You are here
Home > BLOG > Rock Evaluation and Wellbore Stability > The influence of water-based drilling fluid on mechanical property of shale and the wellbore stability

The influence of water-based drilling fluid on mechanical property of shale and the wellbore stability

by Emanuel Martin - 0
Because of high cost and pollution of oil-based drilling fluid, the water-based drilling fluid is increasingly used now. However, bedding planes and micro-cracks are rich in shale formation. When water-based drilling fluid contacts formation rock, it causes the propagation of crack and invasion of drilling fluid, which decrease shale strength and cause wellbore instability. In this paper, we analyzed influence of water-based drilling fluid on shale strength and failure mode by mechanics experiment.

The influence of water-based drilling fluid on mechanical property of  shale and the wellbore stability

 

Shu Hea, Lixi Liangb, Yinjin  Zenga, Yi Dingb, Yongxue Lina, Xiangjun Liub

aSinopec Research Institute of Petroleum Engineering, Beijing 100101, China. bState Key Lab  of Oil & Gas  Reservoir Geology and Exploitation, Southwest  Petroleum University, Chengdu, Sichuan 610500, China.

Abstract

Because of  high cost and pollution of  oil-based drilling fluid, the  water-based  drilling fluid is increasingly used now.  However, bedding planes and micro-cracks are rich in  shale formation. When water-based  drilling fluid contacts formation rock, it  causes the propagation of crack and invasion of drilling fluid, which decrease shale strength and cause wellbore instability. In this paper, we  analyzed influence of  water-based  drilling fluid on  shale strength and failure mode by  mechanics experiment. Based on those experimental results, considering the effect of bedding plane and drilling time, we established modeling of wellbore stability for shale formation. The result from this model indicates that  in  certain azimuth of  horizontal well, collapsing pressure increases dramatically due to shale failure along with bedding plane. In drilling operation, those azimuths are supposed to be avoided. This model is applicable for predication of  collapsing pressure in  shale formation and offers reference for choosing suitable mud weight.

1. Introduction

As a kind of unconventional energy sources, currently shale gas plays an important role in industrialization exploration of the natural gas  [1].  In  the shale gas  exploration and development, the  United States  is leader in  the  world. Though China has abundant shale reserves as  America, the development of shale gas  is on  elementary stage and faces  so many challenges. Especially in drilling operation, borehole collapse has been a common problem [2], which increases drilling period and cost.

In view of the instability problem, normally oil-base drilling fluid is the first choice because of its  relatively strong plugging and inhibitive property. But the defect of oil-base drilling fluid is too expensive and harmful to environment [3]. On the contrary, water-based  drilling  fluid  has   comparatively  low prize and pollution. Therefore, many scholars are   trying to  develop an efficient water-based drilling fluid for shale formation. However, shale formation has strong anisotropy and sensitive for  water fluid, leading to serious instability problems in drilling process.

In this paper, composition and structure of shale have been investigated by  means of X-ray  diffraction (XRD) and Scanning electron microscope. Meanwhile, triaxial compression test and shear test have been applied to observe its mechanics property. By those experiments, the effect of water-based drilling fluid on structure and mechanics can be analyzed. Those analyses indicate that crack propagation and bedding plane are two key factors of causing borehole collapse in shale formation. According to the result, we  establish a wellbore stability model for shale formation. This model is practical for analyzing wellbore stability in shale formation.

2.  Structure and composition of shale

2.1.  Structure of shale

Rock samples were taken from Southern China Longmaxi formation of black shale. Bedding plane is clearly observed from standard shale cores (Fig. 1). Moreover, Scanning electron microscope was applied to observe substructure morphology of shale. The result in Fig. 2 shows micro-cracks and micro-pores are rich inside shale. By measurement, width of micro-cracks ranges from 0.4μm to 3µm.

Rock samples were taken from Southern China Longmaxi formation of black shale. Bedding plane is clearly observed from standard shale cores (Fig. 1). Moreover, Scanning electron mi- croscope was applied to observe substructure morphology of shale.

Fig. 1. Shale core samples.

2.2. Mineral composition and content analysis

XRD analysis results are  presented in Table  1 and Table  2. In those samples, brittle mineral (quartz, plagioclase and calcite) is predominated and its  average content is 80.77%,  whereas  clay mineral only  averages 12.92% and ranges between 11.12%  and 14.10%.  In clay  mineral, illite  is the main content and averages 85.80%. Montmorillonite is  extremely little and only  averages 0.01%.

The result in Fig. 2 shows micro-cracks and micro-pores are rich inside shale. By measurement, width of micro-cracks ranges from 0.4μm to 3µm.

Fig. 2.  Substructure morphology shale specimens.

It is noted that content of brittle mineral is very high and clay mineral is not the abundant one in the component. In addition, Montmorillonite and illite  smectite, which have strong hydration and swelling property, are in low content. According to that, the shale from Southern China Longmaxi formation is typical brittle shale and has  weak hydration. So hydration swelling is not the key factor for borehole collapse.

XRD analysis results are presented in Table 1 and Table 2. In those samples, brittle mineral (quartz, plagioclase and calcite) is predominated and its average content is 80.77%, whereas clay mineral only averages 12.92% and ranges between 11.12% and 14.10%. In clay mineral, illite is the main content and averages 85.80%. Montmorillonite is extremely little and only averages 0.01%.

3. Effect of water-based drilling fluid on mechanics of shale

Bedding plane has  huge impact on strength of shale [4,5].  To analyze this type of mechanics structure, we  assume that shale rock is composed by 2 parts-rock matrix and bedding plane. We use  2 methods to get shale strength by shear test (Fig. 3) so that obtain the strength of  rock matrix and bedding plane respectively. In this experiment, we  can  get  strength of rock  matrix by shearing core  in  the direction perpendicular to  bedding plane (Fig. 3a)  and strength of bedding plane by shearing core  in  the direction parallel to the bedding plane (Fig. 3b).We use 2 methods to get shale strength by shear test (Fig. 3) so that obtain the strength of rock matrix and bedding plane respectively. In this experiment, we can get strength of rock matrix by shearing core in the direction perpendicular to bedding plane (Fig. 3a) and strength of bedding plane by shearing core in the direction parallel to the bedding plane (Fig. 3b).

Fig. 3.  Schematic of shear test for  obtaining strength of rock matrix and bedding plane.

According to above methods, shear test was used to  obtain the strength of matrix and bedding plane after shale was soaked with water-based drilling fluid in different time. The results are presented in Fig. 4 and 5.

From results of Figs. 4 and 5, internal friction angle and cohesion of rock matrix are higher than bedding plane, which indicates bedding plane is relatively weak plane. After soaking water-based drilling fluid, the strength of bedding plane declines more quickly, which means that bedding plane is affected more by drilling fluid. The reason for that is the bedding plane has relatively high permeability, compared to rock matrix [6]. Therefore, it is easier for drilling fluid to penetrate inside. Consequently, bedding plane is more sensitive to water-based drilling fluid. Compared with decline trend of rock matrix and bedding plane, it is similar. Both of they drop dramatically firstly and then become stable in the late stage, which means the influence of drilling fluid is more obvious in initial stage.

From results of Figs. 4 and 5, internal friction angle and cohesion of rock matrix are higher than bedding plane, which indicates bedding plane is relatively weak plane.

Fig. 4. Curve of  friction angle of shale bedding plane and matrix in different soaking time.

To analyze the failure mode of shale, triaxial test was conducted along with the parallel and perpendicular direction of bedding  plane, as  shown in  Fig.  6.  Broken shale cores after triaxial test are  illustrated in Figs. 7 and 8. Based  on  the results, different compressing direction has little influence on failure mode, which is still mainly single shear failure mode. In addition, there are  several cracks around shear plane. With increase of soaking time, the failure mode is  still same but more cracks occur. Parts of  those cracks are connected with each other, forming a crack network zone. The reason of the phenomenon is that drilling fluid invades into shale after soaking, which leads to crack propagation and strength decrease. So for brittle shale with low  hydration, the key  point for  drilling fluid is its  sealing capacity to prevent invasion.

From results of Figs. 4 and 5, internal friction angle and cohesion of rock matrix are higher than bedding plane, which indicates bedding plane is relatively weak plane. After soaking water-based drilling fluid, the strength of bedding plane declines more quickly, which means that bedding plane is affected more by drilling fluid.

Fig. 5. Curve of cohesion of shale bedding plane and matrix in different soaking time.

4. Wellbore stability modeling

At present, for shale formation exploration and development, in order to obtain greater production, the horizontal well is the first option. But horizontal well has  long  drilling time. In the late stage of drilling, the instability problems are  getting worse. So this model takes horizontal well as case.

To analyze the failure mode of shale, triaxial test was conducted along with the parallel and perpendicular direction of bedding plane, as shown in Fig. 6.

Fig. 6.  Schematic of 2 methods of triaxial compression test.

Based  on  the linear elastic mechanics, the single weak-plane strength  theory and Mohr-Coulomb criterion, effective stress around the borehole was obtained by coordinate conversion [7] (Fig.  9).  The coordinate conversion equations are shown as follows:

Based on the linear elastic mechanics, the single weak-plane strength theory and Mohr-Coulomb criterion, effective stress around the borehole was obtained by coordinate conversion

Based on the linear elastic mechanics, the single weak-plane strength theory and Mohr-Coulomb criterion, effective stress around the borehole was obtained by coordinate conversion

where σH, σh, σv are in-situ stress, MPa. σxx, σyy, αzz, σxy, σxz, σyz are the stress components of the local  wellbore coordinates, MPa. σr, σθ, σz are the radial stress, hoop stress and axial  stress, MPa. τθz, τrθ, τrz are three components of the shear stress, MPa. ν is Poisson's ratio.  Φ is porosity, %.pi is mud weight, MPa.  pp is  pore pressure, MPa. δ is wellbore permeability coefficient. ζ is  Biot coefficient. β is deviation angle, degree. α is well azimuth, degree.

Broken shale cores after triaxial test are illustrated in Figs. 7 and 8. Based on the results, different compressing direction has little influence on failure mode, which is still mainly single shear failure mode. In addition, there are several cracks around shear plane. With increase of soaking time, the failure mode is still same but more cracks occur.

Fig. 7.  Broken shale core samples by compressing perpendicular direction in  different soaking time.

Broken shale cores after triaxial test are illustrated in Figs. 7 and 8. Based on the results, different compressing direction has little influence on failure mode, which is still mainly single shear failure mode. In addition, there are several cracks around shear plane. With increase of soaking time, the failure mode is still same but more cracks occur.

Fig. 8.  Broken shale core samples by  compressing parallel direction in  different soaking time.

As weak plane, the bedding plan has great effect on rock mechanics. Especially, the different dip and dip azimuth can make different situation for wellbore stability in shale formation. Therefore, as shown in Fig. 10, we use coordinate conversion to get state of stress on bedding plane from stress around borehole [8]. The equations can  be written as follows:

where β1 is dip angle of bedding plane, degree. α1 is dip azimuth angle of bedding plane, degree. srxx, sryy, srzz are normal stress on bedding plane, MPa. τrxy, τrxz, τryz are shear stress on bedding plane, MPa.

where β1 is dip angle of bedding plane, degree. α1 is dip azimuth angle of bedding plane, degree. srxx, sryy, srzz are normal stress on bedding plane, MPa. τrxy, τrxz, τryz are shear stress on bedding plane, MPa.

From coordinate conversion above, stress distribution around borehole and on bedding plane can be obtained. Based on the stress state, Mohr-Coulomb criterion is applied to determine shale failure along with rock matrix or bedding plane.

Based on the linear elastic mechanics, the single weak-plane strength theory and Mohr-Coulomb criterion, effective stress around the borehole was obtained by coordinate conversion [7] (Fig. 9).

Fig.  9. Borehole coordinate system.

Fig. 10. Bedding plane coordinate system.

Fig. 10. Bedding plane coordinate system.

If shale rock failure is along with the bedding plane, according to Mohr-Coulomb criterion, the equation of failure criterion is shown as followed:

where Cw is cohesion of bedding plane, MPa. C is cohesion of rock matrix, MPa. φw is internal friction angle of bedding plane, degree. φ is internal friction angle of rock matrix, degree. σ1, σ3 is the maximum principal stress and minimum principal stress respectively, MPa.

If shale rock failure is on the matrix, the equation of failure criterion can be expressed by the following equation:

where Cw is cohesion of bedding plane, MPa. C is cohesion of rock matrix, MPa. φw is internal friction angle of bedding plane, degree. φ is internal friction angle of rock matrix, degree. σ1, σ3 is the maximum principal stress and minimum principal stress respectively, MPa.

where Cw is cohesion of bedding plane, MPa. C is cohesion of rock matrix, MPa.  φw is internal friction angle of bedding plane, degree. φ is internal friction angle of rock  matrix, degree. σ1, σ3 is the maximum principal stress and minimum principal stress respectively, MPa.

Based  on above equations, if we want wellbore not collapsed, the minimum drilling fluid pressure is supposed to  keep shale stable in both matrix and bedding plane. So the collapse pressure can  be acquired by above equations.

5.  Case analysis

A case  study on Southern China  Longmaxi formation with our model is in the following. According to drilling date from oilfield, overburden pressure is 68MPa, maximum horizontal principal stress is 62MPa  and minimum horizontal principal stress is 49 MPa. Pore  pressure is 30 MPa. Porosity is 7.4%. Rock mechanical parameters are  taken from previous experiments.

Using the above datum into model, with the same azimuth angle of bedding plane (10°) and the same well azimuth angle (90°), we plot collapse pressure distribution with different borehole azimuth angle and different dip of bedding plane. The results are illustrated in Figs. 11-14.

From Figs. 11-14, with the increase time of contacting water-based drilling fluid, collapse pressure grows. Besides, bedding plane only affects shale strength in low dip. When dip of bedding plane is between 0° and 30° , as shown in Figs. 11 and 12, shale is broken along with bedding plane in azimuth from 20° to 60° and from 200° to 240° .

Fig. 11.  Collapse pressure with 0° dip  in  different azimuth and soaking time.

From Figs. 11-14, with the increase time of contacting water-based drilling fluid, collapse pressure grows. Besides, bedding plane only affects shale strength in low dip. When dip of bedding plane is between 0° and 30° , as shown in Figs. 11 and 12, shale is broken along with bedding plane in azimuth from 20° to 60° and from 200° to 240° .

Fig. 12. Collapse pressure with 30° dip  in different azimuth and soaking time.

From Figs. 11-14, with the increase time of contacting water-based drilling fluid, collapse pressure grows. Besides, bedding plane only affects shale strength in low dip. When dip of bedding plane is between 0° and 30° , as shown in Figs. 11 and 12, shale is broken along with bedding plane in azimuth from 20° to 60° and from 200° to 240° . It is noted that, when shale failure along with bedding plane, the collapse pressure will grow dramatically. When dip is 60° and 90°, as shown in Figs. 13 and 14, shale formation is damaged in rock matrix and has relatively low collapse pressure compared to shale failure along with bedding plane.

When dip is 60° and 90°, as shown in Figs. 13 and 14, shale formation is damaged in rock matrix and has relatively low collapse pressure compared to shale failure along with bedding plane.

Fig. 13. Collapse pressure with 60° dip in different azimuth and soaking time.

When dip is 60° and 90°, as shown in Figs. 13 and 14, shale formation is damaged in rock matrix and has relatively low collapse pressure compared to shale failure along with bedding plane.

Fig. 14.  Collapse pressure with 90° dip in  different azimuth and soaking time.

High collapse pressure means it is easy to be collapsed in this area. Therefore, high mud density is  necessary. However, too high mud density tends to cause leakage of formation. So during drilling  operation,  we   should  avoid the  azimuth  with  high collapse pressure in order to ensure the safety of drilling. In this case,  azimuth from 20° to 60° and from 200° to 240° need to be avoided in drilling.

6. Conclusion

After  experiment and analyzing collapse pressure based on calculation results of model, we have conclusion in the following.

  • The content of clay minerals in Longmaxi shale is very low and does not have strong hydration expansion. But microcrack develops very well.  Hence drilling fluid may intrude the rock along with crack, causing it propagation and resulting in borehole instability. So during drilling operation, when water-based drilling fluid is used, sealing ability is the first consideration.
  • Based on mechanical experiment, strength  of  bedding plane is clearly lower than rock  matrix. Meanwhile, after soaking drilling fluid, drop range of bedding plane is larger than rock  matrix, which indicates bedding plane is more sensitive to fluid.
  • Shale mechanical strength would decline after soaking in the drilling fluid. In  addition, crack develops more and connects with each other. The reason for this is that drilling  fluid penetrates shale rock  and then micro-crack expands after contacting water-based drilling fluid, resulting in  the  increase of  the  number of  the cracks and the decrease of strength.
  • Wellbore stability model of shale formation is established by means of  coordinate transformation.  Based on  the calculation of  the model, with the increase of  soaking time, the strength of rock  declines, collapse pressure goes up and the impact of bedding plane is more obvious. When the dip of bedding is low  (0° or 30°) and the azimuth angle of well is from 20° to 60° and from 200° to 240°,collapse pressure rises sharply because of shale failure along with bedding  plane. Therefore, those azimuths need to be avoided during drilling operation.

Acknowledgments

This  research was supported by  the United Fund  Project of National Natural Science Foundation of China  (Grant No. U1262209), the Open Fund (Grant No. PLN0906) of Key Laboratory of Oil and Gas  Reservoir Geology and Exploitation (Southwest Petroleum University) and Basic research Project of Sichuan Province (Grant No. 2014JY0092).

 

References

  1. J.Y. Xu,  A.J. Wu, The  development status of  shale gas in the world and its exploration prospect in China, Special Oil Gas  Reservoirs 17 (5)  (2010) 1-6.
  2. H.P. Wang, R.D. Zhang, D.J. Zhang, et al., Drilling technologies on shale gas in weiyuan structure, Drill.  Prod. Technol. 35 (2)  (2012) 9-11.
  3. S.  Wang, Q.  Cheng, H.  Liu,  et al.,  Shale gas development  on water-based drilling  fluids   research   progress,   Sci.    Technol.   Eng. 13   (16)  (2013) 4597-602.
  4. F. Zhao, H.M.  Tang, Y.F. Meng, et al.,  Effect and strategy of microstructure of geology on wellbore stability of clay shale, Drill.  Prod. Technol. 30 (6)  (2007) 6-19.
  5. J.C. Jaeger, Shear failure of  anisotropic  rock, Geol. Mag. 97 (1960) 65-72. [6]   C.L. Yan,  J.G. Deng, B.H.  Wei, et al.,  Research  on collapsing pressure of  gas shale, Chin. J. Rock Mech. Eng.  32 (8)  (2013) 1595-1602.
  6. B.S. Aad,  Modeling of the stability of highly inclined boreholes in anisotropic rock formation, SPE Drill.  Eng.  3 (3)  (1998) 259-268.
  7. K. Zhao, J.G. Deng, B.H. Wei, et al., Borehole stability of highly-deviated well in bedding shale, Sci.  Technol. Eng.  13 (5)  (2013) 1147-1159.

Corresponding author.

  • E-mail address: [email protected] (L. Liang).
  • Peer review under responsibility of  Southwest Petroleum University.

2405-6561/Copyright © 2016,  Southwest Petroleum University.  Production and hosting by Elsevier B.V. on behalf of  KeAi  Communications Co., Ltd.  This is  an open access article under the CC BY-NC-ND license (http://creativecommons.org/licenses/by-nc-nd/4.0/).

Emanuel Martin
Emanuel Martin is a Petroleum Engineer graduate from the Faculty of Engineering and a musician educate in the Arts Faculty at National University of Cuyo. In an independent way he’s researching about shale gas & tight oil and building this website to spread the scientist knowledge of the shale industry.
http://www.allaboutshale.com

Leave a Reply

eleven + twenty =

Top