bluuebunny/crossref_metadata_2025_split huggingface dataset:
In-situ Measurement of Fracturing Parameters from Communication Between Horizontal Wells
Authors: Daneshy Ali , Pomeroy Mark 
Published: October 2012

Abstract
The study reported in this paper presents direct and in-situ measurement of critical fracture properties using analysis of downhole pressure data recorded in a horizontal well. The first well (Monitor Well) was fractured in multiple stages, produced, and later instrumented for downhole pressure measurement while a second (Active Well) was being fractured. Review of the pressure data from the Monitor Well showed intermittent communication between the two wells. Analysis of this data provides direct indications of in-situ fracture conductivity. Signatures of other non-intersecting fractures (shadowing) were also detected in the Monitor Well. This data is used for estimation of fracture orientation, length, and propagation pattern. Some of the results obtained from these measurements include;
Two types of communication were observed between wells connected via hydraulic fractures; a shadowing effect, and direct hydraulic communication Fracture conductivity was very high during fracture communication and then decreased rapidly with time as fractures closed. The connection between the two wellbores was entirely lost soon after pumping stopped. Fractures extended vertically from Three Forks into the Middle Bakken The fracture growth pattern in this case study can best be classified as off-balance with low to medium branching and shear fracturing.
Given the operational simplicity of these measurements and accuracy of its results, the technique is recommended as a tool for fracture diagnosis.
Flow Induced Vibration Of Subsea Gas Production Systems Caused By Choke Valves
Authors: Ligterink N. E. , de Groot R. , Gharaibah E. , Slot H. J. 
Published: October 2012

Abstract
In the design of subsea flow systems the integrity and reliability is paramount. As the equipment must be designed to operate at a large variety of conditions, inherent to the many processes, evaluation of the integrity is complex. Flow induced pulsations and vibrations can cause serious design and production problems, especially in subsea gas production systems. Mechanical vibrations can be induced by internal and external flow through a complex process that is affected by numerous factors such as the piping geometry, flow conditions and fluid properties.
Wellhead choke valves are commonly used to control the flow of fluids from the reservoir. During production, significant noise is produced by the flow as it passes through the choke. The noise is of broadband nature: it can be described by pressure pulsations with frequencies over a large range (1-20 kHz). The subsequent vibration levels can become significant when the pressure pulsations match with a certain acoustic or mechanical resonance mode of the production piping, and can lead to an increased risk of failure of nearby equipment.
The paper describes a method to examine the mechanical loads on nearby equipment due to the vibrations induced by the usage of a wellhead choke by the means of Computational Fluid Dynamics (CFD) simulations and Finite Element Modeling (FEM). Numerical experiments were performed on a generic piping system consisting of standard pipes and bends as well as a fictive ensemble of sensor block and choke valve to explore: 1) the acoustic eigenmodes of the piping, 2) the mechanical eigenmodes of the piping and equipment, and 3) the resulting mechanical loads on the subsea equipment.
It is shown that typical frequencies characteristic of noise related fatigue are such that the number of cycles, easily reaching 1010 within a few months, can be regarded as the primary source instead of the maximum stress levels. Some aspects are not considered in the current approach, such as the effect of the medium and the surrounding. These will lead to slightly lower cyclic stress estimates, and will therefore not invalidate the presented method as a worst case estimation of noise induced vibrational stresses.
Development and Practical Application of a Chemical Hazard Rating System
Authors: Hepburn Krista 
Published: October 2012

Abstract
In order to address the ambiguous nature of the popular terms "environmentally acceptable" and "low toxicity" as they relate to chemical technology, a number of hazard classification and assessment systems were researched. The need for a quantitative determination of the health, safety, and environmental (HSE) impact of well stimulation chemicals was identified, and a meaningful and robust scoring system was developed for that purpose. Discussion of the development of this Chemical Hazard Rating System will include an explanation of the hazards assessed, the classification method, and the scoring framework. Application of the rating system to improve the HSE profile of stimulation fluids was a priority. The system was used to rate the HSE impact of an acid spearhead additive blend frequently used prior to hydraulic fracturing treatments in the Eagle Ford formation in South Texas. Alternative candidate products were identified for use in a new acid spearhead additive blend, based on the HSE impact scores as well as performance testing results. Data from laboratory testing of the improved acid spearhead additive blend will be summarized and presented. The relative cost of the two blends will be discussed, as this project illustrates that contrary to common assumptions, improving the HSE impact of a blend does not necessarily result in significant cost increases. The blend was optimized for the Eagle Ford and implemented with great success in the field.
Rapid Digital Technology Roadmap Deployment in a Growing Unconventional Business
Authors: Sparks Charles J. , Hall Ben R. 
Published: October 2012

Abstract
Delivering useful production information to the right people at the right time can be a challenging proposition in the oil and gas industry. As XTO Energy has grown rapidly through acquisition and drill bit, close engagement between the IT and business organizations has been critical to effectively deliver flexible, scalable software platforms to support various business needs and workflows with rapid setup of new assets.
The result is a standardized yet flexible technology roadmap from the wellhead to the desktop integrated with business operations functionality demands that is as simple as possible, delivering information transparency and utility to the multiple end users including operations, production engineering, regulatory, production accounting, and management.
This paper reviews how XTO Energy has deployed and utilized technology to maximize flexibility in support of growth while providing a stable reliable digital technology platform to serve business requirements, and shares lessons learned.
Evaluating the Impact of Fracture Proppant Tonnage on Well Performances in Eagle Ford Play Using the Data of Last 3-4 Years
Authors: Gao Chao , Du C. Mike 
Published: October 2012

Abstract
Since 2008, horizontal wells completed with multi-stage hydraulic fracturing have dramatically boosted Eagle Ford production. Due to high drilling and completion costs, operators have been trying to improve development economics by optimizing the stimulation treatments. This paper presents a look-back analysis on the stimulation treatments performed by different Eagle Ford operators from 2008-2012 using data mining methodologies, focusing on how proppant tonnage has impacted early-time production of their Eagle Ford wells. The Eagle Ford wells have been observed having high decline rates and the early time production performance evaluation will be critical in project economics evaluations and EUR forecasts. The results of this look-back analysis may be used for field development optimization, where to drill and how much proppant should be pumped in each of different areas of Eagle Ford play.
The focus of this paper is to present how proppant tonnage could impact the early time production performance. However, there are many variables affecting the early time performance of Eagle Ford wells. In this paper, we present data using bubble maps, contour maps, grid maps and scatter plots to show how some major geological and reservoir engineering variables could affect the early time performance of the Eagle Ford wells. The wells with similarities are grouped in order to minimize the variation of geological variables and other engineering variables and to derive consistent correlations between proppant tonnage and early time performances in different well groups. We present data in different well groups to show the correlations between proppant tonnage and early time well performance.
For this study, the authors built a database of 3000+ Eagle Ford wells (including 2300+ horizontals). The authors found that it was very challenging to clean the public data and reformat it to a presentable manner.
Assessment of Artificial Lifts for Oil Wells in Egypt
Authors: Ghareeb M. , Ellaithy W. F. , Zahran I. F. 
Published: October 2012

Abstract
One of the challenges facing the Egyptian oil industry is to increase production and maximize reserves especially in mature and marginal fields.
The fast and continuous development in artificial lift technology plays a role in solving these problems. Recent improvements in technology, automation and metallurgy have reduced lifting costs through system components that resist hostile environments, optimize power usage, and improve reliability allowing profitable production from previously uneconomic fields or wells.
Since the oil industry first emerged in Egypt, over 200 oil and gas fields have come on-stream. Natural producing wells represent less than 9% of this total; other wells are lifted artificially.
This paper will present the history, present day, and the future application of artificial lift systems in Egyptian oil fields, covering the main problems encountered in the operation of each single system of artificial lift including the actions taken to overcome or eliminate these problems. Special emphasis will be given to marginal and mature oil fields because of the economical limitations accompanied with development costs.
Vector Field Based Fault Modelling and Stratigraphic Horizons Deformation
Authors: Bouziat Antoine 
Published: October 2012

Abstract
Consequent choices during hydrocarbon exploration and field developement depend on 3D numerical models of the main geological interfaces and the major faults in the area of interest. Such structural models provide decisive informations like reservoir rock volume or compartmentalization, and are unavoidable stages to build the reservoir grids used for resources estimation, flow simulations and well planning. However, these models need to be continually modified, either to integrate new information from well drilling and production history or to consider several hypotheses about the most uncertain features of the fault network. To do so, petroleum engineers involved in reservoir modeling need flexible and efficient tools to easily edit parts of structural models while preserving their general consistency.
In a first step to handle structural model edition challenges, we propose a new way to numerically model a fault object and deform previously modelled stratigraphic horizons. This method is inspired by the "Vector Field based Shape Deformations" (VFSD ) techniques used by the Computer Graphics community. Our approach considers a fault as a 3D vector field, interpolated thanks to several scalar fields linked to the fault geometry and few scattered data points if available. This vector field is then integrated into path lines able to drive the deformation of the surrounding objects in a purely geometrical manner. The so-obtained deformation is limited to an influence region neighboring the fault and can affect several horizons simultaneously in a consistent and reversible way. Moreover, self-intersections can be prevented and both the first order smoothness and the fine-scale features of the deformed horizons are conserved.
The vector field interpolation methodology we present is based on a user-defined conceptual model for deformation attenuation and a direction constraint on the displacement. It was implemented in common geomodelling software. The resulting tool is applicable on a wide range of fault geometries, and can be added as a new exit condition for fault network stochastic simulation algorithms. Last, some derived applications, related to salt diapir modelling or paleotopography restoration, are also conceivable.
Application of Nanotechnology on Borehole Wall Stability in Gas-Liquid Medium Transition during Gas Drilling
Authors: Xu Zichen 
Published: October 2012

Abstract
Gas drilling has many advantages such as high drilling speed, low damage to reservoir and avoiding circulation lose, etc. However, when gas drilling encounters geological risks, drilling fluid must be filled, which may lead to serious borehole wall collapse. These problems severely restrict the application of gas-drilling technology. Thus, this paper puts forward using nano technology to reverse the wetting characteristics of borehole-wall surrounding rock before filling water based drilling fluid into the well. In this way, the capillary effect can prevent further penetration of drilling fluid, and avoid the swelling of shale and propagating of fractures on the surrounding rock. The strength of the borehole wall can be improved by taking advantage of this technology. The author puts forward that the application of the high-speed gas current to atomize the solution. The atomized solution will carry nano wetting reverse agent and anti-swelling agent rise with gas along borehole wall. Instead of the previous research method from perspective of drilling fluid, this technology can directly change the surface character of fracture surface with small amount of treating agent to avoid the propagating of fractures. Besides, the technique can effectively reduce the friction of the drill string and the impact of the drill string on the borehole wall. The technology is expected to achieve the goal of keeping the wellbore stability in gas liquid medium transition during gas drilling process.
Oil Shale Technology and Efficient Utilization of Oil Shale Resources in Egypt
Authors: Khaled Mohamed Shafik 
Published: October 2012

Abstract
In The Name of God the Merciful
The availability of energy resources is of paramount importance to society. The greatest challenge facing the energy sector today is how to meet the rising demand for energy and on the other hand, the depletion of crude oil resources. To solve this dilemma, greater efforts should be devoted to develop alternative energy resources such as oil shale as a supplement of conventional oil supplies.
However combinations of high oil prices, improved extraction technologies and increasing energy depend have reignited interest oil shale industry.
Oil shale is a rock that contains kerogen, an organic substance that breaks down when heated to yield combustible liquids, gases, and solids. The liquid product – crude shale oil can be transformed into a replacement for conventional crude. Shale oil is expensive to produce, and it has never been able to compete with conventional crude for very long time. However, crude prices have risen in the past few years and are expected to stay high which could make oil shale development practical. The quality of oil shale is either expressed by its heating value or the amount of shale oil that can derived from it liter/ton. Oil shale is considered commercial for use if its quality from 100 – 200 liter/ton.
Processes for producing shale oil generally fall into one of two groups: mining followed by surface retorting and in-situ retorting.
In this paper we try to study the strategic significance of oil shale development in Egypt from many aspects (economic profit – employment benefits – socioeconomic).
On the other hand there are critical issues with oil shale project, I try to suggest practical solutions that can help to reduce the severity of these critical issues and improve shale oil production cost.
Fluid Flow and Heat Transfer in the Top Hat Oil Recovery System
Authors: Mathews Kyle J. 
Published: October 2012

Abstract
In 2010, as part of the remediation efforts surrounding the Deepwater Horizon drilling rig incident, also known as the Macondo incident, multiple containment and collection systems were deployed in an attempt to capture as much oil as possible, as well as minimizing the amount of oil released into the Gulf of Mexico. The Top Hat was one of the recovery systems implemented to collect oil. In a Top Hat recovery system, oil is produced up the tubing and hot water is injected down an annulus (riser and drill pipe—two concentric pipes are required) to prevent the onset of hydrate formation. Recovery data of collected oil was readily accessible [10]. However, no data was available concerning the temperature and flowrate of the injected water. A coupled model of fluid flow and heat transfer was developed to estimate the hot water injection temperature and flow rate needed to keep the oil warm enough to avoid hydrate formation.
Existing well production data was extensively analyzed to determine the fluid flow and heat transfer of the oil produced through the tubing in the riser. The fluid flow analysis of the production data, coupled with the surrounding seawater pressure and temperature distribution, was used to model the flow and heat transfer of the injected water in the Top Hat recovery system. Two cases were studied in detail—the first assumed a riser made up of uninsulated steel, and the second assumed a steel riser with an outer insulation sheath. The goal was to maintain a water injection temperature high enough to agree with the production data, as well as to maintain a pressure versus temperature distribution outside the hydrate forming region. The flow rate, injection temperature and injection pressure of the hot water are the desired parameters. In order to approximate the operating conditions of the collection system, a coupled model of fluid flow and heat transfer was developed.
Laboratory study of Fracturing Fluid Migration due to Spontaneous Imbibition in Fractured Tight Formations
Authors: Dutta Riteja 
Published: October 2012

Abstract
During hydraulic fracturing operations in low permeability formations, spontaneous imbibition of fracturing fluid into the rock matrix may be responsible for having a significant impact on the retention of water-based fracturing fluids in the neighborhood of the induced fracture. This may consequently affect the post-frac productivity of the well. However, there is lack of direct quantitative and visual evidence of the extent of retention, evolution of the resulting imbibing fluid front, and how they relate to potential productivity hindrance. In this paper, laboratory experiments have been carefully designed to represent the vicinity of a hydraulic fracture. The evolution of fracturing fluid leak-off is monitored as a function of space and time using X-ray computed tomography (CT). The X-ray CT imaging technique allows us to map saturations at controlled time intervals to monitor the migration of fracturing fluid into the reservoir formation. It is generally expected for low permeability formations to show strong capillary forces due to their small characteristic pore radii, but this driving mechanism is in competition with the low permeability and spatial heterogeneities found in tight gas sands. The relevance of capillarity as a driver of fluid migration and retention in a tight gas sand sample is interpreted visually, quantified and compared with high permeability Berea sandstone in our experiments. It is seen that although these formations demonstrate strong capillarity, the effect can be suppressed by the low permeability of the formation and the heterogeneous nature of the sample. However, saturation values attained during imbibition experiments are comparable to those previously obtained for high permeability samples, which can have significant implications in terms of phase mobilities in the neighborhood of induced fractures. Results from this investigation are expected to provide fundamental insight regarding critical variables affecting the retention and migration of water-based fracturing fluids in the neighborhood of hydraulic fractures, and consequently on the post-frac productivity of the well.
Experimental Investigation of Formation Damage Reduction: Mud Cake Removal and Mud Filtration Treatment using Ultrasonic Wave Radiation
Authors: Vakilinia Bahador 
Published: October 2012

Abstract
Interactions of reservoir with drilling and completion fluids, mud cake and mud filtration, lead to formation permeability damages which result in reduction of production rate. For increasing the production rate and treating the formation damage, normally Matrix Acidizing and Hydraulic Fracturing treatment are used. Although hydraulic fracturing and matrix acidizing are effective operations, they have some critical issues. For instance, they need some specialized fluids that require the petroleum industry to spend over millions of dollars per year for this treatment.
Applications of ultrasonic waves have been widely developed in petroleum processes due to its significant positive effects. In this study, wellbore stimulation using ultrasonic wave radiation has been experimentally investigated. The experiment is categorized in two steps: At first, the effect of sonication on mud cake removal has been studied and next, the effect of ultrasonic wave on mud filtration treatment has been surveyed. Glass beads ranging from 70 to 100 mesh sizes were packed as the porous media and three kinds of water based mud in different weights were used as the samples for making the damage on glass bead pack to simulate the reservoir formation damage. Various ultrasonic wave intensities have been examined with different radiation times in order to find the optimum radiation time. The results show that at early time of ultrasonic exposing for mud filtration treatment, the permeability decreases by pervading the mud filtration in porous media while at the late time it increases, which shows that ultrasonic radiation removed mud cake form porous media and improved permeability. Finally, an optimum time obtained and it has been proved that ultrasonic radiation can increases the permeability of damaged zone.
New Guidelines Document Assists With PRMS Applications
Authors: Lee W. John , Purewal Satinder , Harrell D. Ronald 
Published: October 2012

Abstract
Continuing their leadership in developing consistent, clear, and reliable practices and guidance for international use in reserves reporting, SPE and sister organizations (AAPG, WPC, SPEE, and SEG) issued in November 2011 a new document entitled Guidelines for Application of the Petroleum Resources Management System (AG) to accompany and support PRMS. The AG updates the 2001 document Guidelines for the Evaluation of Petroleum Reserves and Resources, also published by SPE, which was issued prior to adoption of PRMS by three of these major professional organizations. This new document will assist reserves evaluators throughout the world in understanding PRMS and how it should be applied in financial, regulatory, and reporting activities. Two new chapters (on deterministic reserves estimation and on unconventional resources) have been added to the AG; eight others have been updated; and a comprehensive glossary entitled "Reference Terms" has been added.
The AG is available free to the public (not just to SPE members) on the SPE website. In addition, the SPE Oil and Gas Reserves Committee (OGRC) has begun to conduct Advanced Technology Workshops throughout the world. These workshops are intended to provide opportunities to discuss the AG and to present and discuss regional examples of PRMS applications.