Abaltusov, Nikolay (Weatherford) | Sukhanov, Aleksandr (Weatherford) | Zaripov, Emil (Weatherford) | Orlov, Dmitriy (Tyumenneftegaz) | Enikeev, Ruslan (Tyumenneftegaz) | Pitsyura, Evgeniy (Tyumenneftegaz)
The purpose of the work performed is to show the possibility of using geosteering not only for achieving geological targets but also for supporting directional drilling operations in multilateral wells. Drilling of multilateral "fishbone" design well in complex terrigenous section of Pokur suite in Russkoye field is reviewed as an example. Three kickoff operations with the use of Rotary Steerable System were carried out in an open hole when drilling a horizontal section of the well under review. The well logs of the previous hole were used for optimal selection of the kickoff point. To control the distance to the reservoir boundaries a 3 layers parameter inversion (based on azimuthal resistivity data) was used in addition to density and porosity sensors. As a result of the operations performed, the optimal conditions for kicking off with the Rotary Steerable System, were identified within the geological structure of Russkoye field. Geosteering in real time was successfully used not only for solving geological issues, but for directional drilling as well: optimal kickoff depths were selected for laterals, the trajectory was followed according to the plan; the problems related to bit deflections when the laterals exit the main productive formation were avoided. The geological targets were delivered as well: the length of the hole in the target formation totaled 98.9%.
This seminar will teach participants how to identify, evaluate, and quantify risk and uncertainty in everyday oil and gas economic situations. It reviews the development of pragmatic tools, methods, and understandings for professionals that are applicable to companies of all sizes. The seminar also briefly reviews statistics, the relationship between risk and return, and hedging and future markets. Strategic thinking and planning are key elements in an organisation’s journey to maximise value to shareholders, customers, and employees. Through this workshop, attendees will go through the different processes involved in strategic planning including the elements of organisational SWOT, business scenario and options development, elaboration of strategic options and communication to stakeholders.
Decisions in E&P ventures are affected by Bias, Blindness, and Illusions (BBI) which permeate our analyses, interpretations and decisions. This one-day course examines the influence of these cognitive pitfalls and presents techniques that can be used to mitigate their impact. Bias refers to errors in thinking whereby interpretations and judgments are drawn in an illogical fashion. Blindness is the condition where we fail to see an unexpected event in plain sight. Illusions refer to misleading beliefs based on a false impression of reality.
This paper describes the specifics of oil production and the recommendations developed for the operation of horizontal wells (hereinafter Hz wells) in unconsolidated reservoirs with highly viscous oil with the purpose to increase the efficiency of reserves recovery, based on the interpretation of pilot project results.
The depletion of the majority of mature fields with the best reservoir properties and the easiest extracted reserves determines the necessity of involvement in the elaboration structurally complex reservoirs of different kind.
Among them a special place occupy laminated sands, which can contain and produce oil and gas. However, ther is a number of problems associated with determination of their reservoir properties, reserves volume and effective development.
In this context PK formation of Russkoye field in Western Siberia is the classical example of such kind of objects (pic.1.). The main problem is that the shale microlayers are not resolvable on the logging curves, as their thickness is much less than the resolution of the main well logs. The logging methods characterize integral rock properties (sandstone and shale alternation). The usage of classical approach does not allow determine the real properties of sandstones, and net thickness estimated by conventional log evaluation is not real, as it contains impermeable shale microlayers.
Lachugin, Denis (OJSC) | Edelman, Inna Yakovlevna (Rosneft) | Shandrygin, Alexander (Gazprombank) | Aksenov, Maxim Anatolevich (OJSC) | Lachugina, Yuliya (OJSC ) | Abramochkin, Sergey (Schlumberger IPM-SPM) | Davidovskiy, Alexander Olegovich (Schlumberger Logelco Inc)
The Russkoe oil and gas field was discovered in 1968. It is one of the biggest and complex fields in Russia. It has yet to be put to production, however the development is already concerned by a number of geological and operational issues, such as high crude viscosity, remote location (beyond the Polar Circle), considerable heterogeneity, compartmentalization of poorly cemented sandstones as well as the presence of extensive gas cap, bottom water, and thick permafrost zone.
OJSC "Tyumenneftegaz", a subsidiary of Rosneft, has been responsible for the pilot works to seek operational solutions for full-field development. Intensive pilot wells drilling and testing have been performed since 2007 in different zones of the field. In 2009-2012 23 wells, including 16 horizontal ones, were drilled in these pilot areas. Additionally cold and hot water injection tests have been conducted in one of the pilot areas. The main goal of these studies was to learn and reduce geological risks and to find an effective system for full-field development.
The article presents the data and results of pilot operations as well as the methods and equipment for monitoring of the pilot works including multi-phase measurements of flow rates of producers using Vx tool, measurements of flow rates of injectors, tests of injectivity/inflow profiles in horizontal sections using DTS and PLT systems, measurements of bottom hole pressure dynamics and parameters of PCPs and ESPs using high precision metering systems.
Effectiveness of different control and monitoring methods and of different production technologies has been analyzed. As a result applicability of these methods for the development of viscous oil fields under difficult weather conditions has given using the example of the Russkoe field.
Russkoye field is a unique field containing strategic volumes of hydrocarbon reserves. The pilot projects that lasted more than 20 years show its complexity and ambiguity: high viscosity oil, unconsolidated reservoir, thick gas cap, bottom water, location in the Arctic environment determine the objectives of the seismic, geophysics, development, production and exploitation studies.
This paper announces the key uncertainties that exist in the field and were taken into account to form the current vision of the project solutions for its development: determine principal production profiles, count and mutual location of production and injection wells, consider lateral heterogeneity through an adaptive development system, meeting the critical operating conditions.
Although conventional rod driven Progressing cavity Pumps (PCPs) have been in use since the early 1980's, the industry has continued to seek alternative methods of powering the system. Initial Attempts were made using conventional electric submersible induction motors however their high synchronous speeds proved to be problematic. these inherent high speeds resulted in developing motors with more poles (hence a slower synchronous speed) as well as down-hole gear boxes. All of this was in an attempt to get the motor speeds down to an acceptable range whereby the progressing cavity pump would work successfully. Using Submersible Permanent Magnet Motors (PMM) rather then conventional Induction Motors (IM) to drive the PCP is an effective and efficient method directly powering the PCP as well as elimination the need for a downhole gear. In addition the PMM motor's power density is much higher, thus the motor length is significantly shorter which enhances deployment of the system in deviated wells. Over 1000 PCP-PMMs have been successfully installed in several Russian fields in differing applications with more then 250 still in operation. Their average run life exceeds 200 days and is typically in the range of 360-600 days with a maximum run time of 1091 days. This paper will share numerous case histories on PCP-PMM installations by providing a general review of the application, a summary of the PMM-PCP components installed and the overall design approach that led to the long term success.
Russkoye heavy oil field is located in the northern part of Siberia. The field was discovered in 1968. It is characterized by the huge reserves: more than 1.3 billion tonn of oil in place and remote location (the field is located to the north from the polar circle). Main challenges for the field development are: unconsolidated formation, gas cap, high heterogeneity of formation, permafrost zone and heavy oil.
This paper covers latest experience (2007-2012) obtained during field development pilot project implementation at the representative part of the Russkoye field. Pilot stage results will be used for the further field development strategy building. Effectiveness of different approaches has to be estimated, considering specifics of the field. Traditional field instrumentation did not provided reliable data for the analysis. New technologies (such as fiber optic distributed temperature sensors, specifically adopted multiphase metering etc.) were implemented for the building of the proper data acquisition system. During the pilot stage specific injection schedules, cold and hot water injection, various well completion applications were implemented. Depletion rate estimation based on real production data, determination of critical drawdown and numerous well testing activities including conventional buildup/drawdown pressure transient analysis and interference testing were made. Special attention is paid to the comparison of the cold and hot water injection and to the methods of control/monitoring of the well production. Monitoring and effectiveness estimation of the tested technology should be based on flow rate measurements data (MPFM), distributed pressure and temperature sensors (DP/TS) in horizontal production wells. Numerous new technologies were used for the pilot project. Paper describes approaches for integrated data acquisition implementation; development techniques comparison and new technologies adaptation workflow to the specific field conditions. New technologies application allowed to see specific field behavior and to estimate effect of various field development and management approaches tested.
The results obtained during the pilot project will be used for the Russkoye field development planning, technical solutions will be implemented for the field monitoring and managing. Successful development of the first biggest heavy oil field should lead to initiation of development of other numerous challenging heavy oil fields in Russia.
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 predefined 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.