Day 3 Wed, September 26, 2018最新文献

{"title":"Present Day Softskills Needs and Views – 2017 SPEI Survey Results","authors":"S. Cheung, Peggy Rijken, E. Agbor","doi":"10.2118/191619-MS","DOIUrl":"https://doi.org/10.2118/191619-MS","url":null,"abstract":"\u0000 This paper documents the results from a SPEI survey that was distributed in October 2017 to gauge the members’ Softskills needs and preferences. We received approximately 1100 responses from 72 countries. This paper shows the survey statistics and shares the actions the SPEI Business Management and Leadership Committee (BML) (previously known as the Softskills committee) will consider in response to the survey results.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"381 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125244296","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Asphaltene Gradients and Connectivity Analysis in Reservoirs, Asphaltene Onset Pressure, Bitumen and Tar Mats All Treated Within a Simple, Unified Chemistry Treatment","authors":"O. Mullins, H. Dumont, Julia C. Forsythe, Li Chen, V. Achourov, John Meyer, Y. Johansen, J. Rinna, B. Winkelman, T. Wilkinson, R. Primio, H. Elshahawi, Canas Jesus Alberto, S. Betancourt, A. Pomerantz, J. Zuo","doi":"10.2118/191582-MS","DOIUrl":"https://doi.org/10.2118/191582-MS","url":null,"abstract":"\u0000 Asphaltenes can be dispersed in crude oils in 3 different forms; molecules, nanoaggregates (of molecules) or clusters (of nanoaggregates); these forms are codified in the Yen-Mullins model and relate to the extent of solvency of the asphaltenes in the crude oil. Many reservoir studies are used here to show the systematic behavior of the specific asphaltene species in crude oil and the corresponding magnitude of the asphaltene (and viscosity) gradients. In addition, the specific asphaltene species is related to the chemical origin controlling asphaltene onset pressure (AOP) and tar formation and depends on 1) the quality of the live crude oil solvent for asphaltenes and 2) the concentration of asphaltenes. Elevated quantities of solution gas of a reservoir crude oil significantly reduce the solvency of asphaltenes in crude oil. For low concentrations and/or good solvency, asphaltenes are dispersed in crude oils as molecules with small gradients (unless there are large GOR gradients). For moderate concentrations and/or moderate solubility, asphaltenes are dispersed as nanoaggregates with intermediate (gravity) gradients of asphaltenes. With large concentrations and/or poor solvency, asphaltenes are dispersed as clusters with very large gradients in reservoirs. These crude oils can also exhibit higher asphaltene onset pressures and/or phase separated bitumen or tar in the reservoir depending on the origin of asphaltene cluster formation. Secondary gas charge into oil reservoirs can yield tar and/or a high AOP. The effect of biodegradation on these factors is also discussed. The systematics presented here are helpful in understanding a variety of reservoir concerns associated with asphaltenes.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"43 2","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113972257","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Comprehensive and Comparative Experimental Study of the Effect of Wettability on the Performance of Near Miscible WAG Injection in Sandstone Rock","authors":"Bashir Alkhazmi, S. A. Farzaneh, M. Sohrabi, J. Buckman","doi":"10.2118/191477-MS","DOIUrl":"https://doi.org/10.2118/191477-MS","url":null,"abstract":"\u0000 Accurate predictions of the performance of near-miscible water-alternating-gas (WAG) injection under different wettability conditions using the current commercial reservoir simulators are difficult and associated with significant uncertainties. Reliable experimental data are needed to tune reservoir simulators and optimize the performance of WAG injection in the field.\u0000 In this study, a series of coreflood experiments has been carried out, under ultra-low gas/oil interfacial tension (IFT) level, on the same sandstone core with three different wettability conditions; water-wet, weakly-water-wet and mixed-wet. We present the performance of WAG injection, in terms of oil recovery and differential pressure, under near miscible and weakly water-wet conditions in a homogenous sandstone rock and the comparisons of these results with those in water-wet and mixed-wet systems. Each WAG injection experiment started with a water flood period, followed by three cycles of gas and water injections. To minimize experimental artefacts, the same long and large sandstone core (2in × 2ft) was used in all of the coreflood experiments presented in this paper as well as the same core preparation and experimental procedure were repeated.\u0000 Analysis of the average oil recovery profile, for the weakly water-wet core, shows that about 62% (IOIP%) of recovered oil was achieved by the initial water flood, whereas 81.5 % (Sorw%) of the remaining oil was recovered by the alternation of water and gas injection cycles post-waterflooding. Our experimental results revealed that the performance of secondary water flood increased as the direction of wettability changed from water-wet to mixed-wet, passing through weakly water-wet conditions. As a result, the remaining oil saturation in the water-wet system is about a factor of two larger than that in its mixed-wet counterpart, whereas its value in the weakly water-wet system is lying on between that of the other two wettability systems. The oil recovery efficiency by tertiary gas injection cycles, under near miscible and the three different wettability conditions, increased as further WAG cycles were carried out. However, their oil production rates decreased when wettability changed from water-wet towards mixed-wet system.\u0000 Although the ultimate oil recoveries were 96.7 %, 93% and 88.5 % (IOIP%) in mixed-wet, weakly-water-wet and water-wet respectively, the overall oil recovery performance (post-waterflooding) was slightly higher in water-wet, then less in weakly water-wet and much lower in mixed-wet system. Comparison of the water and gas injectivity behaviors based on their DP values during near miscible WAG injection revealed that water and gas injectivity increased when core wettability changes from water-wet towards mixed-wet, passing through weakly water-wet conditions.\u0000 Most of the existing three-phase relative permeability correlations were developed for water-wet systems; however, they are widely used for non-water-wet res","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"398 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132947066","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Implication of Oil/Brine/Rock Surface Interactions in Modeling Modified Salinity Waterflooding in Carbonate and Sandstone Reservoirs","authors":"A. Sanaei, K. Sepehrnoori","doi":"10.2118/191639-MS","DOIUrl":"https://doi.org/10.2118/191639-MS","url":null,"abstract":"\u0000 It is widely accepted that oil recovery during waterflooding can be improved by modifying the composition of the injected brine. A typical approach is diluting the formation water to a specific lower salinity. However, various recent experimental studies have shown the adverse effect of water dilution on oil recovery which depends on the rock composition and oil properties, especially in carbonates. In this study we investigated the effect of water chemistry on wettability and oil recovery by considering the complex interplay interaction of rock, brine, and oil system.\u0000 We used a coupled in-house compositional simulator and geochemical (IPhreeqc) framework for this study. Using this simulator we were able to capture true physics of the modified salinity waterflooding process. We modeled the wettability alterations as a function of zeta-potential between the oil-brine and brine-rock system. We calculated the surface charge at oil-brine and rock-brine interfaces as a function of surface complexation, ion exchange, oil acid and base numbers, and rock composition. Moreover, using DLVO theory, we calculated disjoining pressure and contact angle in a brine/oil/rock system and compared with recently published experimental data. For sandstones we assumed that multi-ion exchange and double layer expansion are the main mechanisms of modified salinity waterflooding. For carbonates, surface-charge change is the considered mechanism for wettability alteration. In order to validate our simulation approach, the results of our simulations were compared with experiments selected from recently published corefloods.\u0000 The results of this study indicated that DLVO theory can be used to qualitatively analyze the effect of water chemistry on wettability alteration in an oil/brine/rock system. By changing the water composition and zeta potentials we observed the trend of changing toward less attractive forces and a more water-wet surface. We observed that the divalent cations contribute more to wettability alteration as compared to monovalent cations. Moreover, the results of contact angle and comparison with the experimental published data indicated that although the calculated and measured values are not the same, but the change in the contact angle as the system changes is in a good agreement with experiment data. Our zeta potential calculations based on surface complexation model reproduced the experimental data of oil/brine, brine/calcite, and brine/sandstone zeta potential measurements. Our results of coreflood history-matching indicated that for sandstones, diluting the formation brine results in incremental oil recovery due to double layer expansion and multi-ion exchange. In carbonates, the change in surface charge and consequently contact angle as a result of changes in water chemistry is the underlying mechanism of low salinity waterflooding in carbonates. We believe this is the first study that a comprehensive compositional reactive transport simulator is ","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"92 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133611205","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Investigation of Proppant Transport in Friction Reducer Fluid Systems Utilizing a Large Slot Flow Apparatus","authors":"S. Drylie, R. Duenckel, R. Barree, B. Hlidek","doi":"10.2118/191720-MS","DOIUrl":"https://doi.org/10.2118/191720-MS","url":null,"abstract":"\u0000 Current unconventional reservoir development depends on an assumed network of induced fractures created by hydraulic fracturing operations that facilitate production. In many cases natural fractures are linked to the created fractures and also contribute to production. Only in some fraction of the created and natural fracture network will proppant have been placed during the fracturing operation. In order to model the production from these fracture systems, reservoir and completion engineers often make optimistic assumptions about propped fracture half-lengths based on inaccurate expectations regarding proppant transport and proppant pack behavior. This work addresses proppant transport behavior by presenting results from large-scale lab testing of proppant transport with a range of fluid rheologies utilizing a slot flow apparatus.\u0000 Proppant transport tests were performed at multiple rates and proppant concentrations utilizing a 4-foot by 16-foot fracture slot. The primary testing objective was to compare proppant transport in friction reducer (FR)-based fluids against previously published results and other work that has been performed in this apparatus. Additional tests using guar based fluids of a similar nominal viscosity will be used for comparison and to demonstrate the need for other rheological properties for planning and predicting completion results.\u0000 The results of this testing will provide a more realistic description of proppant transport. Through this enhanced understanding, reservoir and completion engineers will be able to make improved assumptions about propped fracture dimensions that will drive better decisions regarding fracture design, improving recovery, optimizing spacing, and field development while reducing the need for costly future interventions and refracturing treatments. After an introductory review of important conclusions from previously published work performed in this and other slots, the results of this testing will be used to evaluate the validity of these conclusions. Additionally, relationships and interactions between viscosity, rate, proppant concentration, and other fluid properties will be established and reviewed to facilitate the development of improved models for proppant transport in unconventional reservoirs.\u0000 Much of the earlier lab work performed in slots of this scale was performed when crosslinked fluids were the preferred fluids in almost all applications. Since that time, the industry has shifted to a preference for slickwater fluids and other systems of much lower viscosity in the hope that increased velocity would make up for the loss in viscosity. This work will highlight where this hope is unrealized and when other fluid properties make the drop in viscosity less important than expected.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131991436","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Systematic Uncertainty Analysis of Reservoir Image from New Generation LWD Azimuthal Resistivity Measurements","authors":"Qiuyang Shen, Jiefu Chen, Hanming Wang","doi":"10.2118/191710-MS","DOIUrl":"https://doi.org/10.2118/191710-MS","url":null,"abstract":"\u0000 A new generation of logging-while-drilling (LWD) azimuthal resistivity tools has emerged in the market since a few years ago. With the depth-of-detection (DoD) more than 100 feet, the application of the new service widely ranges from well placement, reservoir mapping, geo-stopping, landing fault detection to salt edge detection, etc. The azimuthal propagation resistivity tools all use the concept of multi-spacings, multi-frequencies, and multi-components. The measurements acquired by the new generation tools are much richer than those by the conventional azimuthal resistivity LWD tools with DoD around or less than 20 feet. However, due to the complexity of the measurement physics and data interpreting process, without a thorough understanding of the uncertainty of the measurements, the operators do not have sufficient confidence in this service as much as expected from service providers.\u0000 To promote the understanding of the technology, in this paper, we evaluate the ultra-deep azimuthal resistivity tool by systematic sensitivity study, and uncertainty quantification on reservoir image using a new statistical method. The sensitivity of the measurements to the dip angle, the anisotropy, the layer boundaries, and the formation resistivity is essential to assess the capability of the technology for practical applications. A group of studies are conducted to evaluate the sensitivity under several common situations including homogeneous isotropy formation, homogeneous anisotropy formation, and layered formation. The information content of the measurements and the proper use of the measurements are clearly demonstrated.\u0000 The interpretation of ultra-deep azimuthal resistivity measurements stresses on the search of true earth model parameters within DoD from borehole. The unique solution can hardly be found due to local minima problem. The statistical methods governed by Bayesian theorem can search for the statistical distribution, hence, tell the uncertainty of interpreted model. Additionally, a novel statistical analysis, the trans-dimensional Markov Chain Monte Carlo (tMCMC) method is proposed in this paper to handle multi-model uncertainty quantification problem. A set of 1D formation models, proposed by SPWLA Resistivity Special Interest Group (RtSIG) chapter, are used to quantify the uncertainty of the bed boundary position, the formation resistivity, the dip angle through. The probability maps of the boundary interface and the distributions of the resistivity profile can be extracted from the statistical characteristics of the posterior predictive distribution (PPD). The exercise of the statistical solver on the formation models recommended by SPWLA RtSIG demonstrates that the uncertainty quantification techniques can be crucial to assess the azimuthal propagation resistivity technology. A field example from a subsea gas well of Wheatstone liquefied-natural-gas project in Western Australia is used to confirm the importance of the uncertainty quan","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121944763","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Capping Stack Technology Comes of Age","authors":"A. Cuthbert","doi":"10.2118/191687-MS","DOIUrl":"https://doi.org/10.2118/191687-MS","url":null,"abstract":"\u0000 While several years have passed since the 2010 Gulf of Mexico (GOM) source control incident that caused a six-month drilling moratorium, the industry likely believes it is fully prepared to prevent or mitigate the effects of a similar incident in a timely manner. However, installing a source control device on a blowing well is a technically complex exercise, one that has never been performed; while performing such an operation, one should consider challenges posed by metocean conditions, coupled multiphase hydrodynamics, and multibody interactions that complicate the deployment and docking of a capping stack onto a subsea wellhead.\u0000 The latest gate-valve technology intended to close against flow presents a more compact option for rapid capping than unwieldy ram-based systems. The speed of deployment of the lighter capping stack is attributed to the availability of suitable aircraft, lifting equipment at the airport or dockside, and an ample supply of suitable deployment vessels. The underlying logistical issues that prevent rapid responses to subsea incidents have not, for the most part, been addressed until now. A development differentia in capping-stack technology has been necessary to exact the speed of response that the industry calls for and to meet the expectations of stakeholders and the general public. Fortunately, the industry now has access to technology that can be deployed to a source control incident in any global location in a matter of days.\u0000 Sophisticated, high-fidelity simulation, hitherto unavailable, incorporates metocean sea state and uses coupled multiphase hydrodynamics and multibody interaction effects of vessel motion, suspension system dynamics, and the hydrodynamics of the capping system within the unstable blowout forces to create an accurate analysis that addresses plume and landing-force analysis at the wellhead. Coupled with the tools to accurately simulate the effects of the force dynamics from surface to wellhead to complete the entire process, the advances accompany the new capping design and enhance the ability to determine landing capability, heralding further advancement in source control technology and techniques.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122755810","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Case Study on Fluorocarbons Interior Coating for Anticorrosion and Wax-Deposition Inhibition in ASP Flooding Production","authors":"Yang Liu, X. Zhuge, Zhihua Wang, Bin Huang, Xinpeng Le","doi":"10.2118/191656-MS","DOIUrl":"https://doi.org/10.2118/191656-MS","url":null,"abstract":"Under the hovering background of low oil price, alkali/surfactant/polymer (ASP) flooding technique is proven to be vitally important for enhance oil recovery (EOR) in oil industry. The production practice in Daqing Oilfield (China) shows that the EOR of ASP flooding is more than 10% original oil in place (OOIP) over conventional polymer flooding. However, the problems of corrosion and scaling that surface facilities and pipelines encounter with still remain very challenging in ASP flooding production, especially in the strong alkali (NaOH) ASP flooding fields. In the industrialized-application of ASP flooding process, these problems are drawing more and more attention.\u0000 The corrosion behaviors of surface facilities and pipelines that utilized in strong alkali (NaOH) and weak alkali (Na2CO3) ASP flooding fields were characterized with the integration of production practice, the general anticorrosion measures and the failure of internal coating in fields were presented and demonstrated. A coating solution for fluorocarbons surface treatment was proposed and tested in this case study. The performance of interior surface coatings including corrosion-scaling resistance, wax-deposition inhibition and drag reduction was evaluated with the existence of ASP chemicals in produced emulsions, and the mechanism was discussed from both film-forming and reducing surface energy aspect. The distinct competitive advantage of fluorocarbons interior coating for anticorrosion and wax-deposition inhibition in ASP flooding production was presented.\u0000 Considerable corrosion and scaling were created and covering the surface facilities such as the storage tanks of ASP chemicals, the pipelines for injection and production, and the heating furnaces in ASP flooding production. Both of the applied physical and chemical protection measures are facing to the challenges of service life, potential environmental threats and unpredictable cost-effectiveness. High bond energy and strong chemistry inertia of fluorinated resins can prevent the coating structure from being destroyed and develop flexibility and weatherability of the coating. The pore resistance and shielding performance of fluorocarbon coating in corrosion environment highlighted actually result from the superior mechanical properties, super-hydrophobicity, and self-cleaning performance. Furthermore, the low surface energy and low coefficient of friction of the fluorocarbon interior coating provide the possibility of pipeline wax-deposition inhibition and drag reduction. The maximum wax-deposition inhibition rate and the maximum drag reduction rate reached 46.42% and 60.00% respectively for high-viscosity ASP flooding produced emulsions in this case study. The reasonable coating configurations and process are certainly indispensable in the potential applications of fluorocarbons surface technology.\u0000 The case study contributes to the existing knowledge in the implementation of chemical EOR project for a green oilfield dev","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125311486","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Estimating Gas Relative Permeability of Shales from Pore Size Distribution","authors":"B. Ghanbarian","doi":"10.2118/191878-MS","DOIUrl":"https://doi.org/10.2118/191878-MS","url":null,"abstract":"\u0000 Modeling shale gas relative permeability, krg, has numerous practical applictaions, particularly in gas exploration and production in unconventional reservoirs. krg is a key petrophysical quantity for accurately determining recovery factor and production rate. In the literature, a few theoretical models developed to estimate krg are based upon either a \"bundle of capillary tubes\" conceptual approach or a combination of universal scaling laws e.g., from percolation theory. The former is a severely distorted idealization of porous rocks, while the latter is, generally speaking, valid near the percolation threshold and/or in rocks with narrow pore-throat size distribution. Although the effective medium approximation has been successfully applied to model wetting- and nonwetting-phase relative permeabilities in conventional rocks, to the best of the author's knowledge, it has never been used to estimate krg in unconventional reservoirs. Therefore, the main objective of this study is to develop a theoretical model based on the effective-medium approximation, an upscaling technique from statistical physics, to estimate shale gas relative permeability from pore-throat size distribution. In this study, we presumed that pore-throat sizes conform to a truncated log-normal probability density function. We further presumed that gas flow under variably-saturated conditions is mainly controlled by two mechanisms contributing in parallel: (1) molecular flow and (2) hydraulic flow. The total conductance of a single pore (gt), therefore, was equal to the summation of the molecular flow conductance, gm, and the hydraulic flow conductance, gh (i.e., gt = gm + gh). We then invoked the governing equation from the effective-medium approximation to determine effective conductances and, accordingly, gas relative permeabilities at various saturations. Results showed that krg varies as the log-normal distribution parameters standard deviation (σ) and geometric mean pore radius (rm) alter. By comparison with two- and three-dimensional pore-network model simulations, we found that the proposed model estimated gas relative permeability accurately, particularly in three dimensions. We also estimated krg from the pore-throat size distribution derived from measured mercury intrusion capillary pressure (MICP) curve for three experiments (i.e., Eagle Ford, Pierre, and Barnnet) and found that krg of Barnnet was remarkably less than that of Pierre and Eagle Ford.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"33 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126388435","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Fit-for-Purpose Water Treatment in Permian Shale – Field Data, Lab Data and Comprehensive Overview","authors":"J. Walsh, R. Sharma","doi":"10.2118/191529-MS","DOIUrl":"https://doi.org/10.2118/191529-MS","url":null,"abstract":"\u0000 Sourcing water for hydraulic fracturing and disposing of produced water are well-known constraints and significant cost items in the development of shale formations in the Permian Basin. Utilizing a water life-cycle approach, some of the produced water can be treated and reused. However, there is usually more produced water than needed and some must be disposed, typically by injection into a disposal well. Whether the water is to be reused or disposaed, it must be treated to some extent. Given the volumes of water involved, treatment technology must be robust and inexpensive. This suggests that the selected technology should be tailored to the characteristics of the water and the quality requirements of the final purpose (reuse or disposal).\u0000 This paper starts with characterization of produced water from a few Permian shale fields and proceeds to the selection of appropriate conventional, robust and low cost treatment systems. Using this approach, fit-for-purpose treatment systems have been implemented in the field. Impairment problems with reuse and disposal of this treated produced water have decreased.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124382572","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}