Evaluation of Particulate and Hydrocarbon Fracturing Fluid-Loss Additives Under Dynamic Conditions

1997 ◽  
Author(s):  
James M. McGowen ◽  
Sanjay Vitthal
Keyword(s):  
Fluid Loss ◽  
Fracturing Fluid ◽  
Dynamic Conditions

Performance of Fracturing Fluid Loss Agents Under Dynamic Conditions

1968 ◽  
Vol 20 (07) ◽  
pp. 763-769 ◽  
Author(s):  
C.D. Hall ◽  
F.E. Dollarhide
Keyword(s):  
Fluid Loss ◽  
Fracturing Fluid ◽  
Dynamic Conditions

Acid Filtration in Dynamic Conditions to Mimic Fluid Loss in Acid Fracturing

1997 ◽  
Author(s):  
B. Bazin ◽  
C. Roque ◽  
G. Chauveteau ◽  
M. Bouteca
Keyword(s):  
Fluid Loss ◽  
Dynamic Conditions ◽  
Acid Fracturing

An Improved Method for Measuring Fluid Loss at Simulated Fracture Conditions

1985 ◽  
Vol 25 (04) ◽  
pp. 482-490 ◽  
Author(s):  
Robert Ray McDaniel ◽  
Asoke Kumar Deysarkar ◽  
Michael Joseph Callanan ◽  
Charles A. Kohlhaas
Keyword(s):  
Fluid Flow ◽  
Shear Rate ◽  
Filter Paper ◽  
Filter Cake ◽  
Fluid Loss ◽  
Test Results ◽  
Test Apparatus ◽  
Fracturing Fluid ◽  
The Core ◽  
Static Core

Abstract A test apparatus is designed to carry out dynamic and static fluid-loss tests of fracturing fluids. This test apparatus simulates the pressure difference, temperature, rate of shear, duration of shear, and fluid-flow pattern expected under fracture conditions. For a typical crosslinked fracturing fluid, experimental results indicate that fluid loss values can be a function of temperature, pressure differential, rate of shear, and degree of non-Newtonian behavior of the fracturing fluid. A mathematical development demonstrates that the fracturing-fluid coefficient and filter-cake coefficient can be obtained only if the individual pressure drops can be measured during a typical fluid-loss test. Introduction In a hydraulic fracturing treatment, the development of fracture length and width is strongly dependent on a number of key fluid and formation parameters. One of the most important of these parameters is the rate at which the fracturing fluid leaks, off into the created fracture faces. This parameter, identified as fluid loss, also influences the time required for the fracture to heal after the stimulation treatment has been terminated. This in turn will influence the final distribution of proppant in the fracture and will dictate when the well can be reopened and the cleanup process started. Historically, tests to measure fluid loss have been carried out primarily under what is characterized as static conditions. In such tests, the fracturing fluid is forced through filter paper or through a thin core wafer under a pressure gradient, and the flow rate at the effluent side is determined. Of course, the use of filter paper cannot account for reservoir formation permeability and porosity; therefore, the fluid-loss characteristics derived from such tests should be viewed as only gross approximations. The static core-wafer test on the other hand, reflects to some extent the interaction of the formation and fracturing-fluid properties. However, one important fluid property is altogether ignored in such static core-wafer tests. This is the effect of shear rate in the fracture on the rheology (viscosity) of fracturing fluid and subsequent effects of viscosity on the fluid loss through the formation rock. In the past, several attempts were made to overcome the drawbacks of static core-wafer tests by adopting dynamic fluid-loss tests. Although these dynamic tests were a definite improvement over the static versions, each had drawbacks or limitations that could influence test results. In some of the studies, the shearing area was annular rather than planar as encountered in the fracture. In other cases, the fluid being tested did not experience a representative shear rate for a sufficiently long period of time. An additional problem arose because most studies were performed at moderate differential pressures and temperatures. The final drawback in several of the studies was that the fluid flow and leakoff patterns did not realistically simulate those occurring in the field. In the first part of this paper, we emphasize the design of a dynamic fluid-loss test apparatus that possesses none of these drawbacks. In the second part of the paper, test results with this apparatus are presented for three different fluid systems. These systems areglycerol, a non-wall-building Newtonian fluid,a polymer gel solution that is slightly wall-building and non-Newtonian, anda crosslinked fracturing system that is highly non-Newtonian in nature and possesses the ability to build a wall (filter cake) on the fracture face (see Table 1). The fluids were subjected to both static and dynamic test procedures. In the third part of the paper, results of experiments carried out with crosslinked fracturing fluid for different core lengths, pressure differences, temperatures, and shear rates are compared and the significance of the difference of fluid loss is emphasized. Experimental Equipment and Procedure The major components of the experimental apparatus shown in Fig. 1 are a fluid-loss cell, circulation pump, heat exchanger, system pressurization accumulators, and a fluid-loss recording device. The construction material throughout most of the system is 316 stainless steel. The fluid loss is measured through a cylindrical core sample, 1.5 in. [3.81 cm] in diameter, mounted in the fluid-loss cell. Heat-shrink tubing is fitted around the circumference of the core and a confining pressure is maintained to prevent channeling. Fracturing fluid is circulated through a rectangular channel across one end of the core. SPEJ P. 482^

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.

Improving the fracturing fluid loss control for multistage fracturing by the precise gel breaking time design

2015 ◽  
Vol 25 ◽  
pp. 367-370 ◽  
Author(s):  
Xin Lin ◽  
Shicheng Zhang ◽  
Qiang Wang ◽  
Yin Feng ◽  
Yuanyuan Shuai
Keyword(s):  
Fluid Loss ◽  
Fracturing Fluid ◽  
Breaking Time ◽  
Loss Control

Effect of proppant deformation and embedment on fracture conductivity after fracturing fluid loss

2019 ◽  
Vol 71 ◽  
pp. 102986 ◽  
Author(s):  
Jiaxiang Xu ◽  
Yunhong Ding ◽  
Lifeng Yang ◽  
Zhe Liu ◽  
Rui Gao ◽  
...  
Keyword(s):  
Fluid Loss ◽  
Fracturing Fluid ◽  
Fracture Conductivity

Simulation of Pressure- and Temperature-Dependent Fracturing Fluid Loss in Multi-Porosity Multi-Permeability Formations

2021 ◽  
Author(s):  
Chao Liu ◽  
Dung Phan ◽  
Younane Abousleiman
Keyword(s):  
Analytical Solution ◽  
Hydraulic Fracture ◽  
Thermal Effects ◽  
Laboratory Data ◽  
Fluid Loss ◽  
Fluid Temperature ◽  
Temperature Dependent ◽  
Fracturing Fluid ◽  
Fluid Leak ◽  
Rate Comparison

Abstract In this paper, the multi-porosity multi-permeability porothermoelastic theory is used to derive the analytical solution to calculate the pressure- and temperature-dependent fracturing fluid loss. A triple-porosity triple-permeability source rock formation is selected as an example to illustrate the model. The effects of fracturing fluid temperature and natural fractures on the fluid loss rate are systematically illustrated. The model successfully accounts for the varying leak-off rates in the multi-permeability channels through the hydraulic fracture faces. Furthermore, thermal diffusion near the hydraulic fracture faces contributes to a variation of pore pressure whose gradient at hydraulic fracture faces directly controls the fracturing fluid leak-off rate. The model shows that thermal effects bring almost 27% variation in the leak-off rate. Comparison study indicates that the single porosity model without considering multi-permeability systems or thermal effects significantly underestimates the rate of fracturing fluid loss and predicts nearly 84% and 87% lower leak-off rate, compared to the dual-porosity dual-permeability and triple-porosity triple-permeability models, respectively. Two case studies using published laboratory measurements on naturally fractured Blue Ohio sandstone samples are conducted to show the performances of the model. It is shown that the model presented in this paper well captures the total leak-off volume during the pressure-dependent fluid loss measured from laboratory tests. Matching the analytical solution to the laboratory data also allows rocks’ double permeabilities to be estimated.

Proppant Concentration in and Final Shape of Fractures Generated by Viscous Gels

1974 ◽  
Vol 14 (06) ◽  
pp. 531-536 ◽  
Author(s):  
H.R. van Domselaar ◽  
W. Visser
Keyword(s):  
Differential Equations ◽  
Solution Procedure ◽  
Fluid Loss ◽  
Square Root ◽  
Fracturing Fluid ◽  
Breakdown Pressure ◽  
Minimum Width ◽  
Fracture Width ◽  
Final Fracture ◽  
Fracture Shape

Abstract A mathematical procedure is given for calculating proppant concentration and final fracture shape for proppant concentration and final fracture shape for a fracture generated by injection of a viscous gel in which the propping material does not settle. To prevent bridging in the fracture, a decreasing pad prevent bridging in the fracture, a decreasing pad volume is present ahead of the proppant slurry. If combined with a criterion for proppant admittance - expressing the minimum width required for nonbridging particle transport - the developed procedure will result in a realistic design of fracturing treatments. Introduction Hydraulic fracturing is a well known technique for improving the productivity of wells by creating a highly conductive path in the reservoir. This path is made by fracturing the formation through the injection of fluid into a well at pressures above the breakdown pressure. To keep the fracture open after the treatment, propping material is injected with the fracturing fluid. Settling of the proppant can be reduced or even prevented by using viscous oil- and water-based gels as fracturing fluids.From theoretical considerations it follows that the cross-section of a propagating hydraulic fracture is approximately elliptical. The dimensions of the ellipse are determined by the injection rate, the injected volume of fracturing fluid, and fracturing-fluid properties-taking into account the volume of fluid loss to the permeable formation. The fluid loss depends partly on the fluid potential gradients at the fracture walls, resulting in a time-dependent fluid-loss coefficient, which is proportional to the reciprocal of the square root of the exposure time.Since the propping material can cause early screenout, a relatively large sand-free pad of fracturing fluid is injected to initiate the fracture. This pad volume moves ahead of the fluid (gel) containing the propping material. Owing to spurt and filtration losses - highest at the fracture tip but decreasing gradually toward the well - the pad length in the fracture will decrease. The proppant-laden fracturing fluid is also subject to fluid loss, which causes the proppant concentration to increase with distance from the well. The propped fracture width obtained after the fracturing treatment depends on the balance between pad volume and proppant concentration in the fracture. A treatment design should therefore aim at optimization of pad volume, fracturing-fluid volume, and proppant concentration. A design program should deliver practical pumping schedules, which generate fractures of required penetration and conductivity. penetration and conductivity. The present study is a new step toward a more realistic design of fracturing treatments. Differential equations describing the proppant distribution in fractures created by very viscous fluids (no settling) are derived and solved. DEFINITION OF THE MATHEMATICAL MODEL The derivation of the differential equations describing the proppant distribution is based on the following model premises.1. Vertical fractures are of rectilinear shape.2. Two symmetric fracture wings move diametrically from the well.3. Fracture dimensions follow the relations established by Geertsma and de Klerk.4. Gel and proppant move with the same velocity in a piston-like manner.5. Rheological properties of the gel prevent settling of the proppant.6. Fluid-loss is proportional to the square root of the exposure time.7. A decreasing proppant-free pad moves ahead of the proppant suspension.Based on these conditions, a set of differential equations subject to the boundary conditions has been derived (see Appendix A). In Appendix B the applied finite-difference scheme, and in Appendix C the solution procedure are discussed. To describe radial fractures, a simple coordinate transformation has been given in Appendix D. SPEJ P. 531

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