Сейсмические исследования неравномерности открытой трещиноватости и неоднородности флюидонасыщения геологической среды для оптимального освоения месторождений нефти и газа

The goal of oil and gas field development is to maximize the benefits of exploitation work. In some large oilfields entering the mid-to-late development stage, to maximize the input-output ratio of oilfield exploitation, in oilfield development work, you will receive Due to the influence of many interference factors, in the field of oilfield exploitation, it is necessary to reduce the economic cost of oil and gas field exploitation as much as possible and continuously improve the economic benefits of oilfield mining units. In the mid-to-late production of oil and gas fields, the use of big data to establish a reasonable and scientific production plan for oil fields and an effective decision support system provide an important guarantee for the development and production of oil and gas fields in the middle and late stages. Through the use of effective production-increasing technology and production decision-making, comprehensively consider some oilfield mining areas and newly-added resource mining areas, comprehensively optimize and set up the development of oilfield resources in the middle and late stages and use big data technology to develop oilfields. Among them, the resource advantages are effectively transformed into economic advantages, in order to provide a good work plan for the middle and late stages of oilfield development.

The development of major oil fields requires considerable primary resources consumptions. Vast use of land, water and energy, negative technogenic impact influence considerably on natural environment in local and regional aspects. Implementation of improved oil recovery (IOR) methods demands additional use of energy, expensive oil displacement agents, skilled personnel, specialised equipment etc. Multicriteria analysis of oil recovery processes by use of primary resources allows to estimate the complex efficiency and rate of natural environmental impact. To achive the solution of multipurpose problem of. rational resources consumption in course of oil fields development procedure of optimization and compromise programming is carried out. The significance of used natural resources in different geographical regions is determined by environment protection expert analysis. Natural environment systems in such regions as the North of the West Suberia and the Kaspean lowland are very sensitive to the processes of oil and gas fields development. The permafrost conditions and easy spoiled land fertile cover, the danger of earth subsidence and possible technogenic seismicity demand thorouth analysis of oil recovery projects applicability and their environmental safety. Complex efficiency assessment and multicriterion optimization of primary resources consumption have been done for the design versions of development of large oil fields Russkoe and Tengiz. Analysis of verious IOR methods on the basis of primary and energy resources consumption allows a better choice of natural environment saving technology and shows the direction and necessity of their further improvement. Study of possible technogenic effects caused by oil field development is of prime importence for timely prevention from negative consequences for nature in the region.

In the world, with the development of science, brand new technologies are being created to generate energy resources (e.g., hydrogen energy, electric car, etc.). These inventions will reduce the consumption and cost of hydrocarbon resources. This leaves oil and gas resource producers with only one option – accelerated development of oil and gas fields with low capital investment. This monograph is devoted to the development of oil and gas fields in a short period of time with a reduction in the volume of drilling operations and well quality by at least 50%. The developed technology of simultaneous split operation will give an impetus to volumetric production of hydrocarbons, accelerated field development and reduction of capital investments, as well as lead to the production of all recoverable and non-recoverable reserves from the subsoil. This monograph also delves into the technological aspects of operating wells in the Altyguyi gas condensate field. The scientific work examines the operational and technological aspects of hydrodynamic and thermohydrodynamic studies. To support this research, patents for invention No. 643 and 644, dated January 6, 2015, were obtained (application numbers 14/101317 and 15/101320). These patents cover the “Simultaneous method of separate and joint operation of several productive horizons by one chink and device for its realization” and the “Method of dual oil and gas production from one well in a multizone”. Based on the findings of the conducted analyses, studies, and calculations, the implementation of the intensification of the gas condensate field using the oil and gas DC method by one well is justified. This approach represents a first in global practice and aims to reduce capital investments and accelerate development.

The Poseidon project aims at developing technology for subsea multiphase development of offshore oil and gas fields. This paper shows the potential of this technology through three synthetic North Sea field examples. The investment cost may be reduced by 10-40% using multiphase technology. Realizing this technology with an unmanned wellhead platform concept or a subsea (Poseidon) concept may give neglible cost differences. The main technical areas of concern are listed and some conclusions are drawn as to the future use of multiphase technology. THE POSEIDON PROJECT The Poseidon project was started in 1984 as a cooperation between Institut Francais du Petrole (IFP), Total and Statoil. The aim of the five year project is to develop the technology for subsea development of deepwater oil and gas fields. The concept, fig. 1 includes subsea wells, subsea multiphase pumps and long distance multiphase pipelines. In this project, IFP has developed a multiphase pump. An industrial prototype of this pump will be tested in a flow-loop, outside Lyon late 1988. Total has developed the subsea station and put main emphasis on full-scale test of an electric motor for the multiphase pump. This motor was tested in 150 meters of water outside the west coast of Norway in the autumn of 1987. Statoil's part of the work has been the pipeline system. A computer program for dynamic simulation of multiphase flow has been developed and used to study slugging phenomena and transient behaviour during start-up and shut-down of the pipeline. Moreover, numerous tests have been performed to study hydrate formation in flowing media as well as corrosion and erosion in the presence of oil, gas water and sand. Special consideration has been given to corrosion under sand beds and inhibitor efficiency in the roof of pipelines carrying mainly gas. Instrumentation for reservoir monitoring and control of pump inlet conditions have been studied. Finally, Statoil has headed the field concept studies in which also personnel from Total and IFP have taken part. This paper will present some of the conclusions from these studies. CONVENTIONAL OIL AND GAS FIELD DEVELOPMENTS Fig. 2 shows the functions included in a conventional field development. To arrive at new concepts it is necessary to consider if all these functions are necessary and where the accompanying equipment should be placed. Apart from the pipelines, the main part of the equipment and therefore also the investment and operating costs are connected to well control/manifolding, separation and pumping. Well control and manifolding are always necessary. The question is therefore whether the equipment should be placed on a platform or on the sea bottom. The equipment for separation and pumping is today always placed on a platform. Platforms for water depths of 70 to 500 meters, as in the Norwegian part of the North Sea, tends to be very large constructions, fig. 3. The Gullfaks C platform, which will be installed in 220 meters of water depths late this year, will cost in the order of 18 billion NOK.

As an essential resource in the process of national economic development, oil and gas has a very important strategic position. As a non-renewable resource, various countries and regions attach great importance to the development and use of oil and gas resources. Generally, oil and gas resources are buried deep underground and are the most critical resources in geological exploration. Reservoir development is a very important work, in the development process involves a lot of professional content, if the development is not reasonable, there will be some geological problems. Therefore, this paper chooses reservoir engineering geological problems in oil and gas field development as the research object, first expounds the impact of reservoir geological characteristics on oil and gas field development, then analyzes the existing problems, and finally proposes corresponding solutions to improve the quality and efficiency of oil and gas field development.

During the development of oil and gas fields, the permeability of the reservoirs decreases due to a decrease in reservoir pressure and an increase in effective pressure, as a result of which significant reserves of oil and gas remain in the reservoir. To predict the rate of decrease in oil production rates during field development and to respond quickly, it is necessary to know the law of permeability decrease with an increase in effective pressure. Existing methods for describing the change in the permeability of rocks were analyzed in the paper. Numerical analysis of the results of core studies from previously published papers and the results of field well testing on the examples of the north Perm region oil fields showed that in both cases, regardless of the type of rock and the type of reservoir, the change in permeability can be described by the same equations (exponential and power-law). Obtained equations can be used to predict changes in the permeability of terrigenous reservoirs of the north Perm region oil fields. At the same time, according to the results of well testing, an intensive decrease in permeability is observed with an increase in effective pressure. Analysis of the nature of permeability changes using the Two-Part Hooke’s Model showed that significant irreversible deformations are currently taking place in the formations of the oil fields under consideration. Predicting the change in permeability from effective pressure can allow to optimize the development of oil deposits.

A Poseidon Multiphase Pump has been installed and is present running on Statoil Gullfaks A platform in the North Sea, giving additional pressure to one of the wells. The main objective of this work has been to qualify the Poseidon Booster Technology, technically and operationally, and to prowide a reliable and industrial tool for multiphase boosting, either sub sea or installedtopside a platform. The paper gives a brief summary of the project and describes the Poseidon pump, the platform installation and outlines the experience and results from the ongoing qualification test. The Gullfaks booster as delivered by Framo Engineering AS, has up to January 7995 accumulated 2400 running hours. The booster is fully integrated into the production systems on the platform. The daily operations are carried out from the central control room by the ordinary platform star. The objectives of the test program have so far been successfully fulfilled. Multiphase booster technology combined with prograss in multiphase flow technology WIV have a significant impact on development and production of smaller oil and gas fields that today are assumed to be non- profitable. Introduction Background A Poseidon Multiphase Booster System, P301, was in 1994 installed on Statoil?s Gullfaks A platform in the North Sea, and is presently providing additional pressure to one of the platform wells. At the same time, the multiphase booster is undergoing a six months qualification test program. The fabrication of the Gullfaks multiphase booster represents the industrialisation stageof a long term development plan for the Poseidon technology. This technology may prove to be a low-cost alternative for developing smaller oil and gas fields in thefuture. This work is the final stage of a long term R&D program that dates back to 1984. The Poseidon project started in 1984 when the two oil companies, Statoil and Total in collaboration with IFP (Institute Petrole du Francais), established the Poseidon Group with the objective to develop cost effective multiphase boosting and transportation technology. One of the successful results from this R&D program was the Poseidon multi phase booster pump. (1) The development of the Poseidon booster technology was organised into three different stages. (Fig. 1) The first stage was the R&D period with development of theory and design tools and model testing in laboratory scale. The second stage covered design and construction of a full scale prototype and was finished with installation and testing in an oil and gas field in Tunisia, Sidi El Itayem. The third stage has been this industrialisation and qualification of the Poseidon pump. Pre-qualified pump manufacturers have been invited to tender. One pump should be build in Norway and one pump in France. Thecontract and a production license was awarded to:Framo Engineering, Norway for a pump to be installed at the Gullfaks A, andSulzer Pumps for an installation on the Pecorade field in France. Thus, two Poseidon pumps have been build last year, and both have been subjected to a six month testing program under real life operating field conditions.

Chapter 3 - Marine Petroleum (Gas) Engineering and Equipment

Background One of the key tasks of the Russian oil industry is the modernization of oilfield equipment for the development and operation of oil and gas fields. In this regard, the improvement of pumping systems on the basis of technology hydraulic piston long-stroke pumps is an important and urgent task. Aims and Objectives Justification of hydraulic piston pump applicability for deep depth oil production. Methods Theoretical studies Results The technological scheme of hydraulic piston long-stroke pump is designed and method of the hydraulic regime calculation is developed.

On-line monitoring technology for internal corrosion of CO2-EOR oil field

As one aspect of flow assurance considerations, severe slugging control strategy in deepwater riser is related to the safety of production system, therefore it’s of great significance to the development of deepwater oil and gas field. This paper summarizes commonly used severe slugging control methods briefly, then takes certain deepwater oil and gas field as an example to introduce the method of software simulation for making severe slugging control strategy of deepwater riser. Firstly the model is built with basic information such as pipeline route, production profile and fluid composition. Data of typical years is used to simulate flowing conditions to determine whether it’s within slugging zone. To mitigate slugging conditions, choking, gas lift and choking& gas lift combined methods are chosen and simulated based on the oil and gas field characteristics, and according to the results gas lift is suggested as the best solution. Factors such as riser type, gas injection location, and flexible riser depth are analyzed for better gas lift efficiency. Finally hydrate formation risk related to severe slugging is analyzed and the slug catcher size is checked. Based on the introduced software simulation procedure, severe slugging control strategy is made, which will be valuable for deepwater flow assurance design and study.

More than 60% of gas reserves in the Middle East region are regarded as sour. The development of sour oil and sour gas fields or originally sweet oil fields, which undergo a souring process during production live, impose significant investments for the H2S treatment and increase significantly the field operation costs. In order to evaluate the origin and development of the H2S in a production system multiple locations covering all process stations such as down hole, well head, separators, gathering stations, pipelines have to be sampled an analysed. The in-field measurements of the H2S concentrations and various laboratory analyses like S34 / S32 isotope ratio, CSIA, DNA sequencing, MPN and Bacterial growth tests could be performed in order to provide a conclusive picture of the H2S contamination. The most promising and cost efficient technology is the analysis of the bacterial activity using DNA analysis and bacterial growth tests. The integration and interpretation of all above mentioned analysis types is key for the evaluation of the origin and development of the field souring process and provides a robust analytical basis for remediation, scavenging and mitigation operations. In combination with modern dynamic reservoir modeling tools, which allow the history match and forecast of the field souring process, the efficiency of mitigation or scavenging operations in the subsurface and at the surface can be simulated and optimized. In context with the envisaged production enhancement, the application of EOR technologies and the souring of several reservoirs due to injection, the monitoring and handling of additional H2S production become an important environmental and economic factor.

On the path of development of Iran, Oil industry is like a two-edge razor. It has earned revenue for the country, but on the other hand, it leads undeniable damage to the environment. Undoubtedly, the pollution of the environment imposes additional cost to the country and the inclusion of these costs in the development of oil and gas fields is inevitable. The issue of preserving the environment is addressed in the Iranian constitution explicitly and the government is responsible for implementing this law, while this law has been neglected in the oil industry. This study tries to answer this question why the performance of the National Iran Oil Company as a representative of the government on the subject of environmental issue was not suitable? Game theory as an analytical tool has been used to answer this question and the methods to improve the performance of the NIOC in the environmental issue. The method including the ways of formulating an oil contract and educational and investment policies.

Water-based drilling solid-liquid waste is the most common environmental pollutant in the process of oil and gas exploration and development. Due to leakage or untreated discharge, these drilling solid-liquid wastes enter the atmosphere, water bodies, and soil, and cause serious pollution to the surrounding ecological environment. At present, how to reduce the heavy metals and other toxic and harmful components in water-based drilling solid-liquid waste, make it meet the discharge standards or recycle it is a major problem that plagues the sustainable development of oil and gas fields. This article introduces the sources and characteristics of water-based drilling solid-liquid waste, summarizes the domestic research status of solid-liquid waste treatment technology for foreign water-based drilling, analyzes the characteristics and advantages of drilling waste non-landing technology treatment. It is pointed out that it is necessary to adopt drilling water-based solid-liquid waste non-ground treatment technology in the exploration and development process of oil and gas fields in Northwest China, and it has good application prospects.

CO2 flooding, as a commonly employed enhanced oil recovery (EOR) method today, is characterized by high oil displacement efficiency, environmental friendliness, and economic viability, and has been extensively developed and applied in oil and gas field development. During CO2 flooding operations, gas channeling frequently occurs within the reservoir due to significant permeability contrasts arising from formation heterogeneity, coupled with the low density and viscosity of CO2. This phenomenon can adversely affect the normal productivity of oil wells. With the advancement of CO2 flooding technology, the effective prevention of CO2 channeling has become crucial for improving oil recovery. Gel particle plugging systems, being economically viable and efficient, exhibit favorable stability, adaptability, and strength, leading to significant applications in oilfield development and demonstrating promising prospects for future development. This paper comprehensively reviews the classification and developmental status of gel particle systems used for channeling control in CO₂ flooding. It introduces the mechanisms of several gel particle types, including preformed particle gel, polymer microspheres, and dispersed particle gel, and examines their current development status both domestically and internationally. Furthermore, future research directions and application prospects are discussed.