Overview of Current Hydraulic Fracturing Design and Treatment Technology-Part 2

Veatch, R.W.

doi:10.2118/11922-pa

Cited by 40 publications

(9 citation statements)

References 17 publications

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“…10,11 Obviously, a more accurate account of C w is necessary. 12 Our investigation of variations in fluid-loss data has shown that the widest variations result from core preparation and fluid mixing procedures.…”

Section: Discussionmentioning

confidence: 96%

Control and Modeling of Fluid Leakoff During Hydraulic Fracturing

Penny

Conway

Lee

1985

Journal of Petroleum Technology

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This work examines the variability in fluid leakoff rates measured under static and dynamic conditions. Laboratory-generated data are compared to field-measured data, and the conditions under which static and dynamic data should be used for fracture design are examined.Control of fluid leakoff in both the low-permeability matrix and highly permeable natural fractures is examined on formation cores under a variety of conditions. The control mechanism offered by various fluid-loss additives is evaluated by examining the fluid-matrix and fluid-filtercake interactions.

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Section: Discussionmentioning

confidence: 96%

Control and Modeling of Fluid Leakoff During Hydraulic Fracturing

Penny

Conway

Lee

1985

Journal of Petroleum Technology

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“…Hydraulic fracturing involves injecting proppant-laden slurries, for example, the mixture of sand and slickwater, under high pressure down a tubular wellbore and through perforations to initiate and propagate hydraulically-induced fractures (Veatch 1983; Xu and Wong 2013; Zhai et al 2015). The pressure and injected fluid distribution during a hydraulic fracturing treatment along a horizontal well is illustrated schematically in Figure 1.…”

Section: Introductionmentioning

confidence: 99%

Modeling of Perforation Erosion for Hydraulic Fracturing Applications

Long¹,

Liu

Wong

2015

SPE Annual Technical Conference and Exhibition

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Predicting perforation erosion and its consequence on the pressure drop and fluid distribution can be an essential part of successful design of hydraulic fracturing treatments, especially for massive treatments along the horizontal wells when limited entry techniques are practiced. Both the perforation discharge coefficient and diameter change dynamically as proppant-laden slurries are pumped through perforations, making it necessary to consider the changes of these two variables in terms of time in order to predict the fluid distribution along multiple-perforation injection sites. In this paper we propose a practical model to calculate the rate changes of these two variables based on the abrasion mechanisms that have been experimentally verified. An example is presented to illustrate how the specific erosion parameters for both perforation discharge coefficient and diameter can be inferred from the field and experiment data. Our model shows that it is inaccurate to treat the change of the discharge coefficient and diameter alternately as assumed in some previous correlations. We emphasize that the new model can be conveniently incorporated in a typical hydraulic fracturing simulation to calculate the geometry change of the perforations and its consequent influence on the bottom-hole pressure and fluid distribution.

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“…One of the main objectives in conducting hydraulic fracturing operations is to design a fracture that optimizes fluid flow to the well, without negatively affecting the integrity of the n involve choosing ) the most effective materials (fluids and proppants), (2) the necessary volume of material, (3) the injection rate, and (4) the injection schedule (Veatch, 1983b). In order to effectively identify an optimal fracture design, detailed information about the lithology and fracturing components needs to be utilized.…”

Section: Introductionmentioning

confidence: 99%

Fracture Dissolution of Carbonate Rock: An Innovative Process for Gas Storage

Castle¹,

Falta²,

Bruce³

et al. 2006

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The goal of the project is to develop and assess the feasibility and economic viability of an innovative concept that may lead to commercialization of new gas-storage capacity near major markets. The investigation involves a new approach to developing underground gas storage in carbonate rock, which is present near major markets in many areas of the United States. Because of the lack of conventional gas storage and the projected growth in demand for storage capacity, many of these areas are likely to experience shortfalls in gas deliverability. Since depleted gas reservoirs and salt formations are nearly non-existent in many areas, alternatives to conventional methods of gas storage are required. The need for improved methods of gas storage, particularly for ways to meet peak demand, is increasing. Gas-market conditions are driving the need for higher deliverability and more flexibility in injection/withdrawal cycling. In order to meet these needs, the project involves an innovative approach to developing underground storage capacity by creating caverns in carbonate rock formations by acid dissolution. The basic concept of the aciddissolution method is to drill to depth, fracture the carbonate rock layer as needed, and then create a cavern using an aqueous acid to dissolve the carbonate rock.Assessing feasibility of the acid-dissolution method included a regional geologic investigation. Data were compiled and analyzed from carbonate formations in six states: Indiana, Ohio, Kentucky, West Virginia, Pennsylvania, and New York. To analyze the requirements for creating storage volume, the following aspects of the dissolution process were examined: weight and volume of rock to be dissolved; gas storage pressure, temperature, and volume at depth; rock solubility; and acid costs. Hydrochloric acid was determined to be the best acid to use because of low cost, high acid solubility, fast reaction rates with carbonate rock, and highly soluble products (calcium chloride) that allow for the easy removal of calcium waste from the well. Physical and chemical analysis of core samples taken from prospective geologic formations for the acid dissolution process confirmed that many of the limestone samples readily dissolved in concentrated hydrochloric acid. Further, some samples contained oily residues that may help to seal the walls of the final cavern structure. These results suggest that there exist carbonate rock formations well suited for the dissolution technology and that the presence of inert impurities had no noticeable effect on the dissolution rate for the carbonate rock.A sensitivity analysis was performed for characteristics of hydraulic fractures induced in carbonate formations to enhance the dissolution process. Multiple fracture simulations were conducted using modeling software that has a fully 3-D fracture geometry package. The simulations, which predict the distribution of fracture geometry and fracture conductivity, show that the stress difference between adjacent beds is the physical property of the f...

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Overview of Current Hydraulic Fracturing Design and Treatment Technology-Part 2

Cited by 40 publications

References 17 publications

Control and Modeling of Fluid Leakoff During Hydraulic Fracturing

Control and Modeling of Fluid Leakoff During Hydraulic Fracturing

Modeling of Perforation Erosion for Hydraulic Fracturing Applications

Fracture Dissolution of Carbonate Rock: An Innovative Process for Gas Storage

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