scholarly journals Research Progress of High Temperature Resistant Fracturing Fluid System

2021 ◽  
Vol 2076 (1) ◽  
pp. 012039
Author(s):  
Ke Xu ◽  
Yongjun Lu ◽  
Jin Chang ◽  
Yang Li
Keyword(s):  
High Temperature ◽  
Oil And Gas ◽  
Guar Gum ◽  
Crosslinking Agent ◽  
Research Progress ◽  
Fracturing Fluid ◽  
Fluid System ◽  
Fracturing Fluids ◽  
Ultra High Temperature ◽  
Exploration And Development

Abstract China has made significant progress in the efficient exploration and development of deep-seated oil and gas wells. Reservoir reformation, as the core tool of high-temperature deep-seated exploration and development, puts forward a strong demand for fracturing fluids. The ultra-high temperature fracturing fluid system developed in my country is mainly divided into two types: ultra-high temperature guar gum fracturing fluid and ultra-high temperature synthetic polyacrylamide fracturing fluid. The high temperature resistant fracturing fluid system is mainly composed of high temperature resistant thickener, high temperature resistant crosslinking agent and temperature stabilizing additives and other additives. Based on indoor research and a large amount of literature, this article summarizes the research and application of high temperature resistant fracturing fluid system, high temperature resistant thickener, high temperature resistant crosslinking agent and temperature stabilizing additives in my country in recent years, and pointed out the shortcomings and limitations of the high-temperature fracturing fluid, the technical direction of the development of high-temperature resistant fracturing fluid technology is proposed.

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 .

New Material Research of 200°C Ultra-High Temperature Fluid in Hydraulic Fracturing Industry Design Technology

2014 ◽  
Vol 915-916 ◽  
pp. 536-539 ◽  
Author(s):  
Gui Fu Duan ◽  
Yun Xu ◽  
Yong Jun Lu ◽  
Bo Cai ◽  
Hua Shen
Keyword(s):  
High Temperature ◽  
Material Research ◽  
Bohai Bay ◽  
Fluid Temperature ◽  
Fracturing Fluid ◽  
Fluid System ◽  
Acid Rock ◽  
High Efficient ◽  
Low Efficiency ◽  
Ultra High Temperature

In order to solve NiuDong101 Well reservoir ultra high temperature (205 °C ) fluid fracturing low efficiency, quick acid rock reaction which usually adopt the 160°C fracturing fluid system. At the same time to meet the deep acid fracturing technology and greatly improve the output, so as to achieve the production increasing reserves of important target. So it is necessary to develop a novel 200°C 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. This fluid system achieved 176mpa.s under the condition of 200°Cand 170s-1of RS600 which can perform good temperature resisting & shearing resistance performance, breakthrough the limit of 200°Cof fracturing fluid temperature resistance. Field application to achieve a major breakthrough, it has important strategic significance for exploration promotion of bohai bay basin.

Preparation of a novel ultra-high temperature low-damage fracturing fluid system using dynamic crosslinking strategy

2018 ◽  
Vol 354 ◽  
pp. 913-921 ◽  
Author(s):  
Yang Zhang ◽  
Jincheng Mao ◽  
Jinzhou Zhao ◽  
Xiaojiang Yang ◽  
Zhaoyang Zhang ◽  
...  
Keyword(s):  
High Temperature ◽  
Fracturing Fluid ◽  
Fluid System ◽  
Ultra High Temperature

A High Density Fracturing Fluid System for HPHT Reservoir Stimulation Treatment

2013 ◽  
Vol 680 ◽  
pp. 312-314
Author(s):  
Ping Li Liu ◽  
Qi Zhu ◽  
Xi Jin Xing
Keyword(s):  
High Temperature ◽  
Petroleum Industry ◽  
Temperature Stability ◽  
High Density ◽  
Fracturing Fluid ◽  
Fluid System ◽  
Shear Properties ◽  
Proppant Transport ◽  
Reservoir Stimulation ◽  
Fracturing Fluids

Petroleum industry is focusing on HPHT reservoir. In high-temperature conditions, fracturing fluids especially need to be stable and induce minimum damage, and have good proppant transport capabilities. In order to overcome these problems, a novel high density fracturing fluid system has been developed whose density can reach up to 1.21 g/cm3. This paper summarizes a study on formulating weighted agent, and extensive studies were also conducted to determine temperature stability and anti-shear properties and compatibility with additives.

scholarly journals Laboratory Testing of Fracture Conductivity Damage by Foam-Based Fracturing Fluids in Low Permeability Tight Gas Formations

Energies ◽  
2021 ◽  
Vol 14 (6) ◽  
pp. 1783
Author(s):  
Klaudia Wilk-Zajdel ◽  
Piotr Kasza ◽  
Mateusz Masłowski
Keyword(s):  
Hydraulic Fracturing ◽  
Guar Gum ◽  
Polymer Concentration ◽  
Laboratory Research ◽  
Damage Effect ◽  
Tight Gas ◽  
Fracturing Fluid ◽  
Fracture Conductivity ◽  
Fracturing Fluids ◽  
Sandstone Rock

In the case of fracturing of the reservoirs using fracturing fluids, the size of damage to the proppant conductivity caused by treatment fluids is significant, which greatly influence the effective execution of hydraulic fracturing operations. The fracturing fluid should be characterized by the minimum damage to the conductivity of a fracture filled with proppant. A laboratory research procedure has been developed to study the damage effect caused by foamed and non-foamed fracturing fluids in the fractures filled with proppant material. The paper discusses the results for high quality foamed guar-based linear gels, which is an innovative aspect of the work compared to the non-foamed frac described in most of the studies and simulations. The tests were performed for the fracturing fluid based on a linear polymer (HPG—hydroxypropyl guar, in liquid and powder form). The rheology of nitrogen foamed-based fracturing fluids (FF) with a quality of 70% was investigated. The quartz sand and ceramic light proppant LCP proppant was placed between two Ohio sandstone rock slabs and subjected to a given compressive stress of 4000–6000 psi, at a temperature of 60 °C for 5 h. A significant reduction in damage to the quartz proppant was observed for the foamed fluid compared to that damaged by the 7.5 L/m3 natural polymer-based non-foamed linear fluid. The damage was 72.3% for the non-foamed fluid and 31.5% for the 70% foamed fluid, which are superior to the guar gum non-foamed fracturing fluid system. For tests based on a polymer concentration of 4.88 g/L, the damage to the fracture conductivity by the non-foamed fluid was 64.8%, and 26.3% for the foamed fluid. These results lead to the conclusion that foamed fluids could damage the fracture filled with proppant much less during hydraulic fracturing treatment. At the same time, when using foamed fluids, the viscosity coefficient increases a few times compared to the use of non-foamed fluids, which is necessary for proppant carrying capacities and properly conducted stimulation treatment. The research results can be beneficial for optimizing the type and performance of fracturing fluid for hydraulic fracturing in tight gas formations.

scholarly journals Potential Use of Water Associated with Conventional Oil Production and Sea Water as Base Fluids for Hydraulic Fracturing Operations: Effect of Water Chemistry on Crosslinking and Breaking Behaviors of Guar Gum-Based Fracturing Fluid Formulations

2016 ◽  
Vol 6 (1) ◽  
pp. 31 ◽  
Author(s):  
Dayanand Saini ◽  
Timea Mezei
Keyword(s):  
Los Angeles ◽  
Hydraulic Fracturing ◽  
Water Chemistry ◽  
Fresh Water ◽  
Oil And Gas ◽  
Guar Gum ◽  
Sea Water ◽  
Oil Production ◽  
Fracturing Fluid ◽  
Conventional Oil

 Even though water consumption per hydraulic fracturing (or fracturing) job is relatively low; nearly all of the fresh water used for fracturing in California is in the regions of high water stress such as San Jouquin and Los Angeles Basins. However, water availability should not be a concern as huge volumes of water are being produced along with oil and gas from conventional formations (i.e. associated water) in the Kern County of California, a region where most of the fracturing activities take place. This associated water can potentially be used for preparing fracturing fluids in stimulating the unconventional formations. The present study reports on the relevant investigation done in this area of interest.The results suggest that associated water chemistry has limited effect on the viscosity of cross-linked formulations. However, guar gum concentration was found to affect the breaking behaviors of cross-linked fracturing fluid formulations. The new type of commercially available biodegradable breaker was found to be effective in breaking the tested cross-linked formulations at elevated temperature which was as high as 85°C (185°F). Both crosslinking and breaking behaviors of fracturing fluid formulations evaluated in this study were found comparable to the behaviors of commonly used cross-linked formulation (guar gum + 2% potassium chloride). These results suggest that both the associated water (i.e. water resulting from regional conventional oil production activites) and sea water (offshore oil fields) could serve as alternative sources of base fluid for use in fracturing jobs without putting significant burden on precious regional fresh water resources.

Reduced-Polymer-Loading, High-Temperature Fracturing Fluids by Use of Nanocrosslinkers

SPE Journal ◽  
2016 ◽  
Vol 22 (02) ◽  
pp. 622-631 ◽  
Author(s):  
Feng Liang ◽  
Ghaithan Al-Muntasheri ◽  
Hooisweng Ow ◽  
Jason Cox
Keyword(s):  
High Temperature ◽  
Gas Flow ◽  
Laboratory Data ◽  
Gelling Agent ◽  
Formation Damage ◽  
Fluid System ◽  
Temperature Range ◽  
Enhanced Production ◽  
Fracturing Fluids ◽  
Polymer Loading

Summary In the quest to discover more natural-gas resources, considerable attention has been devoted to finding and extracting gas locked within tight formations with permeability in the nano- to microdarcy range. The main challenges associated with working in such formations are the intrinsically high-temperature and high-pressure bottom conditions. For formations with bottomhole temperatures at approximately 350–400°F, traditional hydraulic-fracturing fluids that use crosslinked polysaccharide gels, such as guar and its derivatives, are not suitable because of significant polymer breakdown in this temperature range. Fracturing fluids that can work at these temperatures require thermally stable synthetic polymers such as acrylamide-based polymers. However, such polymers have to be used at very-high concentrations to suspend proppants. The high-polymer concentrations make it very difficult to completely degrade at the end of a fracturing operation. As a consequence, formation damage by polymer residue can reduce formation conductivity to gas flow. This paper addresses the shortcomings of the current state-of-the-art high-temperature fracturing fluids and focuses on developing a less-damaging, high-temperature-stable fluid that can be used at temperatures up to 400°F. A laboratory study was conducted with this novel system, which comprises a synthetic acrylamide-based copolymer gelling agent and is capable of being crosslinked with an amine-containing polymer-coated nanosized particulate crosslinker (nanocrosslinker). The laboratory data have demonstrated that the temperature stability of the crosslinked fluid is much better than that of a similar fluid lacking the nanocrosslinker. The nanocrosslinker allows the novel fluid system to operate at significantly lower polymer concentrations (25–45 lbm/1,000 gal) compared with current commercial fluid systems (50–87 lbm/1,000 gal) designed for temperatures from 350 to 400°F. This paper presents results from rheological studies that demonstrate superior crosslinking performance and thermal stability in this temperature range. This fracturing-fluid system has sufficient proppant-carrying viscosity, and allows for efficient cleanup by use of an oxidizer-type breaker. Low polymer loading and little or no polymer residue are anticipated to facilitate efficient cleanup, reduced formation damage, better fluid conductivity, and enhanced production rates. Laboratory results from proppant-pack regained-conductivity tests are also presented.

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.

Improve the Temperature Resistance of Guar Gum by Silanization

2011 ◽  
Vol 415-417 ◽  
pp. 652-655
Author(s):  
Jie Zhang ◽  
Gang Chen
Keyword(s):  
High Temperature ◽  
Reaction Time ◽  
Hydraulic Fracturing ◽  
Reaction Temperature ◽  
Guar Gum ◽  
Molar Ratio ◽  
Fracturing Fluid ◽  
Reaction Conditions ◽  
Temperature Resistance ◽  
Optimized Conditions

For gelating agent in hydraulic fracturing fluid, the temperature resistance is required. To improve the temperature resistance of Guar gum (GG), it was modified by silanization. The reaction conditions were investigated, and the optimized conditions were as following: the reaction temperature of 85°C, 5: 1 molar ratio of guar gum to TMS-Cl and 4-6 h of reaction time. The viscosity of silanized guar gum (SGG) aqueous gel was greatly improved even high temperature at 80°C.

Sign in / Sign up

Export Citation Format

Share Document