scholarly journals New Online Shunt Acidification for Water Injection Increasing Technology and Its Application in Huanjiang Oilfield

2021 ◽  
Vol 2021 ◽  
pp. 1-7
Author(s):  
Zhiying Deng ◽  
Zhenning Ji ◽  
Suiwang Zhang ◽  
Lingpu He ◽  
Xiaobing Lu ◽  
...  
Keyword(s):  
High Efficiency ◽  
Physical Simulation ◽  
Ordos Basin ◽  
Water Injection ◽  
Injection Pressure ◽  
Physical Property ◽  
Injection Wells ◽  
Effective Period ◽  
Injection Technology ◽  
Original Production

The poor physical property and strong heterogeneity of Triassic Yanchang formation in Huanjiang oilfield of Ordos Basin are the main reasons for uneven water absorption, partial injection wells underinjection at high pressure, and decline of production. Previously, large numbers of conventional acidifications were used for plugging removal in the reservoir, but the effect was not so good and effective period was short. Aiming at the geological characteristics of Huanjiang oilfield, an online shunt acidification and augmented injection technology which does not stop water injection, pull original production strings out, and continuously inject acid and diverting agent has been proposed. A chelating acid COA-1S with low corrosion rate (0.3675 g/(m2·h)), good retardation capacity (hydrolysis constant = 1.2 × 10−6), and effective chelating ability (precipitation inhibition rate >95%) has been developed, as well as a diverting agent COA-1P with good dispersion in acid solution, diversion effect, and particle size (10–100 μm), which behaves well in COA-1S acid. It has been proved that the online acid system has a good diversion acidizing ability and plugging removal performance in a deep area in the laboratory core physical simulation test. The field test results show that the online shunt acidizing and augmented injection technology could reduce the injection pressure significantly (4.2 MPa) and increase water injection by 10 m3/d for the measured well (H5) and improve the water injection profile prominently. The online shunting acidification and augmented injection technology have the following advantages: simple procedures, fewer equipment needed, high efficiency of depressurization, and increasing water injection, which could effectively improve the profile of water wells, and there is a bright future of the technology.

Research of Improving Water Injection Effect by Using Active SiO2 Nano-Powder in the Low-Permeability Oilfield

2010 ◽  
Vol 92 ◽  
pp. 207-212 ◽  
Author(s):  
Ke Liang Wang ◽  
Shou Cheng Liang ◽  
Cui Cui Wang
Keyword(s):  
Oil Recovery ◽  
Pore Volume ◽  
Water Injection ◽  
Field Tests ◽  
Injection Pressure ◽  
Rock Surface ◽  
Low Permeability ◽  
Injection Wells ◽  
Decompression Rate ◽  
Nano Powder

SiO2 nano-powder is a new type of augmented injection agent, has the ability of stronger hydrophobicity and lipophilicity, and can be adsorbed on the rock surface so that it changes the rock wettability. It can expand the pore radius effectively, reduce the flow resistance of injected water in the pores, enhance water permeability, reduce injection pressure and augment injection rate. Using artificial cores which simulated geologic conditions of a certain factory of Daqing oilfield, decompression and augmented injection experiments of SiO2 nano-powder were performed after waterflooding, best injection volume of SiO2 nano-powder under the low-permeability condition was selected. It has shown that SiO2 nano-powder inverted the rock wettability from hydrophilicity to hydrophobicity. Oil recovery was further enhanced after waterflooding. With the injection pore volume increasing, the recovery and decompression rate of SiO2 nano-powder displacement increased gradually. The best injected pore volume and injection concentration is respectively 0.6PV and 0.5%, the corresponding value of EOR is 6.84% and decompression rate is 52.78%. According to the field tests, it is shown that, in the low-permeability oilfield, the augmented injection technology of SiO2 nano-powder could enhance water injectivity of injection wells and reduce injection pressure. Consequently, it is an effective method to resolve injection problems for the low-permeability oilfield.

Overview the 5 Years Experience of Intelligent Separate-Layer Injection Technology in B Offshore Oilfield

2021 ◽  
Author(s):  
Yigang Liu ◽  
Zheng Chen ◽  
Xianghai Meng ◽  
Zhixiong Zhang ◽  
Jian Zou ◽  
...  
Keyword(s):  
Short Circuit ◽  
Water Injection ◽  
Operation Time ◽  
Water Flooding ◽  
Internal Diameter ◽  
Injection Wells ◽  
Mode Water ◽  
Separate Layer ◽  
Injection Technology ◽  
Large Flow

Abstract Nowadays intelligent injection is considered as a new frontier for offshore oilfield. In order to improve the water injection indicators such as allocation frequency and qualification rate, intelligent separate-layer injection technology (ISIT) was researched, deployed and optimized in B offshore oilfield from 2015. In the course of 5 years’ project operation, some experience of success or failure was achieved. B offshore oilfield is the largest offshore oilfield in China with 33 water flooding oilfields and more than 800 water injection wells. With the continuous development, the problem of injection management mainly reflected in the contradiction between increasing demand of allocation and limited operation time and space was exposed. Two kinds of ISIT, cable implanted intelligent separate-layer injection technology(CISIT) and wireless intelligent separate-layer injection technology(WISIT), were deployed to solve the above problem. CISIT controlled the distributor downhole by electricity while WISIT controlled the distributor downhole by pressure pulse. By the use of ISIT, downhole nozzle's action, packer testing and downhole data monitoring could be remotely controlled on the ground. During the 5 years’ test, ISIT was optimized from the field breakdown including large flow range flowing test, cable protection project, efficient coding mode, water seepage resistance and so on. With the continuous optimization and quality control improvement, ISIT has overcome many problems, such as downhole short circuit and communication loss, and is becoming more stable and reliable. At present, ISIT can meet the needs of large flow injection(max 800m3/d per layer) and can adapt to the high frequency of acidizing and fracturing in offshore oilfield. The failure rate of ISIT has dropped to nearly 20% in 2020. As of December 2020, ISIT has formed series products for different internal diameter wells and applied in 156 water injection wells in B offshore oilfield. The average allocation frequency has increased from less than one time to 2 times per year. Through the application of ISIT, B offshore oilfield has accumulatively saved more than 2100 days of platform occupation and more than 73 million RMB yuan of allocation cost. The use of ISIT makes B offshore oilfield's injection become more efficient and intelligent. The 5 years’ experience of ISIT applicationin B offshore oilfield has a fairly referential significance for other offshore oilfields.

scholarly journals Dynamics of clogging processes in injection wells used to pump highly mineralized thermal waters into the sandstone structures lying under the polish lowlands

2012 ◽  
Vol 38 (3) ◽  
pp. 105-117 ◽  
Author(s):  
Barbara Tomaszewska ◽  
Leszek Pająk
Keyword(s):  
Water Injection ◽  
Real Life ◽  
Injection Pressure ◽  
Operating Conditions ◽  
Solid Particles ◽  
Injection Well ◽  
Thermal Waters ◽  
Geothermal Systems ◽  
Injection Wells ◽  
Geothermal Resources

Abstract When identifying the conditions required for the sustainable and long-term exploitation of geothermal resources it is very important to assess the dynamics of processes linked to the formation, migration and deposition of particles in geothermal systems. Such particles often cause clogging and damage to the boreholes and source reservoirs. Solid particles: products of corrosion processes, secondary precipitation from geothermal water or particles from the rock formations holding the source reservoir, may settle in the surface installations and lead to clogging of the injection wells. The paper proposes a mathematical model for changes in the absorbance index and the water injection pressure required over time. This was determined from the operating conditions for a model system consisting of a doublet of geothermal wells (extraction and injection well) and using the water occurring in Liassic sandstone structures in the Polish Lowland. Calculations were based on real data and conditions found in the Skierniewice GT-2 source reservoir intake. The main product of secondary mineral precipitation is calcium carbonate in the form of aragonite and calcite. It has been demonstrated that clogging of the active zone causes a particularly high surge in injection pressure during the fi rst 24 hours of pumping. In subsequent hours, pressure increases are close to linear and gradually grow to a level of ~2.2 MPa after 120 hours. The absorbance index decreases at a particularly fast rate during the fi rst six hours (Figure 4). Over the period of time analysed, its value decreases from over 42 to approximately 18 m3/h/MPa after 120 hours from initiation of the injection. These estimated results have been confi rmed in practice by real-life investigation of an injection well. The absorbance index recorded during the hydrodynamic tests decreased to approximately 20 m3/h/MPa after 120 hours.

scholarly journals The Relationship Analysis between Water Injection and Microfacies of SHA1 Reservoir of Liao He Basin, China

2014 ◽  
Vol 2014 ◽  
pp. 1-5
Author(s):  
Qing Wang ◽  
Zhanguo Lu ◽  
Shiguang Guo ◽  
Chao Wang
Keyword(s):  
Water Injection ◽  
Injection Pressure ◽  
Leading Edge ◽  
Inversion Method ◽  
Injection Wells ◽  
Relationship Analysis ◽  
Before And After ◽  
Mouth Bar ◽  
The Relationship ◽  
Distributary Channel

SHA1 is the representative reservoir in Liao He Basin. Through the introduction of curvature displayed on the gray scale, we determine the substructure and fractures. Geostatistical inversion method is used to help study the porosity of reservoir. The relationship between interval transit times and resistivity among mudstone and sandstone, before and after water injection, is analyzed. The relationship between porosity and permeability and the relationship between porosity and impedance from core analysis were studied. Through the whole information above, we divide the microfacies of SHA1 reservoir to distributary channel, mouth bar, the leading edge thin sand, and prodelta mud. The water injections in different microfacies are studied. The distributary channel should be used by large distant injection wells or smaller injection pressure injection. The smaller distant injection wells or large injection pressure should be used in the mouth bar. The arrangement of well injection need consider the different sedimentary microfacies.

Analysis of Reservoir Choke and Broken Down of Tong Liao Uranium Production

2013 ◽  
Vol 868 ◽  
pp. 212-216
Author(s):  
Feng Yan
Keyword(s):  
Water Quality ◽  
Physical Simulation ◽  
Injection Pressure ◽  
Simulation Experiments ◽  
Injection Wells ◽  
Clay Swelling

This project aims at the phenomenon of increasing injection pressure of injection wells of the Tong Liao Uranium SW-8E test wells group, carries out the research of reservoir choke and broken down. By analysis of the water quality of injected and produced fluid through the test wells, scaling prediction, physical simulation experiments and other research, we find the main cause of clogging injection wells: Bacteria blockage, scale blockage, solids blockage and reservoir clay swelling blockage. Meanwhile according to the main reasons of reservoir pollution we have carried on pointed research of broken down, excogitate a better integrated and targeted reservoir choke Blocking Remover. Through on-site implementation, the injection pressure is reduced by 0.3-0.4MPa (maximum allowable injection pressure is 2.0MPa), well purge period is extended from three days to three months, this project solves the problems and achieves very good results.

Research on Degradation of Flocculating Stemming Contained Polymer and Clay Used for Profile Control

2014 ◽  
Vol 912-914 ◽  
pp. 297-300
Author(s):  
Wei Zhang ◽  
Shuang Yan Zhang ◽  
Deng Feng Ju ◽  
Hai Jun Yan ◽  
Guo Qing Fu ◽  
...  
Keyword(s):  
Yellow River ◽  
Sol Gel ◽  
Water Injection ◽  
Injection Pressure ◽  
Control Agent ◽  
Oil Wells ◽  
Control Technique ◽  
Injection Wells ◽  
Fracture Pressure ◽  
Profile Control

Since Menggulin reservoir fully been developed in1990, profile control technique is widely used for improving water swept volume. After multiple rounds and large-scales of polymer flooding by materials mixed with sol-gel and Yellow River clay, the formation damage such as depth blockage and stemming become more and more serious.According to statistics, in 2012 there are respectively 10 and 11 water injection wells happened with back flow of profile control agent and wells pressure higher than fracture pressure that without injection. The original reservoir permeability is good, and individual well production has the capacity of 40 to 50m3/d. Yet recently several oil wells almost have fewer even no liquid output due to the blockage and stemming. Estimated by a typical well group,the speed of sol-gel drive increased from 10 m/year to 50~60 m/year, and average water injection pressure were up to 16MPa which almost double original pressure while the only 2MPa pressure corresponding to oil wells. Hence, it show that the severe depth blockage of the formation exactly exit in Menggulin reservoir.

Water Injection Station Design Based on One-For-Several Rotor VVVF Technique

2013 ◽  
Vol 722 ◽  
pp. 585-590 ◽  
Author(s):  
Yan Rong Chang ◽  
Shou Hu Wang ◽  
Ru Xian He
Keyword(s):  
High Efficiency ◽  
Water Injection ◽  
Electric Energy ◽  
Injection Pressure ◽  
Successful Implementation ◽  
Power Efficient ◽  
Blind Area ◽  
Area Problem ◽  
Oilfield Water ◽  
Valve Control

In the process of oilfield water injection volume of injection allocation often appears with the pump displacement situation does not match; the widespread adoption of stator frequency technology allows the pump displacement and volume of injection allocation phase matching. But the technology in pump class load application speed range is limited, there is still a reflux valve control blind area," turn off undead" problem. One-for-several" rotor frequency Technique in water injection station application solved the control blind area problem, the full realization of the variable frequency close return voltage injection, at the same time, the successful implementation of the slip power efficient feedback. Stable water injection pressure of the system and the electric energy is saved, satisfy the oilfield high efficiency, fine water needs, has a high application value.

Experimental Study of Pumping and Shunting Pump under Pressure in Water Injection Station

2013 ◽  
Vol 329 ◽  
pp. 190-194
Author(s):  
Dong Bo Shao ◽  
Yong Wang ◽  
Sui Wang Zhang
Keyword(s):  
Frequency Control ◽  
Pressure Fluctuations ◽  
Water Injection ◽  
Injection Pressure ◽  
Oil Field ◽  
Maximum Pressure ◽  
Injection Wells ◽  
Pressure Pump ◽  
System Pressure ◽  
Feasibility Test

At present in the process of water injection station operation, starting and stopping the pump caused system pressure fluctuations, and the fluctuations caused many problems about downstream injection wells. In order to eliminate the fluctuations and reduce problems, taking start pump, connect pump test under pressure in the water injection station installed the rotor frequency control system Changqing oil field developed. During the experiment, by progressively increasing the pressure pump to verify start pump with pressure feasibility test , the result shows when the pressure in the 0-25MPa pressure start and connect pump can be realized, and forecast the maximum pressure of the current start of the station with pressure pump. Start pump with pressure achieve the elimination of pressure fluctuations, provide the prerequisites about realizeing stable water injection pressure, and ultimately realize oil field water injection station to be automatic water injection laid a foundation.

Corrosion Behavior for Casing in Producing Well with Water Injection Technology during Long-Term Service

2020 ◽  
Vol 993 ◽  
pp. 1168-1173
Author(s):  
Xin Sun ◽  
Rong Li Nan ◽  
Bo Zhao Shu ◽  
Hang Wang ◽  
Li Juan Zhu ◽  
...  
Keyword(s):  
Corrosion Rate ◽  
Corrosion Behavior ◽  
Water Injection ◽  
Injection Pressure ◽  
Continuous Increase ◽  
Oxygen Condition ◽  
Weight Loss Method ◽  
Loss Method ◽  
Injection Technology

Corrosion leakage became serious due to cyclic sewage injection and continuous increase in water injection pressure. Corrosion behavior for N80 casing was studied during long-term service, using corrosion reaction kettle and weight loss method. The morphology and composition were characterized with laser confocal microscopy (LCM), scan electron microscopy (SEM) and energy disperse spectroscopy (EDS). These results showed that corrosion rate remained constantly at initial stage, and increased gradually, then sharply reached to 0.327mm/a at later stage, accompanying with inflection point under oxygen condition. Meanwhile, corrosion rate decreased significantly from 0.028mm/a to 0.020mm/a under oxygen-free condition. The corrosion of N80 steel was dominated by dissolved oxygen, and accelerated by chloridion. The micro-mechanism was suggested to be the transition of defect structure from crack with micron range to etch pit with millimeter range.

scholarly journals Gas Lift Performance of Some Horizontal Wells in Ahdeb Oil Field

2021 ◽  
Vol 7 (3) ◽  
pp. 66-74
Author(s):  
Dr. Kareem A. Alwan ◽  
Dr. Maha R. Abdulameer ◽  
Mohammed Falih
Keyword(s):  
Water Injection ◽  
Injection Pressure ◽  
Oil Field ◽  
Reservoir Pressure ◽  
Injection Wells ◽  
Artificial Lift ◽  
Electrical Submersible Pumps ◽  
Optimal Injection ◽  
Water Cut ◽  
The Impact

Ahdeb is one of the Iraqi oil fields, its crude characterized by medium API (22.5-28.9) and highly reservoir pressure depletion from Khasib formation due to lack of water drive. This makes it difficult to produce economic oil rates. Therefore, many water injection wells were drilled by the operators to maintain the reservoir pressure during production. In addition to that, electrical submersible pumps (ESP) were used in some productive wells. This study suggests exploitation of gas associated with oil production to be recycled to lift oil as a substitute for the ESP .The work in this study includes using PIPSIM software to build a model of four studied productive wells (AD1-11-2H, AD2-15-2H, AD4-13-3H, A4-19-1H) after choosing the suited correlation for each well. According to the statistical results, Mukherjee & Brill correlation is the best option for all wells. The use of PIPESIM software include determining artificial lift performance to determine the optimum amount of gas injected, optimum injection pressure as well as the optimum injection depth and knowing the impact of these factors on production, as well as the determination of the optimal injection conditions when water cut changes. According to the current circumstances of the wells, the depth optimized for injection is the maximum allowable depth of injection which is deeper than the packer by 100 ft and the amount of injection gas is (1.5, 1, 1, and 1) MMscf/day for wells (AD2-11-2H, AD2-15-2H, AD4-13-3H, and AD4-19-2H) sequentially and injection pressure (2050, 2050, 2050, and 2000) psi for wells (AD2-11-2H, AD2-15-2H, AD4-13-3H, and AD4-19-2H) sequentially.  

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