bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Method for Security Estimation of the Spn-Based Block Cipher Against Related-Key Attacks
Authors: Kaidalov Dmytro , Oliynykov Roman , Kazymyrov Oleksandr 
Published: March 2015

Abstract
Symmetric block ciphers are the most widely used cryptographic primitives. In addition to providing privacy, block ciphers are used as basic components in the construction of hash functions, message authentication codes, pseudorandom number generators, as a part of various cryptographic protocols, etc. Nowadays the most popular block cipher is AES (Advanced Encryption Standard). It is used as a standard of symmetric encryption in many countries. Several years ago it was found a theoretical attack exploiting the AES key expansion algorithm that allows reducing significantly the complexity comparing to the brute force attack. This article presents an advanced method of finding the number of active substitutions that helps to estimate the security of encryption algorithms against related-key attacks. The method was applied to a prospective block cipher, which is a candidate for the Ukrainian standard
Non-Interactive Secure Multiparty Key Establishment
Authors: Eskeland Sigurd 
Published: March 2015

Abstract
Cryptographic schemes that provide establishment of secret keys among a number of participants are generally known as conference key establishment schemes and key broadcasting schemes. In any case, such protocols provide secure establishment of group-oriented cryptographic keys, but with the costs of multiple transmissions of key establishment messages and in some cases multiple secret user keys. In this paper, we present a simple and straightforward efficient non-interactive group-oriented key establishment scheme that provides off-line computation of secret group keys, without computations and transmissions of key establishment messages
A Micro-Controller Implementation of a Fialka M-125 Based Stream Cipher
Authors: Antal Eugen , Hromada Viliam 
Published: March 2015

Abstract
In 2013, a new stream cipher was proposed in Antal, E.-Hromada, V.: A new stream cipher based on Fialka M-125, Tatra Mt. Math. Publ. 57 (2013), 101-118. Its design was inspired and motivated by a Soviet encryption machine Fialka M-125. The authors proposed three versions of the cipher with different inner state bit-lengths. They provided the design, software implementation on a personal computer and a preliminary statistical and performance analysis of the cipher.
In this article we extend their work by implementing all three versions of the cipher on two different micro-controllers: EBV SoCrates evaluation board [Official SoCrates webpage (EBV SoCrates evaluation board), www.rockerboards.org] and STM32F407VG [Official STM webpage (STM32F407VG), www.st.com]. We evaluate the performance of all implementations on both platforms. We also investigate the possibilities of performing a simple power analysis of the implementation of the 8-bit version of the cipher implemented on STM32F407VG micro-controller. It stems from our experiments that we are able to determine a part of the secret key of the cipher by observing the power trace (power consumption) of the encryption/decryption process
Using Poly-Dragon Cryptosystem in a Pseudorandom Number Generator Mstg
Authors: Hromada Viliam , Vojvoda Milan 
Published: March 2015

Abstract
This paper deals with a new pseudorandom number generator MSTg proposed in 2010. Its construction is based on random covers for finite groups. We have used a public-key cryptosystem Poly-Dragon to generate these random covers and have studied the statistical properties of the resulting pseudorandom number generator by testing its output using the NIST Statistical Test Suite
Three-Polar Space Over the Semi-Field of Double Numbers
Authors: Gregor Tomáš 
Published: March 2015

Abstract
Multi-polar space is a generalization of the notion of vector space. In this paper, we deal with a three-polar vector space over a semi-field of double (hyperbolic complex) numbers. We introduce and study operations of addition and multiplication such that they form a commutative ring with unit on the three-polar space
A Risk Analysis Approach: From Subsurface to Surface
Authors: Contento F. Michela , Godi Antonella , Nicotra Giovanna , Pizzo Anna 
Published: March 2015

Abstract
The quantitative assessment of the risk associated with the economic exploitation of a hydrocarbon field is mandatory to support, in an efficient and comprehensive way, the decision process guiding the development management system of an oil company.
The Full Range Risk Analysis (FRRA) approach developed in Eni E&P Division allows the identification of uncertainties arising from each step of an integrated reservoir study, and the evaluation of their impact on recoverable reserves and on the economic value of a project. This methodology has already been successfully applied in the concept selection and concept definition phases of field development projects. Recently it has been further improved to be employed both in the evaluation stage, of a new discovery, and in the revamping of mature fields with production history.

Introduction
The Full Range Risk Analysis is aimed at investigating the whole range of possible reservoir development combinations. Its main objectives are:the support of the sanction of an economic discovery, considering an acceptable and accepted risk; the estimation of the value of information (VOI) of new data acquirement and the comparison between different appraisal strategies; the choice of the best development plan taking into account the main impacting reservoir uncertainties (mainly during concept selection phase);the quantification of downside/upside potential of the reservoir and of residual risk associated to field with production history.
The presented workflow is a valuable tool in assessing the risk associated to a particular development scenario taking into account the entire surface and sub-surface uncertainties and therefore a methodology to support decisions in development projects.
The FRRA methodology is fully based on Montecarlo approach and massive simulations of 3D reservoir models.

Full Range Risk Analysis Workflow
The current paper describes in detail the standard FRRA workflow along with the latest developments of the methodology, starting from the uncertainty definition phase up to the frequency distribution of the target variable, i.e. ultimate recovery, plateau length, NPV.
Chayvo Field, Sakhalin Island, Russia: Identification of a Significant Oil Leg From 3D Seismic and Execution of a World-Class Extended-Reach-Drilling Program
Authors: Apotria Ted , Poffenberger Mike , Powell Rick , Venner Bridget 
Published: March 2015

Abstract
In 1997, the ExxonMobil operated Sakhalin I Consortium acquired a 3-D seismic survey over Chayvo Field, located off the northeast coast of Sakhalin Island, Russia. At the time of the acquisition, Chayvo was thought to contain primarily gas given the results of five pre-existing crestal wells. Interpretation of 3-D seismic revealed seismic amplitude anomalies that conformed to structural spill, were down dip of gas accumulations seen in crestal wells, and indicated the potential for very large, previously unrecognized oil rims. Based on the 3-D seismic interpretation, an appraisal well was drilled in 2000 and penetrated several large oil legs. This appraisal well and associated sequence stratigraphic studies resulted in a significant oil project in a field previously thought to be mostly gas.
When the oil rims were confirmed, the challenge was how to develop the Chayvo field lying 8 to 10 kilometers offshore. Development drilling at the field began in 2003, with the first phase comprising a series of extended reach wells drilled from an onshore location reaching offshore to the western limb of the Chayvo anticline. These wells are technically complex and very expensive, but attractive considering offshore platform costs in a remote, environmentally sensitive location characterized by seismic activity and icebergs.
In 2002, a multi-disciplinary team was assembled to address the challenges associated with designing and executing extended reach wells in stacked deltaic reservoirs comprised of prograding clinoforms. The primary geological concern was the accuracy with which the horizontal well bores could be placed within the oil column, as reservoir simulation indicated the need to be within 10 m of a specified vertical depth to delay water/gas breakthrough. Ongoing drilling has proven to be successful with actual reservoir depths within a few meters of prognosed depths at well reaches of 9–11 kilometers, underscoring the value in the integrating seismic interpretation and extended-reach well planning in a 3-D visualization environment.
Shot-Domain Data Reconstruction and Its Application to Suppression of 3D Surface-Related Multiples
Authors: Baumstein Anatoly , Hadidi Mohamed T. , Hinkley David L. 
Published: March 2015

Abstract
We present a DMO-based technique for reconstruction of densely and regularly sampled shot records from conventional marine data. The reconstruction process allows us to overcome aliasing that typically affects marine data in the cross-line direction and enables us to apply high-end processing techniques, such as 3D SRME, to conventional marine data without imposing additional acquisition requirements. A low-cost version of our reconstruction method, which is particularly suitable for use as a part of a multiple-suppression processing flow, is introduced and its advantages and limitations discussed.
An example of performing data reconstruction for a conventional marine field dataset, followed by application of 3D SRME, is presented. This field data example is used to illustrate how the choice of data reconstruction method impacts the quality of multiple suppression.

Introduction
Many advanced seismic processing techniques, such as 3D surface-related multiple suppression (SRME) and 3D shot-record wave-equation migration (SRWEM), require regularly and densely sampled input data. In particular, 3D SRME requires dense sampling of both shots and receivers, while SRWEM efficiency is a function of the number of shot records in the data set. Current marine acquisition geometries do not provide the data suitable for either one of the above processing algorithms. In the case of 3D SRME, shot (and to a lesser degree, streamer) crossline spacing is too coarse for the algorithm to predict 3D multiples correctly. In the case of SRWEM, run times could be greatly reduced if multiple shot records could be combined in one "super-shot", thus reducing the total number of shot records.
We discuss a DMO-based method for transforming conventional marine data into an equivalent set of data on a finely sampled regular and dense grid including all source-to-receiver azimuths. The new data are equivalent in the sense that a migration code would accurately map a reflection event associated with a single subsurface interface in the new data to the same subsurface locations as the corresponding data in the input data set.
Cement Designs for High-Rate Acid Gas Injection Wells
Authors: Benge Glen 
Published: March 2015

Abstract
High rate acid gas injection wells pose a significant challenge for the design of cementing systems. CO2 conversion of Portland cement to calcium carbonate is a significant problem. This paper describes the design and use of two cement systems for high rate acid gas injection wells. The paper compares risks and benefits of a high alumina cement slurry to those of a specialty Portland based system. Case history reviews of the application of both systems on liner cement jobs are detailed. The systems were used on wells designed for a 65% H2S, 35% CO2 injection stream at a rate of 65 million scf/day.
High alumina cement is used in many applications to address the problem of CO2 conversion of Portland cement. The cement is resistant to CO2, but high temperature fluid loss control was not available, preventing its application on long liners. Lack of an effective high temperature fluid loss additive required the development of an alternate Portland based system. Later development of an effective high temperature fluid loss additive ultimately allowed use of the high alumina cement system.
A CO2 resistant Portland system was developed by limiting the cement concentration and reducing total system permeability by use of specialty sized particles. This paper discusses the development and testing of a Portland based cement system and the associated risks with the use of this specialty system. Quality control steps to address the complex blending process and steps taken to improve system reliability are presented.

Background
Two acid gas injection wells (AGI 3–14 and 2–18) were drilled in the western United States as part of an overall gas plant de-bottlenecking. Plant throughput capacity was being increased by converting the plant to acid gas disposal by injection. The anticipated waste gas stream was 65% H2S and 35% CO2, with the design volume for the wells being based on the capacity of the plant plus adequate backup.
Front-End Engineering Studies for Carbonate Stimulation Optimization
Authors: Lizak Kenneth F. , Fulton Dwight David , Van Domelen Mary Susan 
Published: March 2015

Abstract
This paper describes an integrated approach to stimulation treatment design for carbonate reservoirs. Using this process helps ensure that appropriate candidates are stimulated with the optimum treatment. Historically, many of the steps described have been applied in sandstone reservoir stimulation, but industry has lagged in the application of these technologies to carbonate reservoirs.
The discussion begins with preliminary candidate selection based on estimated productivity gains from various stimulation options. Well history and formation data is reviewed to evaluate near-wellbore damage and identify possible fluid-formation compatibility issues that will affect treatment choices. Productivity analyses indicate formation flow capacity, which can then be used to rank potential treatment options such as comparing the expected results from a matrix treatment to an acid fracturing treatment.
Core testing demonstrates that specific carbonate "rocks" will have uniquely different reaction characteristics when treated with various acid systems. This is a valid design consideration, whether the proposed treatment is matrix or fracture acidizing. This paper reviews the specialty core testing programs which are used to optimize acid treatments and present illustrative data.
All the previously-gleaned data provide inputs to selection of the most appropriate approach to stimulation and set the stage for the final design. In matrix treatments, the biggest challenge is often fluid placement and diversion. Fluid placement modeling, which also predicts skin reduction and stimulation results, is critical to evaluate the potential effectiveness of a possible treatment. When fracture acidizing is required, the same data can be used to refine the treatment design and provide more realistic simulation of the expected well response.

Part 1– Candidate/Treatment Selection
For any field with more than one well, candidate selection for stimulation is a part of the field development decision processWise use of available budget funds for well treatment requires selecting wells with the greatest potential to improve both short-term productivity and long-term reservoir management and recovery.
Development and Application of Combining a Real-Time Hydraulics Model and Automated Choke To Maintain a Relatively Constant Bottomhole Pressure While Drilling
Authors: Reitsma Don 
Published: March 2015

Abstract
The increasing demand to drill wells having narrow pore pressure and fracture gradient margins and the increasing concern that irreparable damage from extreme overbalanced drilling negatively impacts productivity and recoverable reserves, requires a new method of controlling bottomhole pressure while drilling, beyond the current capability of conventional drilling techniques. Where the dynamic pressure or equivalent circulating density can be supported, a solution has been developed to drill with a relatively constant bottomhole pressure equal to the dynamic conditions rather than static conditions, thereby reducing the maximum bottomhole pressure. The method also establishes a continuous method of well control that should reduce the risk of taking a kick.
Shell International Exploration & Production Research & Development has developed a robust solution using a flow model running in real time coupled to an automated choke control system to continuously maintain the bottomhole pressure at a relatively constant value. Several applications of this method have been implemented or proposed, including fractured reservoirs where it is difficult to control losses, HPHT wells subject to ballooning and wells with narrow pore pressure and fracture gradients margins subject to kicks and losses. Underbalanced drilling is another application where increased control of bottomhole pressure to limit inflow and decrease the potential for borehole instability can be realized. The development, testing, application and results of this automated system will be presented.

Introduction
With the advent of circulating drilling mud, bottomhole pressure has been subjected to two different pressure conditions; a static pressure state when the pumps are off and a higher dynamic pressure state caused by the addition of frictional pressure when the drilling pumps are on and drilling fluid is being circulated in the well.
The recently developed Dynamic Annular Pressure Control (DAPC) system now changes that by making it possible to drill with a relatively constant bottomhole pressure equivalent to the dynamic pressure at a given depth in the well by holding the necessary backpressure on the annulus as shown in figure 1. In essence, the pressure curve is reversed by having the increase in pressure at surface using backpressure control rather than at the bottom of the hole.
Application of an Efficient Multiscale Finite Volume Simulator to Practical Reservoir Models
Authors: Wolfsteiner Christian , Gadelle Frederic , Lee Seong Hee , Tchelepi Hamdi A. 
Published: March 2015

Abstract
A reservoir simulator was developed for accurate modeling of multiphase flow and transport in large scale heterogeneous reservoirs. The simulator is based on a multiscale finite volume (MSFV) method. In MSFV, the pressure equation is solved on a coarse grid, where coarse scale transmissibilities are computed via dual basis functions (i.e., localized interpolators). The fine scale pressure and velocity field is computed as a superposition of basis functions using the coarse pressure information. These reconstructed properties are very accurate when compared to results from a conventional fine grid simulation. In the second step, a localized and adaptive transport scheme is employed to update the saturation distribution. Both IMPES and sequentially implicit formulations are described. To resolve the fine scale flow field around wells, a special well basis function is devised. The multiscale algorithm is also extended to include gravity, capillary pressure and compressibility.
The multiscale simulator achieves the robustness and computational efficiency through scalable (efficient for large problems) adaptive computation of flow and transport. We establish the accuracy of MSFV relative to conventional methods with several test examples. The multiscale simulator is subsequently applied to large field scale reservoir models to demonstrate its practical use and efficiency, compared with the conventional finite difference simulator.

Introduction
The trend in modern reservoir characterization is to build geocellular models with an ever increasing level of detail and number of cells. In addition, specific applications (e.g., history matching, Monte Carlo Simulation) may require running large numbers of these detailed simulations. The multiscale framework is a particularly promising method for solving these highly detailed problems directly without resorting to traditional upscaling techniques. In the multiscale approach, the problem is decomposed into a coarse scale operator and local fine scale reconstruction operators. The local problems are small, independent from each other (via appropriate closure assumptions) and typically weak functions of time (for large parts of the reservoir). The resulting method is efficient and scalable.
Fracture Characterization Using Multicomponent Surface Seismic Data
Authors: Kristiansen Pal , Gaiser James E. , Probert Tony 
Published: March 2015

Abstract
In reservoirs producing primarily from secondary porosity like fractures, the flow is largely controlled by the fracture system and characterizing these fractures is key to effectively managing these reservoirs. Aligned fractures will affect the average stiffness of the rocks even when fractures are smaller than seismic wavelengths. Small scale aligned fractures lead to variations in the seismic velocities that are directionally dependent, an effect known as anisotropy. Measuring this seismic anisotropy provides information on the fracture systems properties, such as fracture density and orientation. Such information can be used to identify sweet spots and in general be used for better reservoir management, like guiding directional and infill drilling.
Since fractures are often nearly vertical to bedding the dominant seismic effect is azimuthal anisotropy, which is observed both on P- and S-waves. AVOA (azimuthal AVO-effect) and variations in the NMO velocities have been used to estimate P-wave anisotropy. S-waves will split into one fast and one slow mode and this splitting is very sensitive to small changes in the subsurface. The fast shear-wave direction aligns with the fracture strike and the amount of time splitting between the fast and slow mode depends on fracture density.
Apart from the difference in sensitivity between the P- and S-wave measurements there are attributes of the fracture system that can only be observed on the S-wave data. The asymmetry in the converted waves (PS-data) can say something about the tilt of the fractures. Multicomponent seismic provides access to both the P- and S-wave azimuthal information. Combining these two can enable the extraction of information about the fluid in the fractures. In this paper we will give an overview of the theory and several cases where multi-component data has been used to characterize fractures and fracture attributes.

Introduction
Whilst many fractured reservoirs have been profitably produced, few of them have been depleted in an efficient manner. Nelson points out the importance of classifying fractured reservoirs based on the amount of heterogeneity and anisotropy observed in the porosity and permeability. Quantifying this anisotropy with surface seismic data should provide an optimal strategy for fractured reservoir management by integrating the geophysical data from all scales with the engineering data.