A Cohesive Technique to Optimize an Openhole Multistage Acid Frac in Unconventional Oil Reservoir - North Kuwait
- Sabry Abd El-Aziz (Kuwait Oil Company) | Chao Chin (Kuwait Oil Company) | Ayham Ashqar (Halliburton) | Moudi Al-Ajmi (Kuwait Oil Company) | Rick Mauro (Halliburton) | Mohamed Nada (Halliburton) | Mohamed Nada (Halliburton)
- Document ID
- Society of Petroleum Engineers
- Abu Dhabi International Petroleum Exhibition & Conference, 13-16 November , Abu Dhabi, UAE
- Publication Date
- Document Type
- Conference Paper
- 2017. Society of Petroleum Engineers
- 7.2 Risk Management and Decision-Making, 5 Reservoir Desciption & Dynamics, 3.3.6 Integrated Modeling, 1.6 Drilling Operations, 7 Management and Information, 1.2.3 Rock properties, 5.8 Unconventional and Complex Reservoirs, 2 Well completion, 2.5.4 Multistage Fracturing, 3.3 Well & Reservoir Surveillance and Monitoring, 2.4 Hydraulic Fracturing, 7.2.1 Risk, Uncertainty and Risk Assessment, 5.8.7 Carbonate Reservoir, 1.6.6 Directional Drilling, 2.6 Acidizing, 2.1.3 Completion Equipment, 3 Production and Well Operations, 5.2 Reservoir Fluid Dynamics
- Sonic, Rock mechanics, Unconventional, multistage, Frac
- 2 in the last 30 days
- 153 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
The combination of horizontal wells and multistage fracturing enabled the development of tight carbonate reservoirs. The successful completion of these reservoirs can be challenging. Correct placement of multistage intervals plays a critical role in improving and sustaining production. Openhole (OH) multistage (MS) technologies enhances reservoir contact and productivity by optimizing the distribution of the stages across the openhole. This paper presents an engineering technique to optimize OH fracture stages and cluster placement distribution within heterogeneous unconventional oil carbonate reservoirs based on formation, completion properties, and reservoir fluid distribution.
Completion technology is based on distributing intelligent packers along the lateral section to develop the MS fracturing stages. Intelligent packer displacement influences fracture effectiveness and conductivity. Equal spacing packer placement can undermine formation potential and productivity results. The placement of the packers and their ports is based on the petrophysical and mechanical properties of the formation to increase the cumulative production in a shorter timeframe and to help improve recovery. The method followed is based on an analysis of the reservoir properties (porosity and permeability). These were later integrated with the measured rock mechanical properties. The developed integrated model was used to categorize the rock into segments that share similar properties.
The use of an advanced azimuthal sonic tool with a high signal-to-noise ratio and wider frequency response helped to improve the accuracy in assessing formation mechanical properties. In addition, conventional logs, when combined with formation mobility measurements, help to calibrate the permeability model and classify the formation into distinctive clusters. These clusters are then grouped according to their mechanical and brittleness properties to form a separate unit with a selected fracture port to help ensure the necessary fracture length. The developed method provides an opportunity to determine the necessary fracture stages and to reduce the risks of overor underplacement. It also improves stage integrity, helps to ensure better distribution of the acid across the formation matrix, and provides effective propagation of the fracture network.
The applied procedure follows an innovative approach to optimize the fracture stage and cluster placement distribution across the reservoir using a new combination of advanced and conventional data acquisition and interpretation. The case study presented in this paper demonstrates the benefits of engineered fracturing stage placement, as compared to a geometric displacement.
|File Size||2 MB||Number of Pages||14|
Buller, D., Hughes, S. N., Market, J. 2010. Petrophysical Evaluation for Enhancing Hydraulic Stimulation in Horizontal Shale Gas Wells. Presented at the SPE Annual Technical Conference and Exhibition, Florence, Italy, 19–22 September. SPE-132990-MS. https://doi.org/10.2118/132990-MS.
Bybee, K. 2007. Rock-Mechanics Considerations in Fracturing a Carbonate Formation. J Pet Technol 59 (07): 50–53. SPE-0707-0050-JPT. https://doi.org/10.2118/0707-0050-JPT.
King, G. E. 2010. Thirty Years of Gas Shale Fracturing: What Have We Learned? Presented at the SPE Annual Technical Conference and Exhibition, Florence, Italy, 19–22 September. SPE-133456-MS. https://doi.org/10.2118/133456-MS.
Rickman, R., Mullen, M. J., Petre, J. E. 2008. A Practical Use of Shale Petrophysics for Stimulation Design Optimization: All Shale Plays Are Not Clones of the Barnett Shale. Presented at the SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA, 21–24 September. SPE-115258-MS. https://doi.org/10.2118/115258-MS.
Salah, M., Orr, D., Meguid, A. A. 2016. Multistage Horizontal Hydraulic Fracture Optimization Through an Integrated Design and Workflow in Apollonia Tight Chalk, Egypt from the Laboratory to the Field. Presented at the Abu Dhabi International Petroleum Exhibition & Conference, Abu Dhabi, UAE, 7–10 November. SPE-183068-MS. https://doi.org/10.2118/183068-MS.
Smith, M. B., Bale, A. B., Britt, L. K. 2001. Layered Modulus Effects on Fracture Propagation, Proppant Placement, and Fracture Modeling. Presented at the SPE Annual Technical Conference and Exhibition, New Orleans, Louisiana, USA, 30 September–3 October. SPE-71654-MS. https://doi.org/10.2118/71654-MS.
Teufel, L. W. and Clark, J. A. 1984. Hydraulic Fracture Propagation in Layered Rock: Experimental Studies of Fracture Containment. SPE J 24 (01): 19–32. SPE-9878-PA. https://doi.org/10.2118/9878-PA.