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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.

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.

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.

Problems of oilfield and geophysical control over oil and gas fields development are for more than 10 years conventionally solved by using modern complex of nuclear methods. This complex includes pulse neutron logging (2INGK, 2INNK), carbon-oxygen logging (INGKS), spectral gamma-ray logging (SGK). Well logging equipment of the complex with merchandise mark TsSP is successfully being developed in OJSC SPE VNIIGIS in association with LLC SPE INGEO and is used for service performance in order to support oil and gas companies in Russia as well as CIS and far abroad countries. At the moment. the complex is competed by a new development such as 3INGKS, which realizes standard technology of 2INGK, neutron capture gamma-rays spectrocsopy for estimation of rock elemental composition, including weight content of hydrogen and chlorine, and also natural gamma-radiation spectrometry (U, Th, K). TzSP-2INGKS tool is 76 mm in diameter and can be used in boreholes of small diameter, including sidetracks and horizontal holes

One of the real challenges facing the oil industry in Egypt now, is to keep up production and maximize reserves especially in mature oil fields. The application of artificial lift systems to improve the productivity, whilst ensuring the most effective use of the existing reserves, should optimize the petroleum resources. A total of 137 oil and gas fields were placed on production since the oil industry in Egypt started in 1910. Currently there are 122 oil and gas fields on stream, among which 9 are gas production fields and the other remaining 113 are producing oil from 1311 oil wells. The natural producing wells are representing 15%, while the gas lifted wells are 24% and the pumped wells are 61%. This paper presents the philosophy and the methodology of applying artificial lift system in the Egyptian oil fields. Pending on the production forecast and the expected well behavior and also the effects of applying the secondary recovery mechanism either by water flood or gas injection. Also the problems encountered on well behavior are analyzed and solutions are suggested. Special emphasis is given to the marginal oil fields artificial lifting systems, because of the economical limitation accompanied with such field's development costs. The concept is not only to equip a well with a cost effective means of artificial lift to be able to continue production, but also to manage the reservoir behavior for the maximum oil recovery.

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.

Calcium Carbonate (CaCO3) is one of the most common scales in oil field operations. Various fluids (brine, oil and gas) can mix in the reservoir and/or wellbores under drastically varying sets of thermodynamic, kinetic and hydrodynamic conditions that will affect the carbonate scale forming tendencies. Many of these critical conditions are ignored in today's oil field operations as far as calcium carbonate scale is concerned. Presently, the mechanisms of CaCO3 scale formation, as conceived by the industry, considers only the liquid brine phases. The flashing of gases from both the oil and the brine phases is critical for the CaCO3 scale formation. Pertinent aspects of this flash process are generally ignored. In addition, the complete mechanism of the CaCO3 must also consider the partitioning of gases (particularly CO2) between the liquid oil and brine phases during the entire gas flash process. This means, the formation of CaCO3 can not be determined by considering only the brine phase as attempted by the industry. Instead, the entire three-phase PVT behavior (oil/brine/gas) and associated CO2 partitioning must be considered to determine the CaCO3 scale formation in an oil field. The existing and published models on the CaCO3 formation consider only the basic thermodynamics of the brine phase and totally ignore the critical effects of the oil phase behavior on this scale formation. This automatically means that the oil industry can not adopt any of the existing scale models without serious modifications to account for the unique effects of the oil phase. The main variables dictating the location and amount of calcium carbonate scale deposition in an oil field are as follows: Pressures and temperatures at any location within the entire system.The brine and oil compositions prior, during and after the reservoir fluids have been exposed to temperature and/or pressure changes.The bubble point and pertinent flash behavior of the three-phase oil/brine/gas system as a function of pressure and temperature.The distribution of CO2 between oil and brine phases and the drastic variations of this CO2 partitioning prior and during any production operation.The constant variation of the water(brine)/oil ratio ("WOR"), the gas/oil ratio ("GOR") and the gas/water(brine) ratio ("GWR") during any production operation. These reservoir and production variables at various locations in the production system may change constantly as a function of location and time during any type of production operation within a given field. These critical variables are not considered in their entirety in the existing and most frequently used CaCO3 scale prediction models. In the present paper, the problems of calcium carbonate scale formation in oil field operations (primary, secondary, and tertiary production modes) are critically discussed. The various effects of the gas distribution (especially CO2) between oil and brine phases under reservoir and various production conditions are delineated as far as CaCO3 scale is concerned. Some algorithms are given. Finally, the paper discusses a methodology which can be used to predict CaCO3 under all field conditions as a function of the water composition, pressure, temperature, ‘VOR", "GOR", "GWR", total CO2 in the system and CO2 partitioning between the various liquid phases. The methods and problems of obtaining all the required input information in order to apply this or similar models for site-specific oil field operations will be discussed in detail. PVT and CO2 partitioning data obtained through some recent work with three-phase fluid systems from California oil fields will be used to illustrate the complex CaCO3 scale behavior in an oil field.

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

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.

With the development of economy and the fluctuation of international crude oil price, people are more and more concerned about the economic benefits of oilfield development. At present, most of the domestic oil fields have entered the middle and late stage of development. With the increase of water cut and decline of production, the economic benefits vary greatly, and some single Wells and block incomes are not enough to make up for their production costs. How to carry out economic evaluation, provide basis for production and operation decision, and seek the best economic benefit is the first problem that must be studied and solved in the development of oilfield quality benefit. Single well and block benefit evaluation system is applied in this article, combined with the most oil field in recent years, the crude oil output, production cost, sales income, etc. comprehensive analysis and evaluation has been developed single well, block, formulate corresponding measures and countermeasures, to guide the oilfield production and operation, inefficient, invalid next block and single well comprehensive treatment has a positive meaning.

The production of sulfide by sulfate-reducing bacteria (SRB) in oil and gas fields causes problems including enhanced corrosion risk, reservoir plugging and deterioration of product quality. Injection of nitrate or nitrite stimulates heterotrophic nitrate-reducing bacteria (hNRB), which compete with SRB for oil organics, such as volatile fatty acids (VFA). Nitrate also stimulates nitrate-reducing, sulfide-oxidizing bacteria (NR-SOB), which lower sulfide levels. Nitrite is a strong and specific inhibitor of the SRB enzyme responsible for sulfide production, whereas nitrate does not inhibit SRB. Hence, injection of nitrate or nitrite can prevent or remediate problems in the oil and gas industry caused by SRB activity, provided hNRB and NR-SOB are present. A survey of 8 oil fields, 2 gas storage reservoirs and an oil storage tank indicated that SRB and hNRB were widely distributed, whereas the distribution of NR-SOB appeared more limited. The SRB and hNRB were able to use lactate, as well as VFA as electron donor for sulfate or nitrate reduction. However, the order of use of VFA components appeared to differ with acetate being used preferentially by hNRB and propionate and butyrate being used preferentially by SRB. The production of nitrite by hNRB and NR-SOB varied greatly with quantitative conversion of nitrate to nitrite (up to 30 mM) being observed in one case; the nitrite formed was then reduced further. Samples from a high temperature North Sea oil field had thermophilic SRB, but no hNRB or NR-SOB activity, causing sulfide production to be inhibited by nitrite only. Although nitrite appeared to react chemically with sulfide under these conditions, causing all nitrite to disappear within 100 h, the observed inhibition was long-lasting (>500-1500 h). Hence, nitrite can be used successfully to control SRB activity in fields where hNRB and NR-SOB are absent. In summary, it appears that many oil and gas fields contain hNRB and NR-SOB populations, which are activated upon injection of nitrate or nitrite, allowing sulfide remediation in situ. Characterization of these populations as described in this paper may allow prediction whether these injections will be successful and whether use of nitrate or of nitrite is preferred.

At the end of April 1983, there were 3,088 active oil and/or gas fields in the state of Oklahoma, as well as 32 officially named abandoned fields, according to the Nomenclature Committee of the Mid-Continent Oil and Gas Association. Oil and/or gas fields are located in 73 of Oklahoma's 77 counties, and represent over 4 million acres (1.5 million ha.) in surface area. The Oklahoma Geological Survey has prepared a new, up-to-date map of all officially named oil and/or gas fields in the state, at a scale of 1:500,000. Each field is outlined, assigned an index number for reference, and designated by color code as either an oil field, gas field, or combination oil and gas field. As an improvement over oil and gas field maps available from commercial sources, the OGS has attempted to define better the geographic boundaries of each field. An alphabetical listing of all fields with their reference numbers and locations is featured on the map, along with a listing of smaller fields that have been combined into Oklahoma's major oil and gas trends. The map is designed for use as a reference by all oil and gas professionals in the state. The OGS oil and gas field map has been prepared in conjunction with the development of a computerized oil and gas field file for Oklahoma. Production of updated versions of the map in future years will be facilitated by digitization of information shown on the present map. End_of_Article - Last_Page 459------------

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Abstract The paper provides an approach to the use of reservoir simulation in North Sea oilfield development. The use of simulators prior to field production is a departure from traditional application and the authors have sought to illustrate that reservoir simulation models can be a relevant part of an overall field development strategy. The models are used to evaluate alternative production schemes and can be upgraded into operating tools as more field information becomes available. Introduction In this paper we will review the application of reservoir simulation models in assessing reservoir development alternatives for North Sea oilfields. In recent years the vast exploration budgets allocated to the search for North Sea petroleum resources have resulted in the petroleum resources have resulted in the successful discovery of new offshore oil and gas fields. Many of these fields lie in water depths between 300 and 700 feet and are located in parts of the North Sea notorious for harsh weather. The focus of activity is now changing to some extent from exploration to development of these resources. Such development requires large capital expenditure and early return on investment. It is necessary to order development platforms and production equipment soon after initial field discovery, when only a limited amount of data is available from exploration wells. The huge investments required for field development justify the need for management to base plans on the fullest technical appraisals that are possible within the narrow time frame; appraisals that recognize the limitations of the available data and effects of different interpretations of the data. To this end, reservoir simulation models are being used to optimize development soon after the field is discovered. Sophisticated computer methods are used for solving the mathematical equations that describe fluid flow in a grid system that represents the physical parameters of the reservoir. The equations are generally non-linear and require numerical solution with the aid of high speed computers.