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Collaborating Authors
SPE Russian Oil and Gas Exploration and Production Technical Conference and Exhibition
Резюме A new multi-purpose hardware-software system based on high-frequency pulsed neutron generator (MANK) is described. The main differences between this device from other devices of pulsed neutron logging (PNL) include: two probes, with each probes consists of a three epicadmium and thermal neutron counters, an variable frequency and duration of the fast neutron pulses. The device can measure the slowing-down time of neutrons, and determine the porosity of the reservoir with high sensitivity and weak influence of lithology, mineralization of the borehole and formation fluids. It is also possible the measurement of macro cross-section of thermal neutron capture (Sigma). There was completed computer (Monte-Carlo) optimization of the device, obtained a series of modeling and borehole measurements, obtained a set of interpretation charts for main parameters,
Abstract The interest in Stoneley waves in wellbores drilled through porous media comes from the dependence of its attenuation on formation permeability. This property makes the Stoneley waves an important tool for measuring the permeability of the porous medium [Xianyun, Hezhu, 2007; Dorovsky V. et al. 2010]. Drilling technology induces mudcake buildup between the borehole fluid and the porous formation with permeability of the latter being our main subject of this paper. Therefore what are the distinguishing properties of mudcake buildup during the permeability-measuring process while using the Stoneley wave properties, and what influence does mudcake thickness and rheology have on the attenuation length? There seems to be no obvious answer to these questions. Another important fact is dependence of the characteristics of the radial oscillations of the borehole fluid on formation permeability [Dorovsky et al. 2010; Dorovsky V. et al. 2012]. This fact allows one to measure formation permeability, and it should be evaluated for the case of mudcake presence. An issue of changes in the measuring procedure for permeability in the presence of radial oscillations of the borehole fluid arises in case of radial oscillations. The main property of radial oscillations is the dependence of the relative velocity of the formation matrix and formation fluid on the permeability of the porous medium at the interface between the media. Measuring the relative velocity at the interface between the media on the borehole side, one can use this dependence to calculate formation permeability. In the presence of mudcake, relative velocity dependence on permeability is retained, but only between the formation and mudcake, which cannot be measured directly on the side of the "mudcake-borehole fluid" interface. However, because the relative velocity in the formation beyond the borehole retains its dependence on permeability, it serves as a means of effective attenuation of borehole fluid waves. This can also serve as a tool for measuring formation permeability in the presence of mudcake and seems to be the foundation for numerical attenuation studies of the Stoneley waves and radial waves in the presence of mudcake. Therefore it should be noted that the influence of mudcake on the Stoneley waves was investigated by Liu, Maximov, etc. [Liu, Johnson, 1997; Maximov, Merkulov, 2002] drew the conclusion based on the theoretical analysis within the framework of the Biot theory that mudcake appears to reduce the influence of permeability on the attenuation length of the Stoneley waves.
Abstrac Operators in the US have been producing from shale for decades, which places Europe and other continents with shale reservoirs in a unique position to benefit from the sharing of knowledge and technology already in use. However, Europe is faced with unique challenges that include the following: Rapid production decline. Water usage/disposal. Small pad size. Equipment limitations. High cost of nonproductive time (NPT). To truly optimize a multizone stimulation treatment of unconventional reservoirs, one should not adopt the premise that the speed of the operation and initial production are all that determine success. Formation evaluation should be the primary determining factor in selecting the optimum completion technique, which must also provide a low-risk, operationally efficient solution designed to increase the reservoir contact and ultimately improve long-term production. This paper discusses a new coiled-tubing (CT-) deployed hydraulic fracturing process, which is expected to have a considerable impact on advancing economic recovery of shale gas in Europe by fracturing one interval at a time using downhole mixing of proppant into the fracturing fluid. The downhole mixing rate can be manipulated in real-time to customize the placement and downhole-proppant concentration instantly. The combination of downhole mixing and microseismic fracture mapping provides unprecedented control of the fracturing treatment execution to facilitate branch fracturing. At the end of the final treatment stage, the well is simply cleaned out, with the entire operation completed with only one CT trip in hole. This paper reviews this technique, comparing it directly to conventional processes. In addition, background information is supplied from a combined CT/jointed-tubing (CT/JT) deployed hydraulic fracturing process.
- North America > United States (1.00)
- Europe (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.77)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (3 more...)
Abstract This paper describes an easy-to-use and fast-track roadmap for Enhanced Oil Recovery (EOR) Prefeasibility Study including (1) screening of EOR suitable methods 2) estimating of additional recovery with mechanistic 3D models 3) evaluating preliminary economics (NPV) for field scale application 4) assessing the main uncertainties to reservoir, fluids and economical parameters. Oil-production from EOR projects represents currently about 4% of the worldwide production; this ratio is expected to increase significantly in the near future. EOR projects require in general important investments often in matured fields. It is therefore important for a decision maker to have a global view of the main technical and economical expectations and risks ahead of an EOR project decision. This roadmap helps identify ahead of an EOR project the main technical and economic challenges and provides a first Go/No-Go taking into account the main uncertainties and risks associated to this type of project. The main results of this roadmap are a set of pre-defined mechanistic 3D models with different reservoir geometries and suitable for 7 EOR methods (polymer, surfactant, SP flooding, steam injection, SAGD, in situ combustion, gases injection) and a simple but robust economic model providing a set of default technical and economical input values. Risk analysis is performed on these technical and economical results using either a deterministic or a probabilistic approach. The outcome of this roadmap is at field scale, for a given EOR method, an expected additional recovery factor and the corresponding discounted NPV with an uncertainty analysis on the main technical and economical parameters.
- Asia (1.00)
- North America > United States (0.46)
- North America > Canada (0.28)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE Russian Oil & Gas Exploration & Production Technical Conference and Exhibition held in Moscow, Russia, 16-18 October 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.
Abstract A method for ranking hydrocarbon reservoir with the zoning objects on the basis of geological knowledge and the economic efficiency of hydrocarbons production is proposed. For a ranking of hydrocarbon reserves, they are conventionally divided into four categories: profitable, contingently profitable, potential and non-commercial. Hydrocarbon reserves of reservoirs and fields are allocated to the categories, taking into account the geological, technological and economic criteria. The result is a ranking of information about the structure of the reserves for the planning of drilling, well intervention and the allocation of areas for pilot projects. The same information can be used to calculate the possible profiles of oil production in a different order involvement in the development zones of various categories of reserves and, thereby, to determine the optimal scenario of field development.
- Reservoir Description and Dynamics > Reserves Evaluation (1.00)
- Production and Well Operations (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (0.70)
- Management > Asset and Portfolio Management > Field development optimization and planning (0.49)
Abstract A number of researchers put on attention on nanoparticles suspension (nanofluids) as part of nanotechnology application in enhanced oil recovery (EOR) nowadays. This experimental study is preliminary stage of nanofluids for EOR project at NTNU. This paper presents the investigation of interfacial tension reduction, nanoparticles retention and permeability impairment in porous media by injecting nanoparticles suspension into glass micromodel. The deposition and pore-blockage of nanoparticles in glass micromodel were investigated and microscopically visualized by taking sequential images. A hydrophilic nanoparticles and synthetic seawater (brine, NaCl 3 wt. %) as base fluid were chosen in this study. The nanofluids were made with various concentration from 0.1 to 1.0 wt. %. The sonicator as liquid homogenization tool was used just before injecting the nanofluids into glass micromodel to avoid agglomeration. A dynamic interfacial tension (IFT) phenomenon has observed during this experiment. Introducing dispersed nanoparticles in brine has reduced dynamic IFT. It will decrease when increasing nanoparticles concentration. Theoretically, it makes oil easier to move out since the friction force between water-phase and oil-phase will also decrease (Afrapoli, 2010). Based on microscopic visualization from glass micromodel, it observed nanoparticle has deposited and adsorbed at surface pore network. In permeability measurement, it reduced 41–72% after injected with nanoparticles. Dynamic light scattering analysis is also performed for nanoparticles entrapment analysis. Another nanoparticles which has bigger average size and lower specific surface area, showed similar behavior with previous nanoparticles suspension. However the permeability reduction is less around 17–21% at similar nanofluids concentration. In conclusion, this phenomenon of nanoparticles transport process possibly occurs due to its deposition on pore surface and blockage in pore throat of glass micromodel. This study provides essential knowledge for us of nanoparticles behavior in pore media before going further experiment stage to as EOR method.
- Europe (0.94)
- Asia (0.68)
- North America > United States (0.49)
- Research Report > New Finding (0.91)
- Research Report > Experimental Study (0.61)
First Channel Fracturing Applied in Mature Wells Increases Production from Talinskoe Oilfield in Western Siberia
Kayumov, Rifat (Schlumberger) | Klyubin, Artem (Schlumberger) | Yudin, Alexey (Schlumberger) | Enkababian, Philippe (Schlumberger) | Leskin, Fedor (TNK-BP) | Davidenko, Igor (TNK-BP) | Kaluder, Zdenko (TNK-BP)
Abstract In the last two decades, hydraulic fracturing has become a routine completion practice in most oilfields producing from the low- and medium-permeability Jurassic formations in western Siberia. To optimize hydraulic fracture conductivity, operators and service companies were progressively decreasing polymer loading in fracturing fluids, developing new polymer-free fluids, implementing foams as fracturing fluids, increasing proppant size and concentration, enhancing polymer breaker performance, increasing breaker concentration, and implementing the tip screenout technique. All these methods have some positive impact on proppant pack conductivity but lead to higher risk of premature screenout. The intrinsic limitations stem from the fact that conductivity is created by the proppant pack, which physically limits permeability. The new channel fracturing technique allows development of an open network of flow channels within the proppant pack; thus, the fracture conductivity is enabled by such channels rather than by flow through the pores between proppant grains in the proppant pack. The channel fracturing technique is capable of increasing fracture conductivity by up to two orders of magnitude. Talinskoe field, located near Nyagan, Russia, produces from a series of Jurassic sublayers at depths of 2270 to 2700 m. Several oil-saturated sandstone sublayers are separated by shale barriers, and their development is conducted separately. For some wells, production from bottom sublayers JK10 and JK11 became uneconomical due to injection water breakthrough or low liquid rates. Production in these wells was switched to upper layers JK2 through JK9 after perforation and stimulation operations. Five of these wells were stimulated with the channel fracturing technique. Six-month of post-frac production data were compared with production data from eight offset wells stimulated recently via conventional hydraulic fracturing. The wells stimulated with the channel fracturing technology showed an average productivity index about 51% higher. This production effect still remains positive. The absence of screenouts confirmed reliability in proppant placement observed in other projects worldwide. The successful implementation of the channel fracturing technique in brownfield development is described in detail with a theoretical and operational review, results from laboratory experiments, and analysis of the production results in comparison with conventional fracturing.
- Europe (1.00)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug (1.00)
- North America > United States > Texas (0.94)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.34)
- North America > United States > Wyoming > Green River Basin > Jonah Field (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- (10 more...)
Abstract This paper describes some of the major issues around drilling world class ERD wells in the North Sector of the Caspian Sea by a team of industry professionals from Lukoil, Schlumberger, Eurasia Drilling Company (BKE-Shelf) and Rostechnadzor (RTN). The ultimate goal of the well construction organisation is to deliver quality wells with zero environmental impact. Drilling performance achieved on Korchagina field has considerably improved despite increased complexity of the wells. Key contributing factors to this success are in-depth understanding of well bore stability by 3D geomechanical modeling, comprehensive directional analysis, revised casing design, application of latest drilling technologies and creation of multi-discipline team with common goals.
- Europe > Russia > Volga Federal District > Volga Basin (0.89)
- Africa > Tanzania > Indian Ocean > Nyuni Island > Ruvuma Basin > Rufiji River Delta > Nyuni Block > Neocomian Sandstones Formation > Nyuni-2 Well (0.89)
Positive Comparison of LWD Data Acquired With and Without Chemical Radioactive Sources in the Vankor field, Russia, Paves the Way for Radioisotope-Free Formation Evaluation
Majidi, A.. (Schlumberger) | Plyuta, A.. (Schlumberger) | Alexandrova, A.. (Schlumberger) | Bourg, L.. (Schlumberger) | Reichel, N. J. (Schlumberger) | Malyasov, V.. (Vankorneft) | Zhadan, G.. (Vankorneft)
Abstract Safety issues, tightening of environmental regulations, and efficiency are among many reasons the petroleum industry has long searched for a way to acquire standard formation evaluation measurements without the use of chemical radioactive sources. Pulsed neutron generator (PNG) technology provides electronically controlled pulses of neutrons. This radioisotope-free source of high-energy neutrons has been in use for decades in wireline-conveyed logging tools for various commonly used measurements such as neutron porosity, spectroscopy, and thermal neutron capture cross section (sigma). For several years, a ruggedized PNG technology that performs under the harsh shock and vibration conditions of an LWD tool operation has allowed these measurements to be made while drilling. Recent developments have extended the suite of measurements to include a radioisotope-free bulk density measurement. In conjunction with the other PNG-related formation measurements, this makes it possible to perform comprehensive formation evaluation without chemical radioactive sources. The sourceless neutron-gamma density (SNGD) measurement is initiated by neutrons, in contrast to the standard gamma-gamma-density (GGD) measurement. The high-energy neutrons from the PNG experience inelastic collisions with the atomic nuclei of atoms surrounding the tool. The gamma rays emitted as the nuclei return to the ground state create a distributed gamma ray source in the formation. These gamma rays then experience Compton scattering in the same way as gamma rays emitted from the chemical radioactive source used for the standard GGD measurement. The count rate of detected gamma rays at a gamma-ray detector at a distance from the PNG is proportional to the electron density of formation, which is then transformed to bulk density in the standard manner. This study compares the new sourceless neutron-gamma density measurement with the traditional source-based bulk density measurement, both of which were acquired in the same well in the Vankor field, Siberia, Russia. Conditions encountered include oil, gas, shale, bad hole, and coal-bearing intervals. A comparison of the final petrophysical analysis derived from the traditional source-based density and the new sourceless SNGD measurement is also made. Our evaluation indicates a positive comparison between density recorded using a chemical radioactive source and neutron-gamma density recorded using a PNG without a chemical radioactive source.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.52)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (0.35)