A Novel Fracturing Fluid System with Ultra-Low Concentration and High Temperature Resistant

2014 ◽  
Vol 624 ◽  
pp. 651-656
Author(s):  
Chao Wang ◽  
Jian Ouyang ◽  
Zhuo Yan Zhu
Keyword(s):  
High Temperature ◽  
Metal Ion ◽  
Ph Value ◽  
Low Cost ◽  
Cross Linking ◽  
Fluid Loss ◽  
Low Permeability ◽  
Fracturing Fluid ◽  
Fluid System ◽  
Low Concentration

According to the low permeability reservoir, fracturing transformation has some requirements on fracturing fluid system with low cost, low damage, and high temperature resistant. First of all, we are able to begin from the concentration of thickener and cross-linking system and then see Synthesis of high temperature resistant polymers as thickening agent. In addition, Non metal ion compounds are introduced as cross-linking agent. Moreover, we will have a performance evaluation on the fracturing fluid system which has been formed, obtaining the best receipe with ultra low concentration and high temperature resistance (calculate according to the mass concentration ):0.075% thickener agent +0.015%pH value regulator +0.25% cross-linking agent +0.01% coagulant +0.4% cleanup agent. This fracturing fluid system has a lot of excellent characteristics such as low density, low cost, low residue, low fluid loss, no metal ion and so on . It also cuts down the use-cost of fracturing fluid and reduces the damage to the Stratum towards which fracturing fluid has. The favorable Cross-linking system fill the gap that we use the non metal ion as cross-linking agent in our present fracturing fluid system at home and abroad.

Study of New Ultra-Temperature Polymer Fracturing Fluid Material

2014 ◽  
Vol 1061-1062 ◽  
pp. 283-286 ◽  
Author(s):  
Sheng Peng Wang ◽  
Xian Zheng Zhao ◽  
Bo Cai ◽  
Shen Hua
Keyword(s):  
High Temperature ◽  
Low Permeability ◽  
Bohai Bay ◽  
Fracturing Fluid ◽  
Fluid System ◽  
Acid Rock ◽  
High Efficient ◽  
New Material ◽  
Buried Hill ◽  
Ultra High Temperature

Nowadays, hydraulic fracturing has become the mainly treatment in low permeability reservoirs.Niudong buried-hill was located in the Baxian Sag of the Bohai Bay Basin. The charactristers of this natural reservoirs are summarized as :low porosity and ultra-low permeability ;complex storage types and complex fracture break and with ultra high temperature (200-210°C) ,In the past, 150°C fracturing fluid system was used in order to solve fluid fracturing efficiency low, quick acid rock reaction.Field test shown that it can’t meet target of greatly improve the output. So it is necessary to develop a novel fluid system to achieve high-efficient stimulation. Therefore, this paper invented a new high temperature resistant ternary anionic thickener, and launched some fracturing fluid performance evaluation.The novel high-temperature fracturing fliud provides a new material to stimulate ultra-high temperature, ultra deep formation to help maximize recovery efficiency. it has important strategic significance for exploration promotion of ultra-high reservoirs .

scholarly journals Research on the Technology of Recovering Low Concentration Ni+ Metal Ion Solution

2021 ◽  
Author(s):  
Huige Chen ◽  
Hangyu Chen ◽  
Kechi Chen ◽  
Xinda Wu ◽  
Wanyu Zheng ◽  
...  
Keyword(s):  
Inorganic Chemistry ◽  
Chemical Industry ◽  
Metal Ion ◽  
High Efficiency ◽  
New Technologies ◽  
Ph Value ◽  
Low Cost ◽  
Strong Discontinuity ◽  
Low Concentration ◽  
Recycling Systems

Under environmentally friendly and environmental issues, wastewater treatment in laboratories and factories is an important international issue. Among them, wastewater from the chemical industry accounts for a large part of industrial wastewater discharge. The introduction of new technologies to treat chemical wastewater is of great significance. In particular, the amount of wastewater produced by inorganic chemistry experiments is relatively large, and the pollutants are mostly heavy metal salts. According to the characteristics of inorganic chemistry experimental wastewater, such as special nature, small amount, strong discontinuity, high hazard, complex and changeable composition, etc., design a chemical reaction to provide a practical and feasible method to treat wastewater with high efficiency and low cost. This research initially takes Ni+ metal ion waste liquid as the first stage of recycling and treatment to improve the traditional low-concentration non-economic treatment. The preliminary results of this research are neutralization reaction and optimal pH value control of Ni+ waste liquid to generate Ni+ precursors to increase the economic value of recycling will be the basis for providing in-house recycling systems for electroplating plants, panel plants, and semiconductor plants to achieve emission reduction, green chemical industry and green environmental protection.

scholarly journals A new type of experimentally proposed in situ heat/gas clean foam fracturing fluid system

2020 ◽  
Vol 10 (8) ◽  
pp. 3419-3436
Author(s):  
Kuangsheng Zhang ◽  
Zhenfeng Zhao ◽  
Meirong Tang ◽  
Wenbin Chen ◽  
Chengwang Wang ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Pressure Coefficient ◽  
System Optimization ◽  
Inert Gas ◽  
Working Fluid ◽  
Fluid Loss ◽  
Fracturing Fluid ◽  
Fluid System ◽  
New Type

Abstract When cold fluid is injected into low-temperature, low-pressure, low-permeability reservoirs containing wax-bearing heavy oil, cryogenic paraffin deposition and heavy oil condensation will occur, thus damaging the formation. Moreover, the formation pressure coefficient is low and the working fluid flowback efficiency is low, which affects the fracturing stimulation effect. Therefore, an in situ heat/gas clean foam fracturing fluid system is proposed. This system can ensure that conventional fracturing fluid can create fractures and carry proppant in the reservoir, generate heat in situ to avoid cold damage, reduce the viscosity, and improve the fluidity of crude oil. The in situ heat fracturing fluid generates a large amount of inert gas while generating heat, thus forming foam-like fracturing fluid, reducing fluid loss, improving proppant-carrying performance, improving gel-breaking performance, effectively improving crack conductivity, and is clean and environmentally friendly. Based on the improved existing fracturing fluid system, in this paper, a new type of in situ heat fracturing fluid system is proposed, and a system optimization evaluation is conducted through laboratory experiments according to the performance evaluation standard of water-based fracturing fluid. Compared with the traditional in situ heat fracturing fluid system, the fracturing fluid system proposed in this study generates a large amount of inert gas and form foam-like fracturing fluid, reduces fluid loss, enhances the proppant-carrying capacity and gel-breaking performance, improves crack conductivity, the gel without residue and that the gel-breaking liquid is clean and harmless.

scholarly journals Research on Property of Multicomponent Thickening Water Fracturing Fluid and Application in Low Permeability Oil Reservoirs

2018 ◽  
Vol 2018 ◽  
pp. 1-10 ◽  
Author(s):  
Chengli Zhang ◽  
Peng Wang ◽  
Guoliang Song
Keyword(s):  
Guar Gum ◽  
New Technology ◽  
Oil Field ◽  
Ammonium Bromide ◽  
Low Permeability ◽  
Fracturing Fluid ◽  
Fluid System ◽  
Fracture Conductivity ◽  
Hydroxypropyl Guar ◽  
Actual Production

The clean fracturing fluid, thickening water, is a new technology product, which promotes the advantages of clean fracturing fluid to the greatest extent and makes up for the deficiency of clean fracturing fluid. And it is a supplement to the low permeability reservoir in fracturing research. In this paper, the study on property evaluation for the new multicomponent and recoverable thickening fracturing fluid system (2.2% octadecyl methyl dihydroxyethyl ammonium bromide (OHDAB) +1.4% dodecyl sulfonate sodium +1.8% potassium chloride and 1.6% organic acids) and guar gum fracturing fluid system (hydroxypropyl guar gum (HGG)) was done in these experiments. The proppant concentration (sand/liquid ratio) at static suspended sand is up to 30% when the apparent viscosity of thickening water is 60 mPa·s, which is equivalent to the sand-carrying capacity of guar gum at 120 mPa·s. When the dynamic sand ratio is 40%, the fracturing fluid is not layered, and the gel breaking property is excellent. Continuous shear at room temperature for 60 min showed almost no change in viscosity. The thickening fracturing fluid system has good temperature resistance performance in medium and low temperature formations. The fracture conductivity of thickening water is between 50.6 μm2·cm and 150.4 μm2·cm, and the fracture conductivity damage rate of thickening water is between 8.9% and 17.9%. The fracture conductivity conservation rate of thickening water is more than 80% closing up of fractures, which are superior to the guar gum fracturing fluid system. The new wells have been fractured by thickening water in A block of YC low permeability oil field. It shows that the new type thickening water fracturing system is suitable for A block and can be used in actual production. The actual production of A block shows that the damage of thickening fracturing fluid is low, and the long retention in reservoir will not cause great damage to reservoir.

scholarly journals Development and Performance Evaluation of Steam Channeling Plugging Agent of Thermal Oil Recovery

2015 ◽  
Vol 8 (1) ◽  
pp. 58-63
Author(s):  
Wang Chunsheng ◽  
Sun Yingfan ◽  
He Chenglin ◽  
Zhang Haipeng ◽  
Du Qiuying
Keyword(s):  
Thermal Stability ◽  
High Temperature ◽  
Oil Recovery ◽  
Ph Value ◽  
Control Agent ◽  
Formation Condition ◽  
Cross Linking ◽  
Profile Control ◽  
High Efficient ◽  
And Performance

Under the constraints of high temperature and heterogeneity, the common profile control agent can not effectively plug the steam channeling. To address this issue, it is necessary to develop the high temperature resistance steam channeling plugging agent to improve the steam suction profile in the heavy oil reservoir. This paper used Simple Variable Method to optimize the content of the components of the high temperature resistant plugging agent. Static performances evaluation aims to study the influence rules of the formation condition (temperature, salinity and pH value). Dynamic evaluation is used to study its performance (plugging ratio, residual resistance factor, scouring resistance and thermal stability) in the sand-filled pipe to testify its applicability. The ratio of the component and the injection sequence are shown as follows: 0.03% coagulant +2.2% cross-linking agent I + 1.2% cross-linking II + 6% high efficient main agent. The evaluation experiment results show that the gel can resist at least 280ºC, the plugging ratio is above 93.1%. The plugging ratio only have a 8.43% reduction after scoured by 15 PV steam (280ºC). After a 10-day thermal stability experiment (280 ºC), the plugging ratio is still above 80%. The result indicated that the plugging agent is suitable for the improvement of steam suction profile. The suggested way of injection is also provided.

Design and Application of High-Temperature Raw-Seawater-Based Fracturing Fluids

SPE Journal ◽  
2019 ◽  
Vol 24 (04) ◽  
pp. 1929-1946 ◽  
Author(s):  
Tariq Almubarak ◽  
Mohammed AlKhaldi ◽  
Jun Hong Ng ◽  
Hisham A. Nasr-El-Din
Keyword(s):  
High Temperature ◽  
Calcium Sulfate ◽  
Ph Value ◽  
Fracturing Fluid ◽  
Remote Areas ◽  
Fracturing Fluids ◽  
High Pressure High Temperature ◽  
Negative Effect ◽  
Static Conditions ◽  
First Time

Summary Typically, water-based fracturing treatments consume a large volume of fresh water. Providing consistent freshwater sources is difficult and sometimes not feasible, especially in remote areas and offshore operations. Therefore, several seawater-based fracturing fluids have been developed in an effort to preserve freshwater resources. However, none of these fluids minimizes fracture-face skin and proppant-conductivity impairment, which can be critical for unconventional well treatments. Several experiments and design iterations were conducted to tailor raw-seawater-based fracturing fluids. These fluids were designed to have rheological properties that can transport proppant under dynamic and static conditions. The optimized seawater-based fracturing-fluid formulas were developed such that no scale forms when additives are mixed in or when the fracturing-fluid filtrate is mixed with different formation brines. The tests were conducted using a high-pressure/high-temperature (HP/HT) rheometer, coreflood, and by aging cells at 250 to 300°F. The developed seawater-based fracturing fluids were optimized with an apparent viscosity greater than 100 cp at a shear rate of 100 seconds–1 and a temperature of 300°F for more than 1 hour. The use of polymeric- and phosphonate-based scale inhibitors (SIs) prevented the formation of severe calcium sulfate (CaSO4) scale in mixtures of seawater and formation brines at 300°F. Controlling the pH of fracturing fluids prevented magnesium and calcium hydroxide precipitation that occurs at a pH value of greater than 9.5. Most importantly, SIs had a negative effect on the viscosity of seawater fracturing fluid during testing because of their negative interaction with metallic crosslinkers. The developed seawater-based fracturing fluids were applied for the first time in an unconventional and a conventional carbonate well and showed very promising results; details of field treatments are discussed in this paper.

Study of Drilling Fluid System of Resisting the High Temperature of 220 Degrees

2013 ◽  
Vol 753-755 ◽  
pp. 130-133
Author(s):  
Hui Hong Luo ◽  
Ze Hua Wang ◽  
Yu Xue Sun ◽  
Han Jiang
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Fluid Loss ◽  
Borehole Stability ◽  
Fluid System ◽  
Well Drilling ◽  
Deep Well ◽  
Materials Used ◽  
Loss Control ◽  
Determine System

Focus on the high temperature rheological stability and the fluid loss control of resistance to high temperature drilling fluid system, further determine system formula and the formula of the high temperature drilling fluid system should be optimized. Eventually, a kind of organo-silica drilling fluid system of excellent performance which is resistant to high temperature of 220 degrees has been developed, and the system performances have been evaluated. The high temperature-resistant organo-silica drilling fluid system is of good shale inhibition, lubricity and borehole stability. The fluid loss is low and the filter cake is thin and tight, which can effectively prevent bit balling. The sand-carrying ability is good and the rheological property is easy to control. The performances of drilling fluid remain stable under high salinity and the system can resist the pollution of 6%NaCl and 0.5%CaC12. The materials used in this system are non-toxic, non-fluorescent and suitable for deep well drilling.

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