Enhancing Fracture Conductivity Through Surface Modification of Proppant

Nguyen, Phillip; Weaver, Jimmie D.; Dewprashad, Brahmadeo; Parker, Mark; Terracina, J.M.

doi:10.2523/39428-ms

Cited by 20 publications

(1 citation statement)

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“…An overall explanation of how proppants work was stated by Nguyen et al, (1998) back into the wellbore, the width of the fracture channels will decrease; the loss of proppant in the fracture limits the flow-channel conductivity, impairing the effectiveness of the fracture treatment". Upon this definition it is very fair to say that conductivity of the proppant pack is the main concern for the proppant selection and success of the fracturing treatment.…”

Section: Proppant Selectionmentioning

confidence: 99%

Fracturing Fluid Effects on Young's Modulus and Embedment in the Niobrara Formation

2014

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New discoveries of shale plays and their abundant resources have directed the petroleum industry towards their development. Production from shale reservoirs has grown significantly in the past few decades spurred by successful development of plays such as the Barnett and Bakken Shales. Due to their low permeability, hydraulic fracturing is a necessity for economic production in these reservoirs, and the success of these reservoirs is dependent on optimizing hydraulic fracturing designs which are in turn dictated by an understanding of the mechanical properties of these reservoirs. The geometric growth and conductivity of fractures in these reservoirs are influenced by many factors. Young's modulus reduction, which essentially means weakening of the formation, is one of these factors. This reduction damages the reservoir and makes embedment of proppants into the fracture face a detrimental effect on fracturing success. The goal of this research project is to focus on how different fracturing fluids change the Young's modulus of the Niobrara shale and how this change affect the proppant embedment and conductivity when commonly used proppants are subjected to pressure tests in the effected Niobrara shale samples.A series of tests and associated methodology were developed and applied to investigate how the Niobrara shale's Young's modulus is affected by various fracturing fluids and to quantify associated proppant embedment. In order to achieve this, core samples at various depths from the same well were selected from the cores. The selection was made based on mineralogy data. Samples containing the highest, lowest, and median calcite percentage and porosity were selected to be imaged with QEMSCAN in order to understand the mineralogy of the samples being used. Eight selected samples were then saturated with four fracturing fluids (freshwater, KCl, KCl+friction reducer, and freshwater+KCl substitute). Four of these samples were the "expansion" samples to see if the results were more dependent on the fluid selections. Two additional samples were heated with freshwater and KCl at 180°F for five days to investigate the heat effect on Young's modulus and embedment in comparison to room iv temperature experiments. In order to compare in-situ saturated Young's modulus values to dry Young's modulus values of cores obtained by nanoindenter, the Gassmann fluid substitution equation was used.This method showed significant Young's modulus difference between in-situ saturated and dry core values.The saturated/room temperature and saturated/heated cores were then subjected to 3030 psi for one hour while selected proppants were placed in between them. Four different proppant types (16/30 Brady, 20/40 Ottawa, 20/40 Ceramic, and 20/40 RCS) were used in this research. Various combinations of cores affected by fluids and proppants were made in order to simulate actual treatment designs. The cores were also scanned by scanning acoustic microscope (SAM) before and after they were subjected to pressure with proppants, so that...

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Section: Proppant Selectionmentioning

confidence: 99%

Fracturing Fluid Effects on Young's Modulus and Embedment in the Niobrara Formation

2014

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Enhancing Fracturing Proppant Performance: Methods and Assessment

Ramazanov,

Matovu,

Al Shafloot

et al. 2024

Arab J Sci Eng

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Remediation of Production Loss Due to Proppant Flowback in Existing Wellbores

2006

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This paper presents the results of experimental study and field case histories of a remedial treatment technique using a low-viscosity consolidating agent placed into the propped fractures by coiled tubing (CT) or jointed pipe coupled with a pressure pulsing tool. The treatment fluids are designed to provide consolidation for previously placed proppant near the wellbore without damaging the permeability of the proppant pack. The consolidation treatment transforms the loosely packed proppant in the fractures and the formation sand close to the wellbore into cohesive, consolidated, yet highly permeable packs. Laboratory flow testing indicates that the proppant pack in a fracture model under closure stress required low-strength bonds between proppant grains to withstand high production flow rates. Field case histories are also presented to discuss treatment procedures, precautions, and recommendations for implementing the treatment process. One major advantage of this remedial treatment method is the ability to place the treatment fluid into the propped fractures, regardless of the number of perforation intervals and their lengths without mechanical isolation between the intervals. The fluid placement efficiency of this process makes remediation economically feasible, especially in wells with marginal reserves. Introduction Many fracture-stimulated wells in the world today are subjected to curtailed production rates because of sustained proppant flowback problems. In fact, many wells are actually shut in because operators found them to be uneconomical to produce at subsequently lowered rates. Typically, production becomes restricted, such as by perforations being covered with produced proppant. The proppant produced during production often causes damage to downhole pumps and to surface equipment. In addition, repairing the equipment often results in costly downtime for the wells. Low production rates directly affect potential revenue for the operator. Frequent workovers required for cleanup or sand removal, including shut-in time, also factor into the revenue losses caused by proppant flowback or sand infill. However, the problem will return and the loss of revenue will continue to stack up unless a treatment can be found that will remediate the problem at its source and not simply clean up the wellbore. After an initial completion, it is often very difficult to conduct cost-effective remedial treatments to treat proppant production problems. Conventional remedial treatments are usually inadequate without some type of mechanical isolation technique. Conventional methods with a good chance of effective treatment are usually either too high a risk for well problems or too costly to consider for low-return reservoir conditions (or both). Resin materials have also been applied to treat proppant flowback. However, a key problem with using these materials has been an inability to achieve a uniform placement of the resin into propped fractures for the entire perforated interval. This problem is amplified by the presence of variable permeability, perforation debris, formation damage in the near-wellbore region, and the high viscosity of many resin materials. A system that attacks the problem at its source is a better approach to this problem. Using a system of precisely placed treatment fluids into propped fractures conveyed by coiled tubing can turn many marginal wells into excellent producers, and do so cost-effectively. The treatment chemicals introduced into the formation form a consolidated, highly permeable pack that can withstand the high drawdown associated with the production. This paper discusses such a system.

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Enhancing Fracture Conductivity Through Surface Modification of Proppant

Cited by 20 publications

References 0 publications

Fracturing Fluid Effects on Young's Modulus and Embedment in the Niobrara Formation

Fracturing Fluid Effects on Young's Modulus and Embedment in the Niobrara Formation

Enhancing Fracturing Proppant Performance: Methods and Assessment

Remediation of Production Loss Due to Proppant Flowback in Existing Wellbores

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