Reservoir Pressure Maintenance Research Articles

USE OF A NEW MISCIBLE AGENT AS A PERCEIVED NEED FOR UZEN OIL FIELD DEVELOPMENT

The Uzen oil field development (in the West of the Republic of Kazakhstan) over a long period is carried out with the miscible agent use, in which the Caspian Sea water is used. Due to the urgency of the problem of optimizing the enterprise costs and minimizing the risks of oil production loss, it became necessary to switch to another miscible agent for the following main reasons: significant costs for repairing wells due to active corrosion of underground equipment (aggressive water of the reservoir pressure maintenance system; using sea water (the main water pipeline length is 150 km, from the city of Aktau; the water pipeline is in poor technical condition to ensure stable and requires constant repair and restoration work); the shortage of oil production due to the frequent interruption of the seawater supply. To determine the possible source of «external» water for technological needs and injection into the reservoir pressure maintenance system of the Uzen oil field, unprepared sea water from the city of Aktau (the current situation) and albenomanskaya water of the Uzen oil field were considered. The article presents the precipitation study results when mixing reservoir and injected water in the conditions of the Uzen oil field. The chemical analyzes results of various water samples are presented and summarized, and the compatibility of their mixtures is assessed experimentally and calculatedly by mixing waters at temperatures of 36 °C and 60 °C with a shutter speed of 24 hours. Studies with samples from the following objects were carried out: water, formation water from GU-74 and GU-80. According to the laboratory research results, flooding of albsenomanian water is preferable to seawater and is cost-effective, since it is characterized by the maximum NPV value. The balance reserves of the ground- water of the albsenomanian aquifer system for the reservoir pressure maintenance system of the Uzen oil field are approved for a 27-year service life and are sufficient. An action plan was developed for switching to albsenomanian water with the implementation of all the necessary preparatory work.

ПОДХОД К АВТОМАТИЗИРОВАННОМУ ФОРМИРОВАНИЮ НОРМ ВРЕМЕНИ НА ТЕХНИЧЕСКОЕ ОБСЛУЖИВАНИЕ СРЕДСТВ КИПиА, АСУ ТП И СООРУЖЕНИЙ СВЯЗИ ПРЕДПРИЯТИЙ НЕФТЕГАЗОВОЙ ОТРАСЛИ

Актуальность исследования обусловлена необходимостью постоянного обновления и пересмотра стратегии повышения общей экономической эффективности предприятий нефтегазовой отрасли путем оптимизации затрат на проведение мероприятий технического обслуживания критически важных контрольно-измерительных приборов и автоматики (КИПиА), оборудования автоматизированных систем управления технологическим процессом (АСУ ТП) и сооружений связи. Цель: разработать научно обоснованный подход к автоматизированному формированию норм времени на техническое обслуживание оборудования КИПиА, АСУ ТП и сооружений связи предприятий нефтегазодобывающей отрасли, позволяющий сократить время и повысить общую эффективность процесса планирования технического обслуживания. Объекты: технологические установки добычи нефти и газа, подготовки, перекачки и хранения нефти и газа, поддержания пластового давления, трубопроводного транспорта, контролируемые и управляемые с помощью оборудования АСУ ТП, оснащенные различными приборами КИПиА; сооружения связи: радиорелейные и спутниковые системы связи, проводные системы связи, волоконно-оптические линии связи, телефонные станции, транковые системы связи, системы видеонаблюдения и сигнализации. Методы. Для автоматизации процесса формирования норм трудозатрат на техническое обслуживание нового оборудования используется метод классификации оборудования по категориям технической сложности. Результаты. Разработана методика автоматизированного расчета нормативов трудозатрат на техническое обслуживание оборудования предприятий нефтегазовой отрасли, основанная на категориях технической сложности. Определены требования к модулю формирования базовых норм трудозатрат информационной системы управления техническим обслуживанием, выполнена соответствующая программная реализация. На основе предложенной методики сформированы базовые нормы трудозатрат на техническое обслуживание средств АСУ ТП, КИПиА и сооружений связи ОАО «Томскнефть» ВНК.

Prospects of long-term development of Shebelynka gas-condensate deposit in conditions of stocks recovery

The work is aimed to study the gas recovery stabilization prospects in Ukraine on the existing deposits due to renewable processes concerning gas reserves. The article reviews and analyzes the main results in the Shebelynka gas condensate field (GCF) development from the point of view of its water flooding.It is possible to restore the gas reserves in the assumption that they are being developed due to the gas flow from deep horizons. In detail, all factors are taken into consideration, which influences the formation pressure in the process of deposits development. The work presents analysis of the water pressure system in the Shebelinka GCF, the results of the calculation of reserves of edge water (water pressure system of the field is limited), investigates the dynamics of water flooding (intrusion of water in gas deposits) and the role of capillary forces in slowing down the advance of the water front. It was shown that water flooding practically does not affect the development of gas depletion, and the reservoir pressure-decline rate is slowing down both under the influence of known factors and due to the flow of gas through tectonic disruptions, especially in the core deposit. It is proved that when the annual gas consumption is reduced to 1800-1900 million 3, it will be fully compensated by the crossflow of gas. The graphic forecast of gas recovery till 2040 is presented in variants without compressor and compressor opening since 2019, taking into consideration the reserves stock. It has been calculated that with introduction of the planned new compressor station at Shebelinka GCF annual gas production in the period of 2020-2040 will be maintained at 2.4-2.1 billion cubic meters and additional gas extraction for the period 2019-2036 is - 6.5 billion m3. During the development of the field, depression between the main reservoir and the deep horizons of carbon will increase, that might increase the volume of gas crossflow and accelerate the degassing of the Earth, taking into account presence of macro- and micro-tectonic faults. Considering the possibility of a long-term development in the Shebelinka GCF, it is necessary to pay special attention to the fund of wells, its updating, repair or use as a means for receiving the heat from the Earth. The phenomenon of restoration of gas reserves at the Shebelinka GCF, which was established by researches, is promising for other deposits of Ukraine and needs further special researches, on separate objects. Object of research: Shebelinka gas condensate field. Gas extraction and processes for maintaining reservoir pressure, including through the gas crossflow of gas from the deep horizons of tectonic disturbances. Subject of the study: Analysis and forecast of gas production in the future for various options for development, both compressor and non-compressor exploitation of the deposit, taking into consideration maintenance of reservoir pressure and stock reserves.

Физические основы работы ингибиторов коррозии в системе поддержания пластового давления

Физические основы работы ингибиторов коррозии в системе поддержания пластового давления

Применение насосов объемного действия плунжерного типа в системе поддержания пластового давления

Применение насосов объемного действия плунжерного типа в системе поддержания пластового давления

ТЕХНОЛОГИЯ ОПТИМИЗАЦИИ ФОНДА СКВАЖИН СИСТЕМЫ ПОДДЕРЖАНИЯ ПЛАСТОВОГО ДАВЛЕНИЯ НА ОСНОВЕ ГИБРИДНОГО МОДЕЛИРОВАНИЯ

ТЕХНОЛОГИЯ ОПТИМИЗАЦИИ ФОНДА СКВАЖИН СИСТЕМЫ ПОДДЕРЖАНИЯ ПЛАСТОВОГО ДАВЛЕНИЯ НА ОСНОВЕ ГИБРИДНОГО МОДЕЛИРОВАНИЯ

Peramalan Kinerja Lapangan SNP Dengan Injeksi Air Menggunakan Metode Material Balance

The decline in production from of a field is the common problem in the oil and gas industry. One of the causes of the decrease in production is the decline of reservoir pressure. Based on the analisis result, it was found that SNP field had a weak water drive. The most dominant drive of the field was fluid expansion. In order to reduce the problem, a reservoir pressure maintenance effort was required by injecting water. In this research, the effect of water injection to reservoir pressure and cumulative production was analyzed. From the evaluation result, it was found that the existing inejection performance using one injection well to Zones A and B was not optimum. Because, the recovery factor was predicted to 29.11% only.By activating the four injection wells, the recoverty factor could be increase to 31.43%.

Selection of Optimal Design of a Universal Device for Nonstationary Pulse Pumping of Liquid in a Reservoir Pressure Maintenance System

A universal downhole device for continuous pulsed pumping of liquid in a reservoir pressure maintenance system is developed. A mathematical model of the device and a derivation of expressions for determining the main basic working output parameters are given. The results of theoretical studies are compared with bench tests of the device. The effectiveness of the device in non-stationary flooding in the pressure maintenance system is demonstrated based on previously conducted scientific studies. Preliminary positive data on commercial use of the device at Rosneft oil fields in 2015–2016 are given.

PRODUCTIVE STRATA FLOODING ENERGY CONSUMPTION AT EXTRACTIVE ENTERPRISE AS A COMPLEX SYSTEM

Background The technological processes of the oil and gas industry are characterized by high energy intensity. Pumps are the prevailing technological electric drive equipment. The operation of the waterflooding system, along with the well equipment of mechanized oil production, determines mainly the efficiency of the development of oil and gas fields, the share of electricity for the operation of the waterflooding system at the late stage of development can reach 30 % of the total energy balance of the oil field. Aims and Objectives Study the questions of development of a hierarchy in the structure of consumption of electric energy in the system of maintaining pressure in productive reservoirs of deposits. Ranking the places of occurrence of energy costs in the waterflooding system, taking into account additional criteria will allow to optimize the flow of investments for the implementation of energy efficiency improvement measures. Methods The structure of the energy balance of the field is developed on the basis of data bases of technological parameters of exploitation of the oil field for 5 years. The multicriterial problem of vector optimization of the subsystem ranking has been formulated, a 4-dimensional space of particular features for 7 subsystems of the reservoir pressure maintenance system has been developed. At the preliminary stage of ranking the subsystems, a method of forming the Pareto set is used. The restriction of the Pareto set is realized by an additive convolution, the validity of which is proved by the homogeneity of particular characteristics. Results On the example of one of the deposits of the Republic of Sakha, the energy structure of the oil flooding system is developed. The shares of electric power consumption for overcoming the hydraulic resistance of all links in the system of ground and underground infrastructure and energy losses in pumps are determined. The systematization of the internal links of the subsystems determined the multi-level hierarchical appearance of the structure of the waterflooding system. A set of Pareto-optimal subsystems is formed on the basis of the 4-dimensional vector of particular features. As a result of the scalarization of the vector of quotients, the subsystems of the waterflooding system are ranked.

ALGORITHM FOR THE CALCULATION OF ENERGY EFFICIENCY INDICATORS OF MAINTAINING RESERVOIR PRESSURE SYSTEM EQUIPMENT

Implementation of energy saving measures is impossible without reliable assessment of energy efficiency indicators of operating process equipment of the entire complex and its facilities. The article proposes an algorithm for calculating these indicators in relation to reservoir pressure maintenance systems (PMS) at oil production facilities. The most energy consuming equipment of PMS systems are pumping units for various purposes: high-pres-sure pumps for pumping water into the reservoir, low-pressure back-up pumps, submersible electric centrifugal pumps for water extraction wells for PMS, and others, depending on the particular process scheme. The paper considers the factors influencing the formation of energy efficiency indicators, as well as the parameters necessary for the calculation, taking into account the limitations of the primary source data and the frequency of their collection. The developed algorithm determines the methodology for calculating such significant indi-cators as actual and normative power consumption, actual and normative specific power consumption for a separate pumping unit and the entire pump block, the actual efficiency of the pumping unit and the pump block, and, as a consequence, the current energy effi-ciency of the pump unit and the pump block as a whole. The proposed algorithm can be implemented in an information and analytical program to automate the calculation process with the required periodicity and issue calculated data for the formation of analytical information and plan further actions to take measures to improve efficiency.

RESERVOIR PRESSURE MAINTENANCE BY WATER INJECTION INTO HORIZONTAL WELLS AT THE CONDITION OF THE GEOLOGICAL UNCERTAINTY IN CONTINENTAL DEPOSITS OF HIGH-VISCOSITYOIL OF PK1-3 FORMATION OF THE VOSTOCHNO-MESSOYAKHSKOYE OIL FIELD

The article considers the problem of correct organization of the system of reservoir pressure maintenance by water injection into PK1-3 formation of the Vostochno-Messoyakhskoye oil field that has many geological uncertainties. To remove these uncertainties the authors offered the pilot well program of flooding system and detailed proposals for data diagnosis obtained during this program that will help to determine the most correct approach to the flooding system for this type of reservoirs.

WATERFLOOD-INDUCED FRACTURE ON THE INJECTION WELLS IN LOW-PERMEABILITY RESERVOIR OF ACHIMOV SEQUENCE

Achimov sequence is characterized by high heterogeneity and low reservoir properties, that makes it impossible economically profitable field development without hydraulic fracturing and usage reservoir pressure maintenance systems. The research aims to develop recommendations for regulating the operations of injection wells, in conditions of waterflood-induced fracture formation. The recommendations can be used to further regulate the waterflooding system for the conditions of Achimov sequence.

HISTORY OF NON-STATIONARY WATER FLOODING TECHNOLOGY DEVELOPMENT AT KUMKOL OIL FIELD

In the article introduction and development stages of non-stationary waterflooding technol-ogy are considered at Kumkol oil field example. It is shown that the history of non-stationary waterflooding application at Kumkol oil field allows to determine the main trends of technology development. The application of non-stationary waterflooding begins as pilot-industrial work on a designated site. In this case, most often begin with the application of cyclics, i.e. all injection wells simultaneous discon-nection/activation of the site during the half cycle period. The analysis of the results of pilot-industrial works makes it possible to decide on the extension of the sections or on the application of non-stationary waterflooding on the entire site (oil field). In this case, the experience of managing the operation of injection wells in a batch mode without complica-tions in the reservoir pressure maintenance system is analyzed. During the time passing, the efficiency of the cyclic water injection technology starts decreas-ing, that needs using new types of non-stationary waterflooding. At the Kumkol oil field, the cyclic mode was replaced by non-stationary waterflooding + change in the direction of the filtration flow due to the selection of injection wells groups, each of which operates in its mode. However, this technology also begins «aging» with time and efficiency reduces. Further development of non-stationary waterflooding is associated with a combination of cyclic water injection and high-water-producing wells periodic operation. This direction of non-stationary waterflooding has great flexibility and can be constantly modified.

Регулирование заводнения для повышения эффективности системы поддержания пластового давления

Регулирование заводнения для повышения эффективности системы поддержания пластового давления

INTEGRATED MONITORING OF HORIZONTAL WELLS WITH MULTISTAGE HYDRAULIC FRACTURING AT THE IMPLEMENTATION STAGE WITHIN THE PRIOBSKIY OIL FIELD FOR THEIR WORK EFFECTIVENESS

Background. Priobsky license area is one of the largest in terms of assets production of Oil Company Rosneft», as well as the leader in the number of initiated pilot industrial tests and pilot works (PW). It was within the framework of the PW that the first clusters were drilled by horizontal wells and carrying out multistage hydraulic fracturing of the reservoir (HW with MHF), which resulted in the decision to introduce them massively throughout the Priobsky license area. Like any new technology at the implementation phase, the technology of HW with MHF in its realization stage also requires optimization solutions, and it may take years to evaluate the effectiveness of these decisions. Aims and Objectives. There considered issues related to: • creation of an integrated system for monitoring HW with MHF for determining the effectiveness of their operation; • increasing the effectiveness of the HW with MHF. Rezults. There proposed the approaches to create the system of monitoring and analysis of the effectiveness of HW with MHF at the implementation stage, as well as a primary assessment of problem wells with a view to further increasing their efficiency through the implementation of measures. The optimal variants of the formation of a reservoir pressure maintenance system (PMS) and the timing of mining in injection wells for clusters with different geological conditions are determined. The calculated terms of transfers are already used for an operative assessment of the appropriateness of transfers of directional wells in the PMS at a number of fields. Optimal quantities of MHF stages and proppant loading on HW are determined depending on different geological conditions. The actual implementation of the first three wells with an increased number of stages of MHF confirmed the success of this direction.

Water-Injection Operations and Gas-Injection Sensitivities in the Bakken Formation

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 185030, “Improved Oil Recovery in Tight Oil Formations: Results of Water-Injection Operations and Gas-Injection Sensitivities in the Bakken Formation of Southeast Saskatchewan,” by S.M. Ghaderi, C.R. Clarkson, and A. Ghanizadeh, University of Calgary, and K. Barry and R. Fiorentino, Crescent Point Energy, prepared for the 2017 SPE Canada Unconventional Resources Conference, Calgary, 15–16 February. The paper has not been peer reviewed. Although improvement in hydraulic-fracture properties and infill drilling remains the focus of recovery enhancement from the Bakken, low oil recoveries and steep initial decline rates are experienced in primary-recovery operations, even after application of multifractured-horizontal-well technology. Therefore, many pilots have been executed to determine the viability of waterflooding for maintaining oil rates and improving recoveries through reservoir-pressure maintenance and sweep-efficiency enhancement. This paper presents the performance results from one of the waterflood pilots in the Viewfield Bakken. Numerical-Model Setup A section of the Bakken reservoir (the geology of which is described in detail in the complete paper) deemed to be representative of the waterflood performance in Viewfield is considered for modeling. This section has been developed by use of multifractured horizontal wells completed in the Middle Bakken (main target reservoir) with a well spacing of 200 m (eight wells per section, named A through H). All eight wells started oil production within a similar time frame, and, after approximately 1 year of production, every other well was converted to a water injector. Reservoir-Fluid Model. Conventional pressure/volume/temperature (PVT) analysis was conducted by a commercial laboratory on 12 surface-separator oil and gas samples. Recombination of fluids at reservoir temperature (156.2°F) yields a final gas/oil ratio of 810 scf/STB. Subsequently, a series of constant-composition-expansion and differential-liberation tests was conducted on the recombined fluid to determine oil-saturation pressure, oil-formation-volume factor, oil density, and oil and gas viscosity as a function of pressure. The Peng-Robinson equation of state and modified Pedersen viscosity correlation were tuned to replicate the PVT properties of oil and gas as a function of pressure. Reservoir Grid Model. On the basis of the well tops and reservoir net-pay values, reservoir structure for the study area was generated. It is known that the minimum horizontal stress is aligned in the northwest direction and at approximately 50° with respect to the east/west horizon. Therefore, reservoir gridding is rotated at this angle to mimic the hydraulic-fracture orientation along the horizontal-well laterals. Grid size in the horizontal direction is 65×65 ft, and the total thickness of the reservoir is approximately 28 ft, which is divided into nine layers of equal thickness.

Field Life Extension in Abu Dhabi Through Hybrid Development Concept

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 181598, “Prospective Unlocking of Future Reserves in Offshore Abu Dhabi: Field-Life Extension Through Hybrid Development Concept,” by T. Nakashima, SPE, D. Ouzzane, SPE, G. Dudley, SPE, and M. Al-Marzouqi, ADMA-OPCO, prepared for the 2016 SPE Annual Technical Conference and Exhibition, Dubai, 26–28 September. The paper has not been peer reviewed. Field A, a giant field consisting of many subreservoirs, is offshore Abu Dhabi and has produced for 50 years, mainly through peripheral water injection. A long-term development plan (LDP) for the field aims to extend the production plateau by 25 years through infill drilling and waterfloods. This paper describes an approach for optimizing the number and type of drilling centers required to enable the development plan to be flexible in design to accommodate infrastructure, facilities, drilling, and subsurface constraints. Introduction Field A, a giant carbonate field, has been developed for 50 years. As the field reaches maturity, it moves to another phase of development. Design of the next development phase, the LDP, began in the early 2010s. The LDP assessment stage, which screened the surface and subsurface development concept, was recently completed, and the development planning team is preparing for the selection stage. The assessment-stage conclusion was for drilling from artificial islands (AIs), wellhead towers (WHTs), or a combination of both and leaves a degree of freedom. This paper describes the optimization approach of the drilling-center options. The LDP is just the first phase of a large-scale long-span offshore reservoir redevelopment that aims for a further 50 years of production. The complexity of the field is significant because of limited seabed space, the age of the existing surface facilities and pipelines, and challenging drilling circumstances. These complexities differentiate the development project from other offshore projects, and an appropriate selection of drilling centers is one of the more important keys to project success. Field and Development History The field of carbonate reservoirs is in shallow water. The field is 40×20 km, and different reservoirs have been developed by two different operators. The stack of reservoirs is divided into shallower reservoirs (U Reservoirs) and deeper reservoirs (L Reservoirs). The L Reservoirs are geologically divided into two major reservoirs, L1 and L2, which have been developed similarly. The development began with natural production with original reservoir energy. Beginning in the 1970s, pressure maintenance through dump flood-water injection by connecting the target reservoirs with a shallow aquifer was conducted for 10 years. For further reservoir-pressure maintenance, powered peripheral water injection was started, and the development scheme has been continuous, with reinforced pressure maintenance through immiscible gas injection from the top structure.

Simulation study of huff-n-puff air injection for enhanced oil recovery in shale oil reservoirs

Abstract This paper is the first attempt to evaluate huff-n-puff air injection in a shale oil reservoir using a simulation approach. Recovery mechanisms and physical processes of huff-n-puff air injection in a shale oil reservoir are investigated through investigating production performance, thermal behavior, reservoir pressure and fluid saturation features. Air flooding is used as the basic case for a comparative study. The simulation study suggests that thermal drive is the main recovery mechanism for huff-n-puff air injection in the shale oil reservoir, but not for simple air flooding. The synergic recovery mechanism of air flooding in conventional light oil reservoirs can be replicated in shale oil reservoirs by using air huff-n-puff injection strategy. Reducing huff-n-puff time is better for performing the synergic recovery mechanism of air injection. O2 diffusion plays an important role in huff-n-puff air injection in shale oil reservoirs. Pressure transmissibility as well as reservoir pressure maintenance ability in huff-n-puff air injection is more pronounced than the simple air flooding after primary depletion stage. No obvious gas override is exhibited in both air flooding and air huff-n-puff injection scenarios in shale reservoirs. Huff-n-puff air injection has great potential to develop shale oil reservoirs. The results from this work may stimulate further investigations.

Carbon-Plastic Plain Bearings for Pumps of Power Plants

The experience of using FUT, FUT-B83, and UPFS carbon plastics in plain bearings of power pumps, crude booster pumps, scavenge pumps, reservoir pressure maintenance pumps, and feed pumps of power plants is generalized. The results of laboratory and bench tests are presented. There are more than 1000 pumps with bearings made of FUT and FUT-B83 plastics.

КОРРОЗИЯ НЕФТЕПРОМЫСЛОВОГО ОБОРУДОВАНИЯ И МЕРОПРИЯТИЯ ПО ПРОТИВОКОРРОЗИОННОЙ ЗАЩИТЕ НА НЕФТЯНОМ МЕСТОРОЖДЕНИИ КАРАКУДУК (ЗАПАДНЫЙ КАЗАХСТАН)

The article delves into the modern problem of oilfield equipment corrosion and anticorrosion techniques. The authors of the article pursued the goal of generalisation of amassed data and information about problems and perspectives of anticorrosion techniques; and tried to analyse current factual material about anticorrosion protection of the Karakuduk oilfield equipment.On the basis of multiyear functioning of the Karakuduk oilfield facility, from the beginning of commercial production in 1998, planned by NIPImunaigaz Research Institute (Aktau, the Republic of Kazakhstan) in 1996, a brief overview on primary causes of oilfield equipment corrosion was made and an array of substantial implications in the functioning of oilfield equipment caused by corrosion was pointed out.The most preeminent and effective applicable anticorrosion techniques were scrutinised. Some information about peculiar features of anticorrosion operations carried out on the Karakuduk oilfield and designed for the anticipation and deflation of the influence of corrosive processes on the key oilfield equipment of various systems: the reservoir pressure maintenance system, the oil production system, the oil gathering system, and the oil treatment system, was sequentially presented. The order of corrosion control was described. Qualitative conclusions about the effectiveness of anticorrosion preemptive measures were made; also some recommendations concerning the choice of anticorrosion techniques were given.