**8. Discussion and conclusion**

**Figure 16.** Production prediction comparison of two different hydraulic fracturing treatments. The red curve is the production prediction from slickwater/linear gel treatment; the blue curve is the production from conventional two-

**Figure 15.** Fracture growth and proppant coverage (colour) for two stage of hydraulic fractures using conventional

wing gel fracturing design.

gel treatment.

1034 Effective and Sustainable Hydraulic Fracturing

In this paper we have outlined a new workflow for simulation of a complex fracture network created by stimulation using low-viscosity fluids in a fractured tight sandstone reservoir. The workflow is based on critically stressed fracture theory. This process of natural fracture stimulation is believed to be the underlying reason for the success in shale gas reservoir stimulation. The results suggested that there would be significantly higher production from this approach compared to conventional two-wing gel fracturing.

There are, however, some uncertainties in the modeling of the natural fracture stimulation for this fractured tight gas reservoir.

**Author details**

Fuxiang Zhang5

**References**

Feng Gui1\*, Khalil Rahman1

1 Baker Hughes, Perth, Australia

2 Baker Hughes, Menlo Park, USA

4 Baker Hughes, Beijing, China

, Jianxin Peng5

3 Gaffney, Cline &Associates, Houston, USA

5 PetroChina Tarim Oil Company, Korla, China

, Daniel Moos2

\*Address all correspondence to: Feng.gui@bakerhughes.com

, Xuefang Yuan5

, George Vassilellis3

Optimizing Hydraulic Fracturing Treatment Integrating Geomechanical Analysis and Reservoir Simulation for…

[1] Modeland, N, Buller, D, & Chong, K. K. Stimulation's influence on production in the Haynesville Shale: a playwide examination of fracture-treatment variables that show effect on production. In: proceedings of Canadian Unconventional Resources Confer‐

[2] Maxwell, S. C, Pope, T, Cipolla, C, et al. Understanding hydraulic fracture variability through integrating microseismicity and seismic reservoir characterization. In: pro‐ ceedings of SPE North American Unconventional Gas Conference and Exhibition,

[3] Sayers, C. and Le Calvez, J., (2010). Characterization of microseismic data in gas

[4] Moos, D. Improving Shale Gas Production Using Geomechanics, Exploration & Pro‐

[5] Zoback, M. D, Kohli, A, Das, I, & Mcclure, M. The importance of slow slip on faults during hydraulic fracturing stimulation of shale gas reservoirs. In: proceedings of SPE Americas Unconventional Resources Conference, SPE June (2012). Pittsburgh,

[6] Mullen, M, & Enderlin, M. Is that frac job really breaking new rock or just pumping down a pre-existing plane of weakness?- the integration of geomechanics and hy‐ draulic-fracture diagnostics. In: proceedings of 44th US Rock Mechanics Symposium and 5th US-Canada Rock Mechanics Symposium, ARMA 10-285, 27-30 June (2010).

ence, CSUG/SPE November (2011). Calgary, Alberta, Canada., 148940, 15-17.

SPE June (2011). Woodlands, Texas, USA., 144207, 14-16.

duction- Oil & Gas Review (2011). , 9(2), 84-88.

Pennsylvania, USA., 155476, 5-7.

Salt Lake City, UT, USA.

shales using the radius of Gyration tensor, SEG Expanded Abstract.

and Guoqing Zou5

, Chao Li3

, Qing Liu4

http://dx.doi.org/10.5772/56384

,

1037


The main uncertainty in gel frac productivity estimation comes from the propped fracture conductivity estimation. This conductivity is based on proppant testing in the laboratory. The proppant inside fractures involves clogging, crashing and embedment over the production period. There is no analytical method available to model these long-term effects on propped fracture conductivity. An approximate conductivity damage factor has been used in this study to consider these effects.

Although there are still some shortcomings with the workflow, it can assist in the assessment of development concepts and the evaluation of stimulation enhancement options. The anisotropy in the slickwater treatment can be reasonably well-predicted and applied into the production simulation, which provides a more robust prediction than a simple isotropy model. The new workflow can be used in naturally fractured shale gas, tight gas/oil and CBM reservoirs.
