Shaybah-220: A Maximum-Reservoir-Contact (MRC) Well and Its Implications for Developing Tight-Facies Reservoirs

Saleri, Nansen G.; Salamy, S.P.; Mubarak, H.K.; Sadler, R. Kumbe; Dossary, A.S.; Muraikhi, A.J.

doi:10.2118/88986-pa

Cited by 28 publications

(16 citation statements)

References 6 publications

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“…Economic studies on Shaybah field in Saudi Arabia (a distinctive example for smart wells), showed a four-fold reduction in unit development cost for such completions. Moreover, production testing indicated five-fold increase in productivity index compared to horizontal wells completed in similar facies (Saleri et al, 2003). Several other studies have shown superiority of nonconventional wells when compared to conventional ones in terms of extended reservoir contact length and drainage area, increasing net worth of drilling investment, reducing operational drawdown pressure, and reducing producing gas-oil ratio (Horn et al, 1997;Taylor et al, 1997).…”

Section: Introductionmentioning

confidence: 91%

Using Distributed Acoustic Sensors to Optimize Production in Intelligent Wells

Bukhamsin

Horne

2014

SPE Annual Technical Conference and Exhibition

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As many fields around the world are reaching maturity, several drilling and completion technologies have been developed to boost production from these fields. Smart completions and distributed measurements are two of the most important tools in this category. This study examined a new smart completion tool, Distributed Acoustic Sensor (DAS) in terms of its utility for inflow monitoring and optimization in smart wells.We began by evaluating the performance of DAS as a tool for measuring downhole multiphase flowrate. A description of the methodology to calculate individual phase flowrates from acoustic signals, caused by pressure fluctuations in the flow, is presented. As DAS provides continuous flow of data from the wellbore, another opportunity emerges to optimize the flow from these smart wells. A methodology to use calculated downhole flowrates to update existing simulation models and perform, near real-time optimization is suggested for wells installed with DAS. As opposed to conventional optimization methods that rely only on reservoir simulation models, this procedure also makes use of real-time flow measurements. The methodology was tested on a synthetic model with encouraging results, where the optimum solutions obtained were in close agreement to the true optimum.The flow profiling procedure was applied to several actual wells. The first well was a single-phase oil producer. This process yielded speed of sound results that matched the fluid properties obtained in the lab. Flowrates from different segments of the well were calculated and results were in close agreement with a surface flowmeter for most sections of the well. More examples were conducted in two-phase flow wells with results being more qualitative and less conclusive. When the optimization procedure was applied for synthetic cases that have wells with similar completions to the tested ones, results showed that significant value could be realized by incorporating real-time measurements in the optimization process.Several advantages could be realized with the application of these methods. First, continuous downhole flow monitoring provides asset managers with more accurate allocation of their wells. Second, more accurate modeling for wellbore flow is possible by using in-situ phase flows to calibrate existing models. With more accurate models, evaluating different flow scenarios is possible before applying them on the field. Finally, quick decisions to change the controls of the well are easier with the described optimization method. By comparison, full reservoir simulation model optimization takes a very long time to make their use practical in everyday applications.

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Section: Introductionmentioning

confidence: 91%

Using Distributed Acoustic Sensors to Optimize Production in Intelligent Wells

Bukhamsin

Horne

2014

SPE Annual Technical Conference and Exhibition

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“…The oil column in this reservoir is overlaid by a huge gas cap and is underlain by a weak aquifer. Gravity drainage mechanism with gas cap expansion is the main drive mechanism (Saleri et al 2003).…”

Section: Introductionmentioning

confidence: 99%

Pushing Maximum Reservoir Contact Applications to New Limits in Tight Facies: A Case Study of Middle East's Highest Reservoir Exposure Producer

et al. 2014

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The paper presents the evolution of reservoir management strategies that supported a recently drilled penta-lateral producer, which set a company record of total reservoir contact in a major greenfield in the Middle East. This paper will investigate the maximum reservoir contact (MRC) evolution in the field, the design phase of this game-changing producer, lessons learned and future implications.The reservoir management objective for this producer was to capture oil reserves in tight layers (less than 10 md) in a gas cap driven carbonate reservoir while delaying gas breakthrough. This design was employed to push the MRC application to new limits of more than 16 kilometers to deliver more production at reduced well requirements while honoring best-in-class reservoir management practices.In the design phase, a very high resolution reservoir simulation model was used to model the performance of this producer. Several sensitivity cases were conducted testing various well designs in terms of lateral spacing and completion depths. Subsequently, this producer was drilled with smallest lateral spacing (62 meter) closer to the oil-water contact (OWC).The drilling of five laterals in 6 ⅛" slimhole was a challenging task that posed hole cleaning threats across the horizontal sections and risked tight hole turning to stuck pipe. Through careful planning and team collaboration between various departments, the well was completed successfully with minor problems. In addition, the well was completed with two permanent downhole monitoring system (PDHMS) gauges and inflow control valves (ICVs) to manage water/gas movement and to ensure lateral clean-up.

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“…In early 2002, the first MRC well was drilled with total reservoir contact of 8.5 km with open hole completion. Drilling and production performance were presented in various SPE papers [Dossary, 2003, Saleri, 2004.…”

Section: Introductionmentioning

confidence: 99%

Application of a Newly Developed Workflow to Design and Optimize MRC and Smart Well Completions

Shenawi

Hidayat

Shammari

et al. 2013

SPE Middle East Oil and Gas Show and Conference

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It is challenging to find optimal well placement and completion design for maximum reservoir contact (MRC) wells in heterogeneous oil and gas reservoirs. Saudi Aramco initiated a new workflow in collaboration with a service company, to achieve such objectives based on integrated software packages of Petrel TM and Saudi Aramco's POWERS TM simulator. This workflow can conduct simulation runs optimizing well architecture, smart completions with inflow control devices (ICD/ICV), lateral and vertical shift of the well, to obtain maximum oil and gas recovery applying sensitivity and optimization algorithms. The new workflow proved to have robust functionality and provided significant cost savings and optimal oil and gas recovery.Three case studies are discussed in this paper. The new workflow assessed the proposed side track and concluded that it was not a good option due to faster water influx from the west flank. This workflow moved the side track lateral to 207 meters to the east and designed to equip the well with ICD and blank pipes. The optimized side track provided 50% more oil recovery than the well that was not moved.The second case was to propose the best location and complex well design for a dual-lateral maintain potential well. The most sensitive parameters were moving the well to the north and vertical locations, motherbore's length and oil rates. Shifting dual laterals to 750 meters north, optimized ICDs, and 1750meter motherbore length provided double the cumulative oil production than the single well manually designed and completed.The third case discusses a tri-lateral well optimization for an oil field that is under development. Based on the sensitivity analysis and shifting well locations have the most significant impact to provide higher oil recovery and delayed water breakthrough for several years.

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Shaybah-220: A Maximum-Reservoir-Contact (MRC) Well and Its Implications for Developing Tight-Facies Reservoirs

Cited by 28 publications

References 6 publications

Using Distributed Acoustic Sensors to Optimize Production in Intelligent Wells

Using Distributed Acoustic Sensors to Optimize Production in Intelligent Wells

Pushing Maximum Reservoir Contact Applications to New Limits in Tight Facies: A Case Study of Middle East's Highest Reservoir Exposure Producer

Application of a Newly Developed Workflow to Design and Optimize MRC and Smart Well Completions

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