52nd U.S. Rock Mechanics/Geomechanics Symposium,
2018. American Rock Mechanics Association
3 in the last 30 days
197 since 2007
Show more detail
ARMA Member Price:
ARMA Non-Member Price:
ABSTRACT: This paper focuses on the development of a technique for the determination of actual fracture length of a hydraulic fracture. Existing hydraulic fracture simulation software may make predictions of fracture length in shale reservoir without considering the volume of natural fractures, which has to fill up before propagation continues. The technique discussed here is limited to shale reservoirs but could be applied to conventional reservoirs with natural fractures. The moving reference point (MRP) technique is used in the analysis of the first three stages of a fracture treatment. With the aid of a fracture length-time plot generated from a hydraulic fracture simulator that matches the data, the distance from the wellbore to the natural fractures, which also translates to the actual fracture length for the stage, could be determined. An algorithm for this technique is developed. From the results obtained, natural fractures in the shale formation were identified and the length of the hydraulic fracture was determined. It can be seen that after 7 mins, the actual fracture length is about 45.72 m, (150 ft.) instead of 76.20 m (250 ft.) predicted by the simulator output.
The real-time analysis of fracturing data using the moving reference point (MRP) technique (Pirayesh, et al, 2013) is used to carry out the analysis of the pressure-time data from a hydraulic fracture job of shale plays used in this paper. Unlike conventional reservoirs, shale plays are characterized by lots of natural fractures. Soliman, et al, (2014) analyzed data for the Marcellus shale and the Eagleford shale, and this paper extends that work by analyzing two new wells on the Eagleford and making calculations of actual fracture length. The technique can help us determine when the hydraulic fracture intersects a natural fracture during treatment, and can further aid us in determining the distance from the wellbore to the natural fractures and the volume of these natural fractures. The technique involves the use of the time-exponent (e) to predict the behavior of the fracture during treatment and can be applied to both conventional and unconventional reservoirs that have been hydraulically fractured.
Nolte-Smith (1981) in his paper came up with a technique for interpreting pressure-time data from a hydraulic fracture job. In his technique (Fig 1), the net pressure (defined as the difference between the pressure inside the fracture and the fracture closure pressure) is plotted against treatment time on a log-log plot.
Number of Pages
Looking for more?
Some of the OnePetro partner societies have developed subject- specific wikis that may help.