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Interaction Of Fracture Fluid With Formation Rock And Proppant On Fracture Fluid Cleanup And Long Term Gas Recovery In Marcellus Shale Reserviors
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Book Synopsis Interaction of Fracture Fluid with Formation Rock and Proppant on Fracture Fluid Cleanup and Long Term Gas Recovery in Marcellus Shale Reserviors by : Wenting Yue
Download or read book Interaction of Fracture Fluid with Formation Rock and Proppant on Fracture Fluid Cleanup and Long Term Gas Recovery in Marcellus Shale Reserviors written by Wenting Yue and published by . This book was released on 2012 with total page 154 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Book Synopsis Proceedings of the International Field Exploration and Development Conference 2019 by : Jia'en Lin
Download or read book Proceedings of the International Field Exploration and Development Conference 2019 written by Jia'en Lin and published by Springer Nature. This book was released on 2020-07-11 with total page 3907 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book gathers selected papers from the 8th International Field Exploration and Development Conference (IFEDC 2019) and addresses a broad range of topics, including: Low Permeability Reservoir, Unconventional Tight & Shale Oil Reservoir, Unconventional Heavy Oil and Coal Bed Gas, Digital and Intelligent Oilfield, Reservoir Dynamic Analysis, Oil and Gas Reservoir Surveillance and Management, Oil and Gas Reservoir Evaluation and Modeling, Drilling and Production Operation, Enhancement of Recovery, Oil and Gas Reservoir Exploration. The conference not only provided a platform to exchange experiences, but also promoted the advancement of scientific research in oil & gas exploration and production. The book is chiefly intended for industry experts, professors, researchers, senior engineers, and enterprise managers.
Book Synopsis Analysis of Fracture Fluid Cleanup and Long-term Recovery in Shale Gas Reservoirs by : Maxian Seales
Download or read book Analysis of Fracture Fluid Cleanup and Long-term Recovery in Shale Gas Reservoirs written by Maxian Seales and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Horizontal wells combined with successful multi-stage hydraulic fracture treatments are currently the most widely applied technology for effectively stimulating and enabling economic development of gas bearing, organic-rich shale formations. Fracture fluid cleanup in the stimulated reservoir volume (SRV) is critical to stimulation effectiveness and long-term well performance. However, if the created hydraulic fractures and reinitiated natural fractures are not cleaned up, post-fracture well performance will fall below expectations. Flowback water typically has 10 to 20 times more total dissolved solids (TDS) than the injected fluid. The total dissolved solids in flowback water can be as much 197,000 mg/L; chloride levels alone can be as high as 151,000 mg/L. Effective management of waste water produced from shale gas wells requires a clear understanding of how the volume and composition of this water change over the long term, not only during the flowback period. A systematic study of the factors that hinder fracture cleanup, those that influence the ionic composition of flowback and produced water, and those that enhance gas recovery can help optimize fracture treatments, better quantify long term volumes of produced water and gas, and aid with the management of waste water. To this end, a fully implicit, 3-dimensional, 2-phase, dual-porosity numerical simulator was developed and coupled with a ionic composition model. The research findings have shed light on the factors that substantially affect efficient fracture fluid cleanup and gas recovery in gas shales, and have provided guidelines for improved fracture treatment designs and water management.
Book Synopsis Effect of Multi-phase Flow on Recovery of Fracture Fluid and Gas in Marcellus Shale Reservoirs by : Alphonsus Igoche Abah
Download or read book Effect of Multi-phase Flow on Recovery of Fracture Fluid and Gas in Marcellus Shale Reservoirs written by Alphonsus Igoche Abah and published by . This book was released on 2014 with total page 160 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Book Synopsis Interaction of Fracturing Fluids with Shales by : Ekrem Alagoz
Download or read book Interaction of Fracturing Fluids with Shales written by Ekrem Alagoz and published by . This book was released on 2020 with total page 146 pages. Available in PDF, EPUB and Kindle. Book excerpt: In petroleum engineering, hydraulic fracturing has been developed to mitigate the crucial problem of the world's dwindling oil supplies. Thanks to hydraulic fracturing, engineers can create new artificial apertures with pressurized fluids. The process includes the high-pressure injection of a fracking fluid, which is basically water and proppants. Hydrocarbons will flow more freely after the flow back of water. Once the pumping of fracturing fluid is stopped, created fractures begin to close, as the stress increases. This has become a critical issue because closing these fractures results in a rapid decline in productivity of the well. The primary reason for proppant usage is to settle between fracture apertures and prop them open in order to increase oil and gas productivity. Proppant embedment is a crucial problem that causes many fractures to fail over time. Fractured well productivity can be dramatically reduced by severe proppant embedment due to a reduction in fracture aperture. Accordingly, understanding the proppant embedment phenomena is essential for hydraulic fracturing treatments. In this thesis, the mechanisms of proppant embedment have been investigated by quantifying the stress-dependent deformations (elastic and plastic) as well as the time-dependent deformation (creep). A set of constitutive equations were developed to account for elastic, plastic, and creep deformation during proppant embedment. Two new experimental apparatuses have been built and used to quantify the shale rock proppant deformation behavior (elastic, plastic, and creep) after exposure to various fracture fluid additives such as surfactants and clay stabilizers. Results show that proppant embedment primarily occurs due to plastic deformation followed by time-dependent creep deformation, while elastic deformation is small. The impact of different fracturing fluids and rock mineralogy on proppant embedment were also studied. Our results show that fluid chemistry substantially affects the amount of plastic deformation and creep. For example, KCI with a Clay Inhibitor was quite successful in reducing the proppant embedment. Shales with high clay-content embedded proppant at lower stresses and showed more plastic deformation. The test results show that 15% more clay-content shale samples experienced almost 50% more deformation. Chemical treatments fostered the best improvements or degradations in high clay-content shales
Book Synopsis Secondary Interaction of Fracturing Fluid and Shale Plays by : Reza Keshavarzi
Download or read book Secondary Interaction of Fracturing Fluid and Shale Plays written by Reza Keshavarzi and published by . This book was released on 2021 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: During hydraulic fracturing in unconventional tight formations a high percentage of the injected fluid may remain in the formation and only a small portion of the fracturing fluid is typically recovered. Although spontaneous imbibition is mainly introduced as the main dominating mechanism, a clear understanding of the fundamental mechanisms through which the fracturing fluid would interact with the formation remains a challenge. The impact of these mechanisms on rock property changes is even more challenging but is important to account for post-fracturing reservoir characterization. In this study, an integrated analytical-experimental-numerical approach was adopted to study these issues using a case study within the Montney Formation in Farrell Creek field in northeast British Columbia. The results of experiments on Montney samples from different depths revealed that because of spontaneous water imbibition, the geomechanical properties of the samples were altered. Also, small scale heterogeneity in tight gas formations and shale results in these property changes occurring at various scales, such as beds. Property changes occurring along the beds and bedding planes, as a result of interaction with hydraulic fracturing fluid, can contribute to increased potential for shear failure along these planes. Therefore, a systematic micro-scale analysis (including micro-indentation and micro-scratch along the beds to capture micro-geomechanical responses) and macro-scale analysis (including ultrasonic measurements, uniaxial compressive loading in high and low capillary suctions and unloading-reloading cycles at varying capillary suction) have been developed and applied to capture the changes in rock behavior in different scales as a result of spontaneous water imbibition and how different behaviors in micro-scale would affect the responses in macro-scale. QEMSCAN analysis, nitrogen adsorption-desorption tests, thermogravimetric analysis (TGA), capillary condensation experiments, pressure-decay and pulse-decay permeability measurements and direct shear tests were also completed for quantitative analysis of minerals, pore shapes and porosity, initial water saturation, capillary suction as a function of water saturation, permeability and strength parameters in both macro-scale and micro-scale (bed-scale). QEMSCAN analysis indicated that mineral components were not the same in different beds and they could be categorized into quartz-rich and clay-rich. The results of the experimental phase indicated that the geomechanical and flow properties of Montney specimens were altered due to fluid imbibition. As the water saturation and capillary suction were changing in quartz-rich and clay-rich beds, they responded differently which would trigger some geomechanical behaviors in macro scale. In addition, it was observed that capillary suction would add extra stiffness and strength to the media and as it was diminishing, the media became weaker. A nonlinear response with hysteresis during unloading-reloading cycles at varying capillary suction implied that as a result of the water softening effect, the reduction in capillary suction and changing the local effective stress there is a high possibility of activation and propagation of pre-existing micro fractures. In the numerical modeling phase of this research, fully coupled poro-elastoplastic partially saturated models were developed that included transversely isotropic matrix properties and bed-scale geometry. Inclusion of bed-scale features in the numerical approach provided better analysis options since different properties of the adjacent beds (including different capillary suction change) that can trigger the failure in the planes of weakness (such as the interface between the beds) can be directly included in the model while it is not possible to have that in transversely isotropic numerical modeling. This implies that conventional numerical analysis of geomechanical responses originated from spontaneous imbibition needs to be revisited. Beds-included numerical analyses indicated that since the changes in local effective stress and rock mechanical properties were not the same in adjacent quartz-rich and clay-rich beds, differential volumetric strain along the interfaces between quartz-rich and clay-rich beds would take place which in turn generated induced shear stress components on the interface planes. For the interfaces where total shear stress along them exceeded the shear strength, failure occurred. Comparing the result of micro-geomechanical (bed scale) and macro-geomechanical analysis with the results of numerical modeling at reservoir in-situ conditions would suggest that as a result of post-fracturing spontaneous water imbibition in the studied Montney Formation, the failures/micro fractures would be generated along the interfaces. Then because of the propagation of activated pre-existing micro fractures in the adjacent beds followed by coalescence with the failed interfaces, a complex micro fracture network can be formed. Accordingly, rock mass geomechanical responses and flow properties would be affected which means that any numerical modeling or analytical approach to account for the production, refracturing and any other reservoir-related analysis without considering this fact is under question mark.
Book Synopsis Experimental Studies on the Reservoir Dynamics of Water-based and Gas-based Fracturing Fluids in Tight Rocks by : Xiao Luo
Download or read book Experimental Studies on the Reservoir Dynamics of Water-based and Gas-based Fracturing Fluids in Tight Rocks written by Xiao Luo and published by . This book was released on 2017 with total page 114 pages. Available in PDF, EPUB and Kindle. Book excerpt: Low permeability formations, including shale and tight reservoirs, have contributed over 50% of U.S. annual oil production. Many of these formations are oil productive formations, they include Bakken, Eagle Ford, Marcellus, Permian, and Utica. In order to obtain economic production, large amounts of fracturing fluids are consumed during the hydraulic fracturing treatments, but only a small fraction of the fluid is returned to the surface as flowback. Water-based fracturing fluids may invade the rock matrix in a tight or unconventional reservoir and result in a water block that hinders oil production. To remedy this possibility, gas- and foam-based fluids have been developed. For an oil productive formation, the invasion of gas can also result in oil permeability reduction, i.e. a gas block, but the mechanism and clean up are likely to be different than a water block. As the two fluids exhibit different wetting nature, it is not clear how they compare to each other in a multi-phase flow perspective, such as their impact on the productivity in the short and long term. In this work, we conduct experimental studies the reservoir dynamics of invaded fracturing fluids, reduction in the hydrocarbon permeability, and potential mitigation for cleaning up the fluid block. We scaled down this fluid invasion problem to a laboratory core sample. Water and N2 are injected into a rock matrix to mimic the invasion of slickwater and gas-based fracturing fluids, respectively. We studied the evolution of the oil productivity and flowback versus time during the oil production. The respective performances for different fracturing fluids under different conditions will also be investigated in this study.
Book Synopsis Fluid-shale-proppant Interactions and the Degradation of Hydraulic Fracture Conductivity in the Niobrara Formation by : Jessica G. Iriarte
Download or read book Fluid-shale-proppant Interactions and the Degradation of Hydraulic Fracture Conductivity in the Niobrara Formation written by Jessica G. Iriarte and published by . This book was released on 2017 with total page 93 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Book Synopsis Water-rock Interaction with Fracture Surfaces in a Unconventional Reservoir by : Amber E. Zandanel
Download or read book Water-rock Interaction with Fracture Surfaces in a Unconventional Reservoir written by Amber E. Zandanel and published by . This book was released on 2017 with total page 63 pages. Available in PDF, EPUB and Kindle. Book excerpt: Hydraulic fracturing of unconventional reservoirs in the Powder River Basin in Wyoming and Montana is a growing source of oil and gas production. However, shale and tight-oil reservoirs in the region have high rates of decline in production compared to conventional oil and gas extraction, severely limiting well life. The full reasons for these high decline rates are unclear and have been attributed to a number of causes, including porosity decrease from fines migration. Recent field and experimental studies have shown that water-rock interaction with hydraulic fracturing fluid can cause mineral precipitation in the reservoir subsurface. Experimental studies into water-rock interaction also suggest that reservoirs are sensitive to changes in mineral surface area and to oil adhering to the mineral grains. This study tests the potential effect on water-rock interaction of removing residual oil from unconventional reservoir rock at reservoir conditions as found in the Powder River Basin in Wyoming. Rock samples from the Parkman Sandstone in the Powder River Basin, Wyoming were combined with synthesized formation water at in-situ reservoir conditions and reacted for ~35 days to approach steady-state. A simulated hydraulic fracturing fluid was then injected and reactions proceeded for another ~35 days. Fluid samples were collected throughout the experiment. One experiments uses rocks chemically processed to remove residual oil (low-residual oil, or LRO) and one uses rocks that retain residual oil (high-residual oil, or HRO). All experiments use 0.5–1 cm rock cubes to emulate the interface between fractures and the rock matrix. Analyzed chemistry results from aqueous samples collected during the experiments indicate water-rock interaction with both carbonates and clay minerals. Observation of rock recovered from the experiments shows changes to mineralogy visible in microscope or SEM. Fluid results suggest that unconventional reservoir rock with less residual oil at the mineral face is more prone to carbonate dissolution than reservoir rock with residual oil at the fracture face. Little evidence of precipitation or dissolution was observed on the recovered rock after experiments; however, water-rock interaction at the timescales of these experiments is not likely to cause significant changes to in-situ reservoir porosity or permeability. The water-silicate interaction trend suggests that the fluid chemistry may favor smectite or other clay precipitation at timescales beyond those represented in the experiments.
Book Synopsis Analysis of Natural Gas Production and Fracture Fluids Flowback in Marcellus Shale Using Data Mining Approaches by : Qiumei Zhou
Download or read book Analysis of Natural Gas Production and Fracture Fluids Flowback in Marcellus Shale Using Data Mining Approaches written by Qiumei Zhou and published by . This book was released on 2017 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Marcellus has been development for more than a decade with the application of multi-staged hydraulically fractured horizontal well technology. The technology requires pumping large amount of fracture-fluids and proppant into the target formation at high pressure. The fracture-fluid will then be recovered as aqueous phase during the flowback periods after well shut-in, which can be treated and reused. Sweet spot identification and efficient fracture-fluid flowback management are keys requirement for sustainable and economic development of Marcellus Shale, which can be benefited greatly by optimizing drilling and completion practices, including accurate fracture-fluids flowback prediction. In this work, a systematic study of the geology and engineering factors that influence fracture-fluids flowback, water production, and gas recovery was developed. The complex correlations between gas production and fracture-fluids flowback and produced water provide more understanding about flow mechanism in shale gas. The results suggest that the numbers of hydraulic fracturing stages and well lateral length have significant influence on gas production. The shut-in time and injected proppant volume have the most influence on fracture-fluids flowback. The correlations between gas and fracture-fluid flowback and produced water were different under certain geological conditions and time periods. These knowledges from previous results were used to develop economic analysis regional scale.This work not only will provide the new insights about shale gas well production and fracture-fluid flowback, but also provide a new idea for how to effectively analyze limited field recorded data and to identify the true story behind data.
Book Synopsis The Interaction of Shale/fracture/fluid and Their Influence on Production from an Unconventional Tight Oil Reservoir by : Caleb Conrad
Download or read book The Interaction of Shale/fracture/fluid and Their Influence on Production from an Unconventional Tight Oil Reservoir written by Caleb Conrad and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The interaction of shale/fracture/fluid interactions and the resulting geomechanical behavior of shale oil unconventional reservoirs is becoming of greater interest as the impact of pressure dependent fracture conductivity is better understood. As more operators develop these resources the diversity in the constituents of the shale and the presence of water-sensitive clays require different approach to yield better EUR results. These efficiency gains are more than just placing proppant and identifying the best acreage with good natural fracture systems. By controlling clay/fluid interactions it is possible to improve pressure dependent fracture conductivity response and improve EUR. The focus of this paper is to investigate stress dependent fracture conductivity, shale/fracture/fluid interactions and the potential of more intelligent completions to improve EUR.
Book Synopsis Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations by : Ahmed Alzahabi
Download or read book Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations written by Ahmed Alzahabi and published by CRC Press. This book was released on 2018-07-03 with total page 262 pages. Available in PDF, EPUB and Kindle. Book excerpt: Shale gas and/or oil play identification is subject to many screening processes for characteristics such as porosity, permeability, and brittleness. Evaluating shale gas and/or oil reservoirs and identifying potential sweet spots (portions of the reservoir rock that have high-quality kerogen content and brittle rock) requires taking into consideration multiple rock, reservoir, and geological parameters that govern production. The early determination of sweet spots for well site selection and fracturing in shale reservoirs is a challenge for many operators. With this limitation in mind, Optimization of Hydraulic Fracture Stages and Sequencing in Unconventional Formations develops an approach to improve the industry’s ability to evaluate shale gas and oil plays and is structured to lead the reader from general shale oil and gas characteristics to detailed sweet-spot classifications. The approach uses a new candidate selection and evaluation algorithm and screening criteria based on key geomechanical, petrophysical, and geochemical parameters and indices to obtain results consistent with existing shale plays and gain insights on the best development strategies going forward. The work introduces new criteria that accurately guide the development process in unconventional reservoirs in addition to reducing uncertainty and cost.
Book Synopsis Evaluation and Effect of Fracturing Fluids on Fracture Conductivity in Tight Gas Reservoirs Using Dynamic Fracture Conductivity Test by : Juan Correa Castro
Download or read book Evaluation and Effect of Fracturing Fluids on Fracture Conductivity in Tight Gas Reservoirs Using Dynamic Fracture Conductivity Test written by Juan Correa Castro and published by . This book was released on 2011 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Unconventional gas has become an important resource to help meet our future energy demands. Although plentiful, it is difficult to produce this resource, when locked in a massive sedimentary formation. Among all unconventional gas resources, tight gas sands represent a big fraction and are often characterized by very low porosity and permeability associated with their producing formations, resulting in extremely low production rate. The low flow properties and the recovery factors of these sands make necessary continuous efforts to reduce costs and improve efficiency in all aspects of drilling, completion and production techniques. Many of the recent improvements have been in well completions and hydraulic fracturing. Thus, the main goal of a hydraulic fracture is to create a long, highly conductive fracture to facilitate the gas flow from the reservoir to the wellbore to obtain commercial production rates. Fracture conductivity depends on several factors, such as like the damage created by the gel during the treatment and the gel clean-up after the treatment. This research is focused on predicting more accurately the fracture conductivity, the gel damage created in fractures, and the fracture cleanup after a hydraulic fracture treatment under certain pressure and temperature conditions. Parameters that alter fracture conductivity, such as polymer concentration, breaker concentration and gas flow rate, are also examined in this study. A series of experiments, using a procedure of "dynamical fracture conductivity test," were carried out. This procedure simulates the proppant/frac fluid slurries flow into the fractures in a low-permeability rock, as it occurs in the field, using different combinations of polymer and breaker concentrations under reservoirs conditions. The result of this study provides the basis to optimize the fracturing fluids and the polymer loading at different reservoir conditions, which may result in a clean and conductive fracture. Success in improving this process will help to decrease capital expenditures and increase the production in unconventional tight gas reservoirs.
Book Synopsis Proppant Fracture Conductivity with High Proppant Loading and High Closure Stress by : Matthew Charles Rivers
Download or read book Proppant Fracture Conductivity with High Proppant Loading and High Closure Stress written by Matthew Charles Rivers and published by . This book was released on 2011 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Ultra-deepwater reservoirs are important unconventional reservoirs that hold the potential to produce billions of barrels of hydrocarbons, but also present major challenges. This type of reservoir is usually high pressure and high temperature (HPHT) and has a relatively high permeability. Hydraulic fracturing high permeability reservoirs are different from the hydraulic fracturing technology used in low permeability formations. The main purpose of hydraulic fracturing in low permeability reservoirs is to create a long, highly conductive path, whereas in high permeability formations hydraulic fracturing is used predominantly to bypass near wellbore formation damage, control sand production and reduce near wellbore pressure drop. Hydraulically fracturing these types of wells requires short fractures packed with high proppant concentrations. In addition, fracturing in high permeability reservoirs aims at achieving enough fracture length to increase productivity, especially when the viscosity of the reservoir fluid is high. In order to pump such a job and ensure long term productivity from the fracture, understanding the behavior of the fracture fluid and proppant is critical. A series of laboratory experiments have been conducted to study conductivity and fracture width with high proppant loading, high temperature and high pressure. Proppant was manually placed in the fracture and fracture fluid was pumped through the pack. Conductivity was measured by pumping oil to simulate reservoir conditions. Proppant performance and fracture fluids, which carry the proppant into the fracture, and their subsequent clean-up during production, were studied. High strength proppant is ideal for deep fracture stimulations and in this study different proppant loadings at different stresses were tested to see the impact of crushing and fracture width reduction on fracture conductivity. The preliminary test results indicated that oil at reservoir conditions improves clean-up of fracture fluid left in the proppant pack compared with using water at ambient temperature. Increasing the proppant concentration in the fracture showed higher conductivity values in some cases even at high closure stress. The increase in effective closure stress with high temperature resulted in a significant loss in conductivity. Additionally, the fracture width decreased with time and increased effective closure stress. Tests were also run to study the effect of cyclic loading which is expected to further decrease conductivity.
Book Synopsis Fundamentals of Fractured Reservoir Engineering by : T.D. van Golf-Racht
Download or read book Fundamentals of Fractured Reservoir Engineering written by T.D. van Golf-Racht and published by Elsevier. This book was released on 1982-04-01 with total page 729 pages. Available in PDF, EPUB and Kindle. Book excerpt: In the modem language of reservoir engineering by reservoir description is understood the totality of basic local information concerning the reservoir rock and fluids which by various procedures are extrapolated over the entire reservoir. Fracture detection, evaluation and processing is another essential step in the process of fractured reservoir description. In chapter 2, all parameters related to fracture density and fracture intensity, together with various procedures of data processing are discussed in detail. After a number of field examples, developed in Chap. 3, the main objective remains the quantitative evaluation of physical properties. This is done in Chap. 4, where the evaluation of fractures porosity and permeability, their correlation and the equivalent ideal geometrical models versus those parameters are discussed in great detail. Special rock properties such as capillary pressure and relative permeability are reexamined in the light of a double-porosity reservoir rock. In order to complete the results obtained by direct measurements on rock samples, Chap. 5 examines fracturing through indirect measurements from various logging results. The entire material contained in these five chapters defines the basic physical parameters and indicates procedures for their evaluation which may be used further in the description of fractured reservoirs.
Book Synopsis Displacement of Water by Gas in Propped Fractures by : Jaskaran Singh Parmar
Download or read book Displacement of Water by Gas in Propped Fractures written by Jaskaran Singh Parmar and published by . This book was released on 2013 with total page 111 pages. Available in PDF, EPUB and Kindle. Book excerpt: Inefficient recovery of fracturing water used in multi-stage hydraulic fracturing operations is a growing industrial concern. Non-recovered water can be trapped in the tight rock matrix and/or in the complex fracture network. Trapped water can block the gas flow and damage the reservoir. This study reports results of various drainage experiments conducted to identify the factors controlling water displacement in propped hydraulic fractures. We conduct two sets of drainage experiments. First set of experiments are conducted by using a proppant packed column which is saturated with frac-fluid. These experiments are used to investigate the role of proppant and fluid characteristics on fluid recovery. Second set of drainage experiments are conducted in a physical fracture model. These experiments are designed to investigate the role of gravity, drawdown, surface tension and proppant wettability on fluid recovery. The results of this study suggest that gravity plays a dominant role in fracture cleanup and that water cleanup in fractures below well may be inefficient. Increasing the drawdown does not improve water recovery. Reducing surface tension and using treated hydrophobic proppant improves the sweep efficiency and in turn the load recovery.
Book Synopsis The Effects of Fracture Orientation and Anisotropy on Hydraulic Fracture Conductivity in the Marcellus Shale by : Mark John McGinley
Download or read book The Effects of Fracture Orientation and Anisotropy on Hydraulic Fracture Conductivity in the Marcellus Shale written by Mark John McGinley and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Production of hydrocarbons from low-permeability shale reservoirs has become economically feasible thanks in part to advances in horizontal drilling and hydraulic fracturing. Together, these two techniques help to create a network of highly-permeable fractures, which act as fluid conduits from the reservoir to the wellbore. The efficacy of a fracturing treatment can best be determined through fracture conductivity analysis. Fracture conductivity is defined as the product of fracture permeability and fracture width, and describes both how much and how easily fluid can flow through fractures. It is therefore directly related to well performance. The goal of this work is to explore fracture conductivity of Marcellus shale samples fractured in both horizontal and vertical orientations. The Marcellus shale, located primarily in Pennsylvania, Ohio, West Virginia, New York, and Maryland, is the largest gas-bearing shale formation in North America, and its development has significant implications on regional economies, the northeast United States' energy infrastructure, and the availability of petrochemical plant feedstock. In this work, a series of experiments was conducted to determine the propped fracture conductivity of 23 different samples from Elimsport and Allenwood, Pennsylvania. Before conductivity measurements were taken, the pedigree of samples was verified through XRD analysis, elastic rock properties were measured and compared against literature values, and fracture surface contours were mapped and measured. Fracture conductivity of both horizontally and vertically-fracture samples was determined by measuring the pressure drop of nitrogen gas through a modified API conductivity cell. Results show that fracture conductivity varies as a function of fracture orientation only when anisotropy of the rock's mechanical properties is pronounced. It is hypothesized that the anisotropy of Young's Modulus and Poisson's Ratio play a significant role in fracture mechanics, and therefore in the width of hydraulically-induced fractures. Ultimately, the experiments conducted as part of this work show that fracture conductivity trends are strongly tied to both proppant concentration and the rock's mechanical properties. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/155300
