of gas influx in the well-bore. Ultrasonic measurement allows accurate and reliable gas detection in the bore-hole because the acoustic properties of drilling mud change P. 439
Abstract Significant financial and environmental consequences often result from line leakage of oil product pipelines. Product can escape into the surrounding soil as even the smallest leak can lead to rupture of the pipeline. From a health perspective, water supplies may be tainted by oil migrating into aquifers. A joint academic-industry research initiative funded by (Pipeline and Hazardous Materials Safety Association) PHMSA has led to the development and refinement of a free-swimming tool which is capable of detecting leaks as small as 0.01 L/min (0.03 gallons) in oil product pipelines. The tool swims through the pipeline being assessed and produces results to the end user at a significantly reduced cost compared to current leak detection methods. Above Ground Markers (AGM’s) capture low frequency acoustic signatures and digitally log the passage of the tool through a pipeline. A tri-axial accelerometer system gives the odometric position of the ball, and has the accuracy of standard instrumented pigs. Several other types of sensors like temperature, and pressure, are also present in the ball and collect useful data.
Abstract Fibre Optic Leak Detection (FOLD) Project Recent news headline came to remind the dangers associated with gas transportation. Due to its asset size, pipelines are often the facilities the more difficult to protect in cases of an explosive gas leakage. The objectives of the Fibre Optic Leak Detection (FOLD) project were to assess the capability of fibre optic sensing to detect a small gaseous leakage on a buried pipe, to give guidelines regarding the best deployment positions of the fibre along the pipe, to compare the performance of several methodologies and to assess the impact of the fibre optic length on the detection performance. The strength of this project is to propose a representative test bench to help the industry to mature the detection methodologies: Gaseous leakages were performed from the external surface of a steel pipe with an internal diameter of 390 mm and a length of 30 m. These leakages were of methane, hydrogen or nitrogen and took place through different orifices (from 1 to 7 mm) and at varying released pressure (between 20 and 100 bar). This pipe and the optical cable were buried in a granular type soil compacted to a known level. Several types of interrogator (DTS - Distributed Temperature Sensor) from different suppliers were tested during the FOLD project. The paper will present the experimental bench and the main results. Based on these results, it will be possible to conclude on the overall performance of the DTS technologies to detect a small gaseous leakage on a buried pipe, to give guidelines to optimise several parameters for improved detection performances: fibre optic position or deployment architecture along the pipe (directly buried or into a polyethylene tube), detection range assessment, equipment choice... Five different instrument suppliers took part in the initiative and delivered comprehensive data. To make sure that detection will occur whatever the gaseous leakage flow rate on a buried pipe, it could be interesting to use both internal detection means (pressure or flowrate transducers placed at both ends) and external ones. Among the technologies available for external sensing, the optical fibre seems to be a promising candidate. This paper will present brand new data, collected in very controlled conditions, to assess the performance of such technology. We will present the proportion of instruments capable of detecting leaks and the possible configurations presently recommended to pipeline designs in project phase.