Eliseev, D. (LUKOIL-Nizhnevolzhskneft) | Golenkin, M. (LUKOIL-Nizhnevolzhskneft) | Senkov, A. (LUKOIL-Nizhnevolzhskneft) | Latypov, A. (Schlumberger) | Bulygin, I. (Schlumberger) | Ruzhnikov, A. (Schlumberger) | Buyanov, M. (Schlumberger) | Kashlev, A. (Schlumberger)
In 2015, LUKOIL-Nizhnevolzhskneft developed two intelligent multilateral (TAML 5) wells in the Korchagina field in the Caspian Sea—a first for LUKOIL and Schlumberger, the company's service provider. The development of offshore fields is difficult, requiring nonstandard procedures and solutions, including the use of new technologies to construct multilateral wells. This paper describes the approach to designing these wells with TAML 5 intelligent completions in conditions where there is a high risk of gas and water breakthrough. The main objectives for this type of completion were extending the production period before catastrophic gas breakthrough, increasing the drainage area by drilling several drains, and, as a result, increasing total oil recovery.
The formation of Korchagina field is an oil rim with height of 20 m located between the massive (up to 90 m) gas cap and bottom edge water. In the majority of wells (usually extended-reach drilling (ERD) wells), the first three months of production see gas breakthrough, drops in oil production, and the gas/oil ratio (GOR) reaching values up to 5,000 m3/m3. To reduce the rate of gas breakthrough and delay water breakthrough, a new well design was proposed featuring the following technologies: dual-lateral production wells with a TAML 5 junction; active monitoring of inflows from each lateral in an interval of the junction by using multiposition valves hydraulically controlled from the surface; pressure and temperature sensor system that enables real-time tracking of the formation conditions in the drainage area of the laterals, estimates flow rate from each lateral, and interprets the obtained data to determine reservoir parameters.
The first TAML 5 intelligent well had a very stable flow regime with a flow rate of more than 400 tons of oil per day. GOR and water cut showed a better dynamic when compared to offset wells in the field, where gas and water breakthrough was observed. One of the main reasons for this was the ability to control drawdown in each of the laterals by using multiposition valves installed in the pressure-tight junction. When compared to the standard monobore well drainage area, boundaries have been considerably extended. At the same time, production was achieved with much lower drawdowns than for wells with a single lateral, while maintaining the same flow rate. As a result of smaller reservoir and tubing pressure differences, the speed of the water and gas vertical movement significantly slowed down, even with the proximity of gas-oil contact (GOC) and oil-water contact (OWC) to the wellbores.
The second TAML 5 well was sidetracked from the existing well. Prior to sidetracking, the well was producing with high GOR (more than 2,000 m3/m3) and low flow rate. After the sidetrack was drilled and completed, total GOR decreased by 75% while the production rate increased more than 3 times. The main reason for such a positive change was the increase in coverage ratio, as well as the redistribution of the drawdown between and along the laterals.
In both wells, the intelligent completion enabled real-time drawdown redistribution to respond to changes in well production during the life of the well. The use of a pressure-tight TAML 5 junction is relevant for any field with an active gas cap.
This manuscript provides the details of the development, justification, and field-testing of this new approach for the development of offshore fields by using multilateral intelligent wells and a pressure-tight TAML 5 junction to substantiate the advantages and benefits of this technology.
Salyaev, Vadim V. (Rosneft) | Sitdikov, Suleyman S. (Rosneft) | Nuykin, Andrey M. (Rosneft) | Arzamastsev, Georgiy G. (Rosneft) | Pilgun, Pavel S. (Rosneft) | Safin, Ayrat F. (Rosneft) | Gashimov, Roman R. (Rosneft) | Susoev, Anton S. (Rosneft) | Gruzdov, Dmitry (Schlumberger) | Gromovenko, Alexander (Schlumberger) | Kapkaev, Alexander (Schlumberger) | Rezanov, Ivan (Schlumberger)
The pdf file of this paper is in Russian.
Well completion using technology enabling to improve performance and life time is an important objective in the development of PK1 productive reservoir of North Komsomolskoye field. The main challenge of the development of this productive horizon lies in the fact that the reservoir is shallow (1,120 m TVD) and consist of poorly consolidated sandstone, which results in massive production of solids during operation. In addition to that, proximity of GOC and WOC together with high oil viscosity in reservoir conditions results in early gas and water breakthroughs when using standard completion technology.
Basic PK1 formation characteristics could be found in
Remote location of the field and impossibility to use all-year-round road transport of materials, equipment and personnel are additional operating problems which had to be resolved to ensure that the project is delivered successfully and without extra costs.
Main questions which the project team had to deal with:
What is the long-term solution to limit solids production at target drawdown to a level that would be safe for pumps and surface facilities?
How to prevent early water and gas breakthroughs?
How to drill a long horizontal section in poorly consolidate rock without any incidents knowing that previously several wells were lost in this zone due to well caving during drilling?
To tackle these problems, we chose a completion technology for the open horizontal section using screens equipped with autonomous inflow control devices (AICD) and inflow tracers. To ensure sand control, we injected gravel packing in the annular space between the screens and the open well bore. In addition to that, we built a 1D rock mechanic model to calculate well bore stability.
During the project execution we drilled 2 long horizontal sections without any incidents; tested completion technology with gravel packing (well A) and without gravel packing (well B); obtained the planned oil inflows; confirmed that the approaches adopted can be successfully used in the Full Field Development.
Given all the particular features of the field and the well design, this operation can be rightly considered one of the most complex onshore operations that have been performed in the Russian Federation.
Varfolomeev, I. (Schlumberger Moscow Research) | Yakimchuk, I. (Schlumberger Moscow Research) | Denisenko, A. (Schlumberger Moscow Research) | Khasanov, I. (Gubkin Russian State University of Oil and Gas, National Research University) | Osinceva, N. (Gubkin Russian State University of Oil and Gas, National Research University) | Rahmattulina, A. (Gubkin Russian State University of Oil and Gas, National Research University)
The aim of the work is the study of structural and textural parameters of sedimentary rocks with application of wide complex of modern technical instruments including mathematical and software methods for data acquisition and processing. We have considered the capabilities of investigation of mineral content and its spatial distributions in thin section by using of two imaging techniques with different resolution and nature of registered signal. It confirmed the need for complementary study of the data of various physical methods.
Vavilin, V. (Branch of LLC, LUKOIL–Engineering, KogalymNIPIneft, Center of Core Analysis and Reservoir Fluids, Kogalym) | Kolpakov, V. (Branch of LLC, LUKOIL–Engineering, KogalymNIPIneft, Center of Core Analysis and Reservoir Fluids, Kogalym) | Romanov, Y. (Branch of LLC, LUKOIL–Engineering, KogalymNIPIneft, Center of Core Analysis and Reservoir Fluids, Kogalym) | Pustoshkin, R. (Branch of LLC, LUKOIL–Engineering, KogalymNIPIneft, Center of Core Analysis and Reservoir Fluids, Kogalym) | Galiev, T. (Branch of LLC, LUKOIL–Engineering, KogalymNIPIneft, Center of Core Analysis and Reservoir Fluids, Kogalym) | Kunakasov, A. (Branch of LLC, LUKOIL–Engineering, KogalymNIPIneft, Center of Core Analysis and Reservoir Fluids, Kogalym) | Urazgulov, R. (Branch of LLC, LUKOIL–Engineering, KogalymNIPIneft, Center of Core Analysis and Reservoir Fluids, Kogalym)
The purpose of our work – is to show our version of determining the strength properties, elastic modules and compressibility factors at reservoir conditions on the example of rock fields OOO "LUKOIL–Western Siberia". This paper briefly shows a method of measurement and processing of the results. The paper also shows some results of the determination of dynamic and static elastic moduli of rocks (Poisson's ratio, Young's modulus, shear modulus, compressibility, ultimate strength, elastic limits). This article also shows some results of a comparison of dynamic and elastic Young's modulus.
Static deformation and strength characteristics of the rock were determined by direct measurements of the longitudinal and transverse strains. All measurements were made at reservoir conditions by increasing the axial load until destruction of the sample. The rate of deformation changes was no more than 1.5 • 10-6 s-1, reservoir pressure and temperature were maintained automatically with a high degree of accuracy. Static deformation and strength characteristics are the most reliable, and reflect real properties of both homogeneous and heterogeneous anisotropic rocks.
In our laboratory, on by our optimized measurement method were performed investigations of dynamic and static strength properties of more than 500 rock samples from different oilfields of OOO "LUKOIL–Western Siberia". Our Company has received a very valuable information about the rocks in the form of diagrams "Stress–Strain," of Mohr's circles, elastic limits, ultimate strengths, elastic modulus, graphs of compressibility factor and Biot's coefficients depending on the pressures. It should also be noted that we have not been able to find any general and uniform dependence (laws) in all studied formations and fields, between dynamic and static elastic moduli. For solving of some specific tasks (for example, a field development, design of hydraulic fracturing) and for obtaining high–quality and reliable results on the rock mechanics we need use only static strength characteristics of rocks identified at true reservoir conditions.
Our methodology is based on the American Standard ASTM D 3148–93, and the results of our experimental work and the measurement procedure (Owner's Manual) for our equipment, taking into account the specific properties of sedimentary rocks of OOO "LUKOIL–Western Siberia". For concrete oil formations studied fields of OOO "LUKOIL–Western Siberia" we had found quite close links between the dynamic and static Young's modulus. Such petrophysical links is possible to use for obtaining more important information from the results of rocks research by dynamic method.
Currently, oil companies are actively using dual completion and production systems (DCPS/DS). In the case of using this technique fluids of two formations are mixed in the wellbore. Two formations are being operated simultaneously by one well. For better control on the oil recovery from both the formations a reliable and prompt product sharing technique is necessary nowadays. Rheological and optical properties of natural and recombined hydrocarbon mixtures have been investigated whithin the research. Recombined mixtures have been produced by mixing oil samples of different reservoirs. These studies are aimed at solving inverse problems, i.e. for product sharing problem.
Abdul-Latif, Benson Lamidi (Saint Petersburg Mining University) | Dziwornu, Christian Kwesi (Saint Petersburg Mining University) | Phu Ha, Nguyen (Saint Petersburg Mining University) | Riverson, Oppong (Gubkin State Oil And Gas University)
Most secondary recovery projects are usually not commenced in a gas or oil reservoir until dictated by the reservoir depleting pressure or by the gas-oil-ratio (GOR) or declining productivity index of the reservoir. During this process it is required to effectively disperse an injection pattern to prevent the oil banks from fleeing away from the production wells. Gas condensate reservoirs usually are produced using primary depletion techniques, which averagely is inefficient for producing the valuable liquid components in the form of condensed liquid. Though the most common approach used to improve liquid productivity in gas condensate reservoirs is the method of recycling produced gas through the reservoir, this technique is economically not friendly due to the fact that larger discounts are usually applied on gas sale values for delayed selling. This paper presents a technique of improving liquid productivity in gas condensate wells by keeping the reservoir pressure above the dew point pressure. Water injection in a gas condensate simulation model with equal well spacing patterns in five- and seven-spot developmental patterns is used.
Simulation results showed that continued water injection resulted in optimum hydrocarbon recovery of 15% and 27% respectively of initial mass higher than primary depletion for gas condensate reservoir with condensate gas ratio of 190 STB/MMscf and 300 STB/MMscf. These results vividly demonstrate that waterflooding of gas condensate wells can perhaps be used as an effective improved oil recovery technique.
Prisyazhnjuk, M. A. (PermNIPIneft Branch of LUKOIL-Engineering LLC Office in Perm) | Filatov, M. A. (PermNIPIneft Branch of LUKOIL-Engineering LLC Office in Perm) | Nikulin, S. E. (PermNIPIneft Branch of LUKOIL-Engineering LLC Office in Perm) | Sabelnikov, I. S. (PermNIPIneft Branch of LUKOIL-Engineering LLC Office in Perm)
In the conditions of the current economic situation many oil fields face the acute problem of achievement of economic profitability for new well drilling and commissioning. Well drilling at the absence of required studies and detail analysis of the current condition of development in the situation of multi-layered and heterogeneous oil strata can fail to provide the expected increase of oil yield and even reduce the oil recovery factor of strata significantly. Comprehensive analysis of all available information about the field (laboratory, seismic, geophysical, hydrodynamic surveys) with further specification of the geological and hydrodynamic model are required for improvement of the quality of design and efficiency of drilling of designed wells. The main purpose of this work is justification of well drilling direction with horizontal laying on the basis of a permanent geological and technological model (PGTM).
Sudakov, V. (Kazan Federal University) | Nurgaliev, D. (Kazan Federal University) | Khasanov, D. (Kazan Federal University) | Stepanov, A. (Kazan Federal University) | Khamidullina, G. (Kazan Federal University) | Kosarev, V. (Kazan Federal University) | Galukhin, A. (Kazan Federal University) | Usmanov, S. (Kazan Federal University) | Zaripov, A. (JSC Tatneft) | Amerkhanov, M. (JSC Tatneft)
The pdf file of this paper is in Russian.
Currently the super-viscous oil deposits are under active development in the Republic of Tatarstan. The general method of production is Steam-Assisted Gravity Drainage (SAGD).
The problem of creation the complex of methods to monitor and control the reservoir processes caused by steam injection is of a great importance for increasing the development efficiency.
Traditional control methods of shallow deposits development are normally based on seismic survey and whether insufficiently adatped for shallow deposits of super-viscous oil or very expensive. Thus, the special modifications of geophysical methods are required.
The paper discusses general approaches used for creation of complex of methods for steam chamber monitoring the oil production from the shallow deposits of super-viscous oil by SAGD. The methods developed include seismic and geoelectric survey.
In context of integrated monitoring technique creation the set of special core survey was conducted to define the possibility of detection of the steam chamber distribution by seismic methods. The distinguishing feature of the monitoring technology developed is the use of downhole monitoring tools to receive the seismic signal and to perform the geoelectrical field establishing.
The article contains the description of the seismic data obtained processing methods and the results of the seismic data interpretation.
The study was made with the financial support of Ministry of Education and Science of the Russian Federation (project ? ?02.G25.31.0170)
Levanov, A. N. (Tyumen Petroleum Research Center) | Smirnov, A. S. (Tyumen Petroleum Research Center) | Komkov, A. E. (Tyumen Petroleum Research Center) | Klinovaya, Y. S (Tyumen Petroleum Research Center) | Anuryev, D. A. (Tyumen Petroleum Research Center) | Musin, R. A. (Verkhnechonskneftegas) | Gorbatko, E. A. (Verkhnechonskneftegas)
Nowadays, geological and simulation models are an essential tool used for design and support of oil and gas field development. At the same time, creation and application of models is technically complex and requires nontrivial approaches and solutions. This paper describes the experience of application of modeling for support of drilling and development optimization of one of the largest fields in Eastern Siberia.
A distinctive feature of the publication is a compilation of tools of geological and simulation modeling, including experience in dealing with applications for the period from the start of field development to the achievement of the maximum hydrocarbon production.
Approaches to creation and rapid response updating of geological and simulation models of a complex productive formation are described. These models incorporate a large number of different geophysical data and are used for a rapid response to field development and production drilling support.
The value of the work lies in the integration of a large set of geophysical and field data into a single geological and simulation model and its further effective use.
Bazhenov Formation (BF) is a complex study target, not only in terms of getting the flow of oil, but also in terms of studying and parameterization of its implementation on the basis of complex laboratory tests. "Standard" approaches to core studies are not applicable to the BF due to the destruction of rocks over time from exposure to air and liquids. Specialists, who analyze core material, are often encounter a lack of manufacturing capabilities of conditioned samples required for the measurement of physico-chemical and estimation parameters.
The purpose of this work is to optimize the operations with core material from source rocks on the territory of the company Gazprom Neft PJSC, which are aimed at maximum recovery of geological information while ensuring the best preservation of core material.
To address this objective it is required to perform an integrated approach for analysis of the core material at all stages - from the selection of suitable coring technologies, operations with a core "in the well" and transportation of the core to the laboratory to selection of the optimal sequence (algorithm) of the sample preparation and laboratory tests, depending on the set of commercial applications.
It is assumed that the section of the BF can be divided into a series of intervals formed by rocks, differing from each other by physico-chemical and filtration parameters. One group of intervals may be involved in the development by creating a pressure differential in the well-reservoir system, the second - by creating artificial fracture network by applying the fracturing technologies, the third will be the result of thermal effects on the rock. A list of studies was compiled on the basis of the basic assumptions of non-uniform vertical structure of the section of BF, that allows addressing a series of commercial tasks: how intervals with different properties are spread in the sections of the BF, the presence of movable hydrocarbons, filtration-capacity parameters range of intervals. To implement a list of studies, that take into account these features, "a roadmap" for research was composed, including the required handling procedure for core material.
The work shows the influence of the selection of technology, transportation, storage and sample preparation methods on the amount and quality of information obtained from geological core material of source rocks in Western Siberia.