Diversion Optimization in New Well Completions

Senters, C. W.; Johnson, M. D.; Leonard, R. S.; Ramos, Claudio; Squires, Christopher; Wood, T. M.; Woodroof, Robert A.

doi:10.2118/189900-ms

Cited by 27 publications

(4 citation statements)

References 3 publications

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“…Panjaitan et al (2018) carried out a comprehensive method including water hammer analysis, step-down test, and micro-seismic data in Haynesville Shale and their results show the diverters can divert the fluid to intended perforations and TPSF can promote uniform propagation of multiple fractures. Some other field researches also get similar results (Huang et al, 2018;Senters et al, 2018;Weddle et al, 2018). In TPSF operations, a key question is how uneven is the fractures at this point when the temporary plugging agents are injected.…”

Section: Introductionmentioning

confidence: 55%

Effects of Fracturing Parameters on Fracture Unevenness During Large-Stage Multi-Cluster Fracturing in Horizontal Wells

Rui

Zhou

et al. 2021

Front. Energy Res.

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Horizontal wellswith multi-cluster fracturing technology is an effective approach to exploit unconventional hydrocarbon reservoirs. The on-site diagnosis results indicate that multi-cluster fractures always tend to propagate unevenly due to stressinterference, therefore it is very essential to study the effect of fracturing parameters on fracture propagation unevenness. In this paper, the unconventional fracturing model (UFM, Unconventional Fracturing Model) is used to study the effect of multi-cluster fracturing parameters on fracture unevenness in a large stage. This model has been validated with the actual fracturing case on-site in the Longmaxi shale. The investigated parameters include completion parameters (cluster spacing, number of perforations per cluster), pumping parameters (fluid injection intensity and proppant injection intensity). Our simulation results show that firstly reducing fracture spacing will increase stress interference, andhydraulic fractures exhibit a “radial” pattern. Secondly, reducing the perforation number of a single cluster can promote the more uniform propagation of multi-cluster fractures. Thirdly, increasing the fluid injection intensity will increase the fracture length, but will also increase the fracture unevenness. Besides, the injection strength of the proppant has a little effect on the average fracture length and the unevenness of the fracture length. Finally, setting a reasonable cluster spacing and injection fluid strength can obtain a more uniform fracture propagation. Meanwhile reducing the number of perforations per cluster can also reach the goal of propagating evenly. This paper provides a certain reference for the optimization of multi-cluster fracturing parameters in large-stage and multi-cluster wells.

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Section: Introductionmentioning

confidence: 55%

Effects of Fracturing Parameters on Fracture Unevenness During Large-Stage Multi-Cluster Fracturing in Horizontal Wells

Rui

Zhou

et al. 2021

Front. Energy Res.

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“…Compared with other stimulation technologies, TPDF has the advantages of safety, efficiency, and economy and is a more advanced method. TPDF has been successfully applied to the stimulation of Bakken shale reservoirs and Eagle Ford shale reservoirs in North America. − …”

Section: Introductionmentioning

confidence: 99%

“…TPDF has been successfully applied to the stimulation of Bakken shale reservoirs and Eagle Ford shale reservoirs in North America. 19 − 23 …”

Section: Introductionmentioning

confidence: 99%

Experimental Study on Plugging Behavior of Degradable Diverters in Partially Open Fracture in Temporary Plugging and Diverting Fracturing

Guo

Zhou

et al. 2023

ACS Omega

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Temporary plugging and diverting fracturing technology (TPDF) has been successfully applied to improve reservoir productivity. In real reservoirs, a considerable number of fractures have relatively rapidly decreasing fracture widths and closed ends. However, the plugging behavior of diverters in this typical fracture called the partially open fracture (POF) is still unclear because of the few related studies. This paper aims to investigate the plugging behavior of diverters at the fracture tip. The 3D-printed fracture model was used to reproduce the partially open fracture, and the morphological characteristics of the partially open fracture and the open fracture were compared based on the scan data. A series of plugging experiments were conducted to monitor the transport behavior of the diverter in partially open fractures through multiple pressure sensors on the fracture model and to investigate the influence of diverter formula and fracture type on plugging behavior. Finally, based on the experimental results, the plugging mechanism of diverters in partially open fractures was analyzed. The plugging experiments show that a higher-pressure distribution appears at the fracture tip when using a combination of fibers and particles, indicating that it is beneficial for the diverter to transport to the tip and form plugging in the fracture, and it should be noted that small changes in particle size and concentration had a significant influence on the plugging performance. Therefore, it is recommended to use a combination of fibers and particles of multiple sizes (maximum particle size not exceeding half of the fracture width) to achieve a better plugging effect. In addition, the plugging behaviors of partially open fractures and open fractures are different. For partially open fractures with widths of 1, 2, and 4 mm, the recommended formula of the diverter is 1 wt % fibers + 1 wt % 0.15 mm particles, 1 wt % fibers + 1 wt % 0.15 mm particles + 1 wt % 1 mm particles, and 1 wt % fibers + 1 wt % 0.15 mm particles + 1 wt % 1 mm particles + 1 wt % 2 mm particles, respectively. The above experimental results provide an experimental and theoretical basis for the application of TPDF in the field.

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“…Due to the complexity of reservoirs, conventional hydraulic fracturing measures show some shortcomings such as small reconstruction volume. Temporary plugging fracturing, as a new reservoir stimulation technology, generally blocks the original fractures with temporary plugging agent, and after pressure suppression, new artificial fractures are generated in other directions, thus realizing the propagation of fracture network [4][5][6][7]. However, the temporary plugging agents in the fracture after temporary plugging will affect the hydraulic fracture conductivity, but the influence law is still unclear.…”

Section: Introductionmentioning

confidence: 99%

An experimental investigation on the influence of temporary plugging fibers and particles on the fracture conductivity

Luo

Han

Kong

et al. 2022

IOP Conf. Ser.: Earth Environ. Sci.

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After temporary plugging and fracturing, some of the difficult-to-degrade temporary plugging agents (fibers and particles) in the fractures will affect the conductivity and ultimately affect the rate of oil production. However, the influence law and mechanism of the fibers and particles on the fracture conductivity are still unclear. In order to solve this problem, based on the FCS-842 fracture conductivity test system, the influence law and mechanism of fibers and particles on the fracture conductivity were investigated. The experimental results show that the larger particles support the fracture wall when particles are contained, resulting in higher conductivity. Further studies have found that high fibers content will lead to a significant decrease in the fracture conductivity under low closure pressure. However, high particles content means high fracture conductivity. The placement position of fibers and particles also affects the fracture conductivity. When the pressure is 10 MPa, the conductivity is maximum when the fibers and particles are placed at the fracture opening. Then, when the pressure increases, the conductivity drops sharply by about 88%. When the closure pressure is ≥ 20 MPa, the conductivity is the highest when the fibers and particles are placed at the fracture tip, followed by the middle of the fracture and the smallest at the fracture opening. After analysis, at the fracture opening, the high flow velocity forms a fiber “Barrier” in the fracture, which makes the conductivity decrease rapidly. In the middle of the fracture, the “Dot-net” structure composed of fibers and particles makes the fracture conductivity decrease, but the decrease amplitude and speed are small. At the fracture tip, the lower flow rate makes the fibers and particles form “Clusters”, and the large flow channel between the clusters makes the fracture conductivity higher than the former two. When the fibers and particles are evenly laid, the fibers are easy to form clusters with the particles to block the flow channel, reducing the fracture conductivity.

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Diversion Optimization in New Well Completions

Cited by 27 publications

References 3 publications

Effects of Fracturing Parameters on Fracture Unevenness During Large-Stage Multi-Cluster Fracturing in Horizontal Wells

Effects of Fracturing Parameters on Fracture Unevenness During Large-Stage Multi-Cluster Fracturing in Horizontal Wells

Experimental Study on Plugging Behavior of Degradable Diverters in Partially Open Fracture in Temporary Plugging and Diverting Fracturing

An experimental investigation on the influence of temporary plugging fibers and particles on the fracture conductivity

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