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Collaborating Authors
Denmark
ABSTRACT Advances have been made in the subsurface temperature estimation basing on the indirect electromagnetic geothermometer. The approach used was based on the artificial neural network technique, which, contrary to other available approaches, does not imply the prior knowledge of the electrical conductivity mechanisms and rock properties. Application of the indirect EM geothermometer to the interwell space interpolation in three areas (Tien Shan, Kyrgyzstan; Soultz-sous-Forรชts, France; and Hengill, Iceland) characterized by different geologic environments indicated that the temperature estimation errors are controlled by four factors: faulting, distance between the EM site and the area where the temperature is estimated, meteoric and groundwater flows, and lateral geologic inhomogeneity (although the latter factor is less restrictive if appropriate EM inversion tools are used). It was demonstrated that the extrapolation errors depend on two factors: spacing between the EM site and the borehole, and ratio between the well length and the extrapolation depth. In particular, the relative accuracy of the temperature extrapolation to the depths twice as large as the borehole depth did not exceed an average of 5%. Using the indirect EM geothermometer, it was possible to reconstruct 2D and 3D temperature models of the studied areas from EM sounding data, which, in turn, enabled us to draw important conclusions regarding the dominating heat transfer mechanisms, fluid circulation paths, and better locations for drilling new boreholes. Application of the indirect EM geothermometer during exploitation of the geothermal reservoirs may enable one to monitor the variations of subsurface temperatures basing on the ground EM monitoring data and forecast future trends.
- Asia > Kyrgyzstan (0.34)
- Europe > France > Grand Est > Bas-Rhin > Soultz-sous-Forรชts (0.25)
- Geology > Rock Type > Igneous Rock (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Mineral > Silicate (0.68)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Renewable > Geothermal > Geothermal Resource (0.47)
- Europe > Netherlands > German Basin (0.99)
- Europe > Germany > German Basin (0.99)
- Europe > Denmark > German Basin (0.99)
- Asia > India > Jammu and Kashmir > Puga Field (0.99)
Characterization of Direct Fractures Using Real Time Offshore Detection of Deuterium Oxide Tracer
Poulsen, Allan K. (Danish Technological Institute) | Lafond, Kim Bousquet (Maersk Oil) | Voigt, Niels V. (Danish Technological Institute) | Lundgaard, Thomas (Danish Technological Institute) | Pedersen, Lars Malcolm (Maersk Oil)
Abstract Induced or natural fractures in waterflooded reservoirs can have a negative impact on oil recovery. Direct connections between injectors and producers allow otherwise recoverable oil to be bypassed by the injected water, reducing the sweep efficiency and the pressure support to the reservoir. Knowledge about the number of connections, their location and size is essential to properly design a reliable conformance treatment. The Danish Technological Institute has together with Maersk Oil developed a deuterium based tracer technology which can provide information about high conductivity fractures in tight reservoirs. The method has been proven on several studies in the North Sea and allows quick and direct analysis offshore. Immediate actions based on real time results offshore can be taken and minimum response time is needed for planning further operations. The tracer used is deuterium oxide which is safe to handle and brings no environmental issues, as it is already naturally present in water. It is completely miscible with water and does not dissolve in the oil phase. The returns are analyzed directly from the produced water stream after separation using a mass spectrometer. This portable equipment allows a quick and reliable analysis with minimal sample preparation. The concentration of tracer is analyzed to give information such has breakthrough time, concentration profile and volume of tracer returned. This data is then used to determine the number of fractures, their conductivity and their relative position in the wellbore using an injector-fracture-producer model.
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5505/13 > Halfdan Field > Maastrichtian Formation (0.99)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5505/13 > Halfdan Field > Danian Formation (0.99)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5504/16 > Halfdan Field > Maastrichtian Formation (0.99)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5504/16 > Halfdan Field > Danian Formation (0.99)
New Sensor Development Helps Optimize Production Logging Data Acquisition In Horizontal Wells
Zett, Adrian (BP) | Webster, Michael (BP) | Noordermeer, Alwin (BP) | Hockley, Mitchell (GE Oilfield Technology) | Lockyer, Glynn (GE Oilfield Technology) | Browne, Hugh (GE Oilfield Technology) | Donkin, Charles (GE Oilfield Technology)
ABSTRACT As horizontal wells become increasingly common, the need to make measurements to optimize well health and manage the reservoir also increases. Production logging in horizontal wells with multiphase flow presents data acquisition challenges in the form of conveyance method and sensor selection. In this paper we present an approach to logging a horizontal well using new generation array sensors. The well was cased and perforated with high water cut and sand production. Logging while tractoring a combination of conventional (centralized) and array sensors provided a good quality data set that enabled successful identification and shut-off of sand and water. The use of a new impeller design in a mini-spinner array helped overcome the challenges sand production posed in the well. Smaller mini-spinner thresholds improved the velocity profile, allowing us to identify water recirculation at very low rates. An array resistance measurement provided an estimate of water holdup. Tool rotation proved an important benefit for array sensors run in this harsh environment. Tool rotation helped keep the sensors free from debris while the traditional centralised spinner showed an increased tendency for jamming when intersecting sand accumulations in casing troughs or restrictions along the well trajectory. In addition, the rotating array sensors provide good circumferential coverage in the well. A sand detection instrument was used in combination with the production logging string. The instrument is combinable with the production logging string and simultaneous data acquisition permits to integrate all sensors, allowing a robust interpretation of sand influx and water salinity. This paper focuses on the acquisition of new generation array data to help meet the well intervention objectives leading to a commercial and technically successful out-come. It identifies the strengths and gaps of current technology relative to existing challenges in horizontal wells and the need to move to array measurements.
- Europe (1.00)
- North America > United States (0.93)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 23/16a > Eastern Trough Area Project > Mungo Field (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 22/20 > Eastern Trough Area Project > Mungo Field (0.99)
- North America > Canada > Alberta > Howard Field > Bpc Et Al Howard 6-31-79-5 Well (0.89)
- (4 more...)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE/ICoTA Coiled Tubing & Well Intervention Conference & Exhibition held in The Woodlands, Texas, USA, 27-28 March 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract Sliding sleeves are used to enable selective zonal isolation and can improve water and gas management throughout the life of the well. Because of the large shifting force and extended reach required to operate sliding sleeves in long horizontals, coiled tubing is typically used. Coiled tubing also provides the benefit of pumping fluids to clean out or treat the well.
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5504/12 > Tyra Field (0.99)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5504/11 > Tyra Field (0.99)