A New Methodology for Stimulation of a High-Water-Cut Horizontal Oil Well through the Combination of a Smart Chemical System with Real-Time Temperature Sensing: A Case Study of South Umm Gudair Field, PZ Kuwait
- Abdulaziz Al-Najim (Joint Operations) | Alireza Zahedi (Wafra Joint Operations) | Talal Al-Khonaini (Joint Operations) | Anwar Al-Sharqawi (Wafra Joint Operations) | Philippe Michel Jacques Tardy (Schlumberger Oilfield Eastern Limited) | Adil Abdur Rahman (Schlumberger) | Ikhsan Nugraha (Schlumberger Overseas S.A.) | Pierre Ramondenc (Schlumberger) | Fahad Saleh Alhadyani (Schlumberger Well Services)
- Document ID
- Society of Petroleum Engineers
- SPE/ICoTA Coiled Tubing & Well Intervention Conference and Exhibition, 27-28 March, The Woodlands, Texas, USA
- Publication Date
- Document Type
- Conference Paper
- 2012. Society of Petroleum Engineers
- 2 Well Completion, 5.8.7 Carbonate Reservoir, 1.6 Drilling Operations, 3.2.4 Acidising, 1.8 Formation Damage, 4.1.2 Separation and Treating, 2.5.2 Fracturing Materials (Fluids, Proppant), 1.10 Drilling Equipment, 5.6.1 Open hole/cased hole log analysis, 5.6.11 Reservoir monitoring with permanent sensors, 7.2.3 Decision-making Processes, 5.1.5 Geologic Modeling, 4.3.4 Scale
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This paper presents a case study of a matrix acidizing treatment in a well located at the neutral zone between Kuwait and Saudi Arabia, whereby the combination of a "smart fluid?? in a stimulation treatment pumped through a Coiled-Tubing (CT) with the real time distributed temperature sensing (DTS) technology helped improve the real-time decision process of fluid placement, temporary plugging placement, and treatment efficiency evaluation. As part of the analysis process and to facilitate the onsite decision-making process, a temperature inversion technique was also used to translate the actual temperature profiles into fluid invasion profiles across the horizontal open-hole section of the well. Additionally, a full scale acid placement and thermal modeling is proposed in order to perform an in-depth post-treatment evaluation. The bottom hole data evaluation further confirmed the benefits of using a smart fluid. Following the treatment, the well produced at a rate of 1500 bbl/day with 17% water cut, which is well below the field average of ~50%.
The South Umm Gudair Field, discovered in 1966, is located at the neutral zone between Kuwait and Saudi Arabia. It is producing mainly from Ratawi Oolite, a lower Cretaceous reservoir, through a water drive mechanism. Through the life of the field, the drilling and completion strategy has evolved from simple vertical wells to horizontal wells to maximize the reservoir contact and to minimize the producing water cut. However, in time, an increase in water cut is inevitable and may dramatically affect the total rate. At the same time, the task of performing an efficient stimulation, which is required for improving the well's production, becomes more challenging without some knowledge of, and control over, where the acid will flow during the treatment, and without having any means of avoiding the stimulation of the water zones, while optimizing the stimulation efficiency in the oil-producing zones.
Numerous papers have reported the success of deploying "smart fluids?? whose viscosity builds up upon contact with water and breaks down upon contact with hydrocarbons (Chang et al. 2001) (Soekama et al. 2003) (Shnaib et al. 2009), as a means of temporarily plugging the water zones and diverting the subsequently pumped acid to the next available oil zones. As explained in Chang (Chang, Thomas & Fu 1998), the material becomes a viscous gel when contacting brine and degrades when contacting oil. Little or no residue remains since the material is non-polymeric. Another significant advantage of this material is its mixing simplicity. Additionally, in order to improve zonal coverage, another surfactant-based self-diverting acid system has been used in the field to divert acid into zones of lesser injectivity (Chang, Qu & Frenier 2001) (Uddin et al. 2007) (Nasr-El-Din & Samuel 2007). This fluid operates as the sole treating fluid or in combination with other fluids and does not leave any residual formation damage. Diversion and resistance to flow occurs by the development of the diverter's apparent viscosity during acid spending (Tardy, Lecerf & Christanti 2007) (Lungwidtz et al. 2004).
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