bluuebunny/crossref_metadata_2025_split huggingface dataset:
Latest marine geophysical technologies for comprehensive study of natural hydrocarbon reservoirs and monitoring of production
Authors: Ampilov Yu. P. , Baturin D. G. 
Published: October 2012

Abstract
This paper presents three innovative technologies of PGS Company for marine geophysical studies: GeoStreamerGS™ is for marine seismic operations, EM for resistivity surveys in combination with seismic survey on the same vessel, and OptoSeis™ permanent reservoir monitoring during oil or gas production.
Seismics is the major marine geophysical technique. Unfortunately, in the conventional modification its effectiveness does not exactly comply with the requirements of our time. Improvements in both the marine seismic itself, its resolution capacity and informativity, and involvement of other geophysical techniques are on the agenda today.
PGS heavily invests in development of emerging technologies. The results are not late in coming. In this paper we present three innovative technologies, which our company started to offer at the geophysical services market in the last two or three years. The direct analogues that are comparable to them in terms of effectiveness and informativity are not yet present in the market.
Stochastic uncertainty analysis in compositional simulation for giant gas-condensate field reservoir performance prediction
Authors: Descubes E. , Madatov R. , Graf T. , Ignatyev A. , Mukminov I. , Redikultsev S. 
Published: October 2012

Abstract
Progress in multi-parallel computers opened up new possibilities in reservoir modelling providing opportunities in compositional simulation to study in detail highly complex physical process that are extremely computational demanding. This is particularly true for probabilistic methods such as the uncertainty quantification and analysis. Experimental design, ED, concept supersedes the conventional deterministic uncertainty analysis and offers new efficient and system approaches to identify and assess the impact of the key geology and engineering risks in strategic reservoir engineering decisions. Use of response surfaces, Monte Carlo stochastic modelling is an alternative to numerous full-scale reservoir simulation and is employed in petroleum industry since long ago [Amudo et al. 2008]. However, although ED has been introduced to reduce computation, it is computational expensive especially in compositional simulation with many degrees of freedom in the uncertainty parameters.
This paper shows implementation of ED and the use of multi-parameter sensitivity analysis based on multidimensional Response Surfaces Models (RSM). The method was validated when key risks associated with development of a unique gas-condensate field in Yamal peninsular, Russia, were assessed. This reservoir is characterized by poor permeabilities in the range around 1.0 mD, abnormally high reservoir pressure and temperature (600 atm, up to 115 °C), high potential condensate content (potential C5+ content 280-380 g/m3) and the risk of a heavily compartmentalized some blocks of the field through faulting.
The numerous identified uncertainties impacting the development of the gas-condensate reservoir are difficult to address in a traditional reservoir study using deterministic methods and only a probabilistic approach would guarantee to assess the production and recovery potential in all aspects and, moreover, allows informed decisions to be made on the data acquisition – or in general the appraisal strategy – and the development.
The Analytical Basis for Accetability Appraisal of the High Pressure Air Injection for West Siberian Oil Fields
Authors: Evseeva M. Y. , Ushakova A. S. , Volokitin Y. E. , Brusilovsky A. I. , Shaymardanov M. M. 
Published: October 2012

Abstract
Presently, the problem of enhancing the efficiency of the oil recovery becomes of the high priority. The procedure described in this paper is the analytical basis for accetability appraisal of the high pressure air injection (HPAI) on the light oil fields for enhancing the oil recovery.
The objective of this paper is the physical basis of the HPAI method, i.e. the air injection into a light oil bearing formation and the in-situ oil oxidation under high temperatureres with production of combustion gases – carbon mono- and dioxides, hydrocarboneous gases.
For evaluation of the technological parameters and the applicability of the HPAI method on the West-Salymskoe oil field of the Salym Petroleum Development Company the results of experimental studies of oil properties, the efficiency of the oil displacement by the injected and the combustion gases and the oxidation kinetics were analysed. The phase behavior of the oil and gases under high temperature conditions was modeled using the developed PVT model based on the equation of state. The experimental results of the linear oil displacement by gaseous agents on the core (lab) scale were simulated. The relative permeabilities have been obtained as saturation functions. The kinetics of oil oxidation reactions obtained by calorithmetic experimenta on the light oil on core was also simulated on the linear models. The developed linear models are the basis for the transition to the 3D modeling of the HPAI method.
Estimating Flow Profile and Composition in Horizontal Wells While Draining the Oil Rim with a Massive Gas Cap
Authors: Semikin Dmitriy , Rakitin Mikhail , Malaniya Georgiy , Kolomytsev Leonid 
Published: October 2012

Abstract
The project presents the results of the production logging campaign performed in horizontal wells of the Korchagina oil gas-condensate field. FSI-MaxTrac tool was run for inflow profiling purposes. Obtained results allowed to: Assess the multiphase fluid dynamics along the wellboreIdentify the oil, gas and water inflow zonesAnalyze the presence of cross-flow behind casing and assess the swelling packers integrityPerform the completion effectiveness and horizontal drain productivity analysis.
This was the first time in this field when production logging was performed. Comprehensive analysis of OH logs and FSI data helped to better understand the reservoir nature and determine the source of gas.
Production data obtained with FSI technology allowed the client to optimize well flowing regimes; to determine the main directions for future downhole operations, workover procedures and bottomhole zone treatment in order to reduce the inflow of free gas.
Chemical and Analytical Work in Support of West Salym Field Enhanced Oil Recovery Project (ASP)
Authors: Volokitin Y. , Sakhibgareev R. , Shaymardanov M. , Nurieva O. 
Published: October 2012

Abstract
Salym Petroleum Development (SPD) oil company is a joint venture between Shell and JSC Gazprom Neft. SPD currently holds three license areas in the south of Khanty-Mansiysk Autonomous Okrug. So far the company has concentrated its efforts on further exploration and development of ‘traditional deposits’: from early production at the Upper Salym filed to commissioning state-of-the-art central oil production facility at the large West Salym field and the satellite Vadelyp field.
At the early stage of field development the company started to research ‘non-traditional’ hydrocarbon resources. One group of these resources is immobile oil remaining in flooded reservoir after the waterflood target oil recovery factor had been achieved; another group of resources is Bazhenov Formation oil. These resources are not currently developed actively because of the combination of technological risks and current macroeconomic conditions in Russia. However, the study of analogous fields shows that the industry practice has successful solutions for both groups of the problems and non-traditional resources with the characteristics presented at the Salym group of oil fields are in fact successfully developed elsewhere (after elimination of technical risks through analytic work and field tests).
The work on the enhanced oil recovery project began with the high-level assessment of various technologies in 2007. In 2010 a more detailed study of potential technologies was carried out including high pressure air injection and low salinity waterflooding.
As a result of screening an EOR method of flooding with the solution of chemicals – Alkaline-Surfactant-Polymer – was chosen. Initial stages of the project comprised lab tests, core experiments and field tests. From these tests, an estimate of potential oil recovery factor increase of 15 % – 20% (of STOIIP) was confirmed. In 2011 the ASP project reached maturity when the next stage would be implementation of the pilot project activities. Currently the work is on the way to design the flooding pattern and surface processing facilities with expected ASP oil production in 2014-2015.
In the beginning the article gives a short overview of the history and status of the project. After that it describes the stages of analytical work in Russian laboratories to find, optimize and test various types of Russian surfactants. This work was carried out under the guidance of the operator (Salym Petroleum) with the engagement of specialists from Shell and Gazprom Neft research centres. As a result lab samples of anionic surfactant showed satisfactory results during core flood experiments.
Finally it is worth mentioning that one of the results of the work was the establishment of methodological and experimental framework on the basis of Russian contractors and laboratories which made it possible to asses, within the short period of time, a large number of chemicals used on the Russian market for EOR activities.
Use of Fiberglass Equipment in Petroleum Production
Authors: Gavrilyuk Y. A. , Perevoshchikov D. O. , Shlyapnikov Y. V. , Agafonov A. A. 
Published: October 2012

Summary
One of the main tasks set in the course of oil and gas field development is the search of efficient technologies to increase the Mean-Time Between Failures (MTBF) period of downhole equipment. In this paper you will read about use of fiberglass equipment in producing wells, as well as about the criteria for well selection for this technology and review of its performance. Physical differences between fiberglass and metal allow increasing equipment service life significantly. The results of introduction of such equipment show high economic effect.
Application of sector modeling technology for giant reservoir simulations
Authors: Dzyuba V. I. , Litvinenko Yu. V. , Bogachev K. Yu. , Migrasimov A. R. , Semenko A. E. , Khachaturova E. A. , Eydinov D. A. 
Published: October 2012

Abstract
Currently, to build models for dynamic simulations of large oil and gas fields, engineers have to upscale the original geological grid not to exceed limits set but by computer memory size, CPU performance, and by the capabilities of standard commercial software packages. As a result, the upscaled model often has a rather low level of detalization. Since upscaling inevitably generates additional simulation errors, the resulting simulation model can solve only a limited number of practical tasks. The coarsened models are typically used for strategic tasks – to find an appropriate field development system, understand fluid and gas migration processes, and plan future production for this field.
Such upscaled models are rarely used for planning of risky, high cost and practically important tactical and operational tasks of field development management and production monitoring. It's ironic that oil and gas companies invest large sums of money on detalization of the reservoir geological description, and then have to drop this information in the process of hydrodynamic simulations. Engineers often call this paradox a "simulation scale problem". Since computer hardware performance increases exponentially in time, it is the technological level of software that becomes the main limitation factor.
If one could build a coherent "hardware+software" solution to resolve flow dynamics in porous media for geological grids with tens and hundreds of millions of blocks without upscaling, the problem could be solved.
In this article, the technology for constructing and effective handling of giant field models by application of sector modeling and advanced parallel algorithms is discussed. The important role of modern computer hardware architecture - especially processors and RAM designs is emphasized.
The authors discuss practical aspects concerning model dimensions, simulation model calculation speed for the whole field model or for any of its parts, choice of optimal model cut into sections, and boundary condition setting methods.
Technology application results are demonstrated for one of the world's biggest oil fields, with a geological model size of about 43 million grid blocks. The authors show that when the whole field is divided into a certain number of sector models, the sum of their calculation times may be substantially smaller than the full model calculation time. At the same time, if boundary conditions are included in simulations of subdomains, the spread in values of calculated production rates can be as small as 1%. The approach described in this paper appears to be efficient for history matching of large hydrodynamic models. It helps to reduce the time to completion for the project, and avoid the unnecessary modeling precision degradation caused by grid upscaling.
Capabilities of High-Resolution Seismic Surveys in Water Areas for Geological Engineering Applications
Authors: Shmatkov A. A. , Tokarev M. Yu. , Buryak S. V. 
Published: October 2012

Abstract
Today there are a number of challenges related to construction and operation of engineering structures in water areas, especially in shallow regions. This primarily includes installation of platforms for exploratory and production drilling in sea shelf areas, underwater piping work, and construction of engineering structures. Shallow water areas are the most dynamic zones affected by quick sedimentation and active transportation of upper sediments, which can be a hazard to the already constructed structures (for example, in the form of such phenomena as landslides and sand waves). In addition, high-resolution seismic surveys in water areas allow addressing various tasks related to environmental monitoring and comprehensive water area status tracking.
There are four groups of geological engineering tasks addressed by high-resolution seismic surveys: 1) obtaining information about the geological section and geometry of geological structures, 2) obtaining information about area distribution of sediment properties, 3) determining physical properties of sediments, and 4) solving geodynamic tasks.
Currently the vast majority of seismic engineering surveys in water areas are carried out using either single-channel (1D) or multi-channel (2D) profiling. At the same time, three-dimensional (3D) exploration systems that offer a number of advantages have been used in petroleum geophysics for quite a while. Nevertheless, such systems are utilized for geological engineering applications only in isolated cases. This is mostly due to the need to solve certain hardware-related and methodological problems during field work and subsequent data processing.
Seismic data from the near-surface sections are complicated by typical seismic and geological conditions: small acoustic contrast between sediments under bottom as compared to the water and bottom boundary, high seismic energy absorption in bottom sediments, and considerable alteration of sediment properties with depth. Surveys in shallow water areas bring problems associated with multiple waves in target seismic trace times, re-reflection of useful signals from the bottom and the water-air surface etc.
Positive Comparison of LWD Data Acquired With and Without Chemical Radioactive Sources in the Vankor field, Russia, Paves the Way for Radioisotope-Free Formation Evaluation
Authors: Majidi A. , Plyuta A. , Alexandrova A. , Bourg L. , Reichel N. J. , Malyasov V. , Zhadan G. 
Published: October 2012

Abstract
Safety issues, tightening of environmental regulations, and efficiency are among many reasons the petroleum industry has long searched for a way to acquire standard formation evaluation measurements without the use of chemical radioactive sources.
Pulsed neutron generator (PNG) technology provides electronically controlled pulses of neutrons. This radioisotope-free source of high-energy neutrons has been in use for decades in wireline-conveyed logging tools for various commonly used measurements such as neutron porosity, spectroscopy, and thermal neutron capture cross section (sigma). For several years, a ruggedized PNG technology that performs under the harsh shock and vibration conditions of an LWD tool operation has allowed these measurements to be made while drilling. Recent developments have extended the suite of measurements to include a radioisotope-free bulk density measurement. In conjunction with the other PNG-related formation measurements, this makes it possible to perform comprehensive formation evaluation without chemical radioactive sources.
The sourceless neutron-gamma density (SNGD) measurement is initiated by neutrons, in contrast to the standard gamma-gamma-density (GGD) measurement. The high-energy neutrons from the PNG experience inelastic collisions with the atomic nuclei of atoms surrounding the tool. The gamma rays emitted as the nuclei return to the ground state create a distributed gamma ray source in the formation. These gamma rays then experience Compton scattering in the same way as gamma rays emitted from the chemical radioactive source used for the standard GGD measurement. The count rate of detected gamma rays at a gamma-ray detector at a distance from the PNG is proportional to the electron density of formation, which is then transformed to bulk density in the standard manner.
This study compares the new sourceless neutron-gamma density measurement with the traditional source-based bulk density measurement, both of which were acquired in the same well in the Vankor field, Siberia, Russia. Conditions encountered include oil, gas, shale, bad hole, and coal-bearing intervals. A comparison of the final petrophysical analysis derived from the traditional source-based density and the new sourceless SNGD measurement is also made. Our evaluation indicates a positive comparison between density recorded using a chemical radioactive source and neutron-gamma density recorded using a PNG without a chemical radioactive source.
Elevated Rates of Diabetes in Pacific Islanders and Asian Subgroups
Authors: Karter Andrew J. , Schillinger Dean , Adams Alyce S. , Moffet Howard H. , Liu Jennifer , Adler Nancy E. , Kanaya Alka M. 
Published: October 2012

OBJECTIVE
We estimated the prevalence and incidence of diabetes among specific subgroups of Asians and Pacific Islanders (APIs) in a multiethnic U.S. population with uniform access to care.

RESEARCH DESIGN AND METHODS
This prospective cohort analysis included 2,123,548 adult members of Kaiser Permanente Northern California, including 1,704,363 with known race/ethnicity (white, 56.9%; Latino, 14.9%; African American, 8.0%; Filipino, 4.9%; Chinese, 4.0%; multiracial, 2.8%; Japanese, 0.9%; Native American, 0.6%; Pacific Islander, 0.5%; South Asian, 0.4%; and Southeast Asian, Korean, and Vietnamese, 0.1% each). We calculated age-standardized (to the 2010 U.S. population) and sex-adjusted diabetes prevalence at baseline and incidence (during the 2010 calendar year). Poisson models were used to estimate relative risks.

RESULTS
There were 210,632 subjects with prevalent diabetes as of 1 January 2010 and 15,357 incident cases of diabetes identified during 2010. The crude diabetes prevalence was 9.9% and the incidence was 8.0 cases per 1,000 person-years and, after standardizing by age and sex to the 2010 U.S. Census, 8.9% and 7.7 cases per 1,000 person-years. There was considerable variation among the seven largest API subgroups. Pacific Islanders, South Asians, and Filipinos had the highest prevalence (18.3, 15.9, and 16.1%, respectively) and the highest incidence (19.9, 17.2, and 14.7 cases per 1,000 person-years, respectively) of diabetes among all racial/ethnic groups, including minorities traditionally considered high risk (e.g., African Americans, Latinos, and Native Americans).

CONCLUSIONS
High rates of diabetes among Pacific Islanders, South Asians, and Filipinos are obscured by much lower rates among the large population of Chinese and several smaller Asian subgroups.
Diabetes Genetic Predisposition Score and Cardiovascular Complications Among Patients With Type 2 Diabetes
Authors: Qi Qibin , Meigs James B. , Rexrode Kathryn M. , Hu Frank B. , Qi Lu 
Published: October 2012

OBJECTIVE
To examine the association between genetic predisposition to type 2 diabetes (T2D) and risk of cardiovascular disease (CVD) among patients with T2D.

RESEARCH DESIGN AND METHODS
The current study included 1,012 men and 1,310 women with T2D from the Health Professionals Follow-up Study and Nurses’ Health Study, including 677 patients with CVD and 1,645 non-CVD control subjects. A genetic predisposition score (GPS) was calculated on the basis of 36 established independent diabetes-predisposing variants.

RESULTS
Each additional diabetes-risk allele in the GPS was associated with a 3% increased risk of CVD (odds ratio [OR] 1.03 [95% CI 1.00–1.06]). The OR was 1.47 (1.11–1.95) for CVD risk by comparing extreme quartiles of the GPS (P for trend = 0.01). We also found that the GPS was positively associated with hemoglobin A1c levels (P = 0.009).

CONCLUSIONS
Genetic predisposition to T2D is associated with an increased risk of cardiovascular complications in patients with T2D.
Insulin Resistance, Brain Atrophy, and Cognitive Performance in Late Middle–Aged Adults
Authors: Willette Auriel A. , Xu Guofan , Johnson Sterling C. , Birdsill Alex C. , Jonaitis Erin M. , Sager Mark A. , Hermann Bruce P. , La Rue Asenath , Asthana Sanjay , Bendlin Barbara B. 
Published: October 2012

OBJECTIVEInsulin resistance dysregulates glucose uptake and other functions in brain areas affected by Alzheimer disease. Insulin resistance may play a role in Alzheimer disease etiopathogenesis. This longitudinal study examined whether insulin resistance among late middle–aged, cognitively healthy individuals was associated with 1) less gray matter in Alzheimer disease–sensitive brain regions and 2) worse cognitive performance.RESEARCH DESIGN AND METHODSHomeostasis model assessment of insulin resistance, gray matter volume, and the Rey Auditory Verbal Learning Test (RAVLT) were acquired in 372 participants at baseline and a consecutive subset of 121 individuals ~4 years later. Voxel-based morphometry and tensor-based morphometry were used, respectively, to test the association of insulin resistance with baseline brain volume and progressive gray matter atrophy.RESULTSHigher insulin resistance predicted less gray matter at baseline and 4 years later in medial temporal lobe, prefrontal cortices, precuneus, and other parietal gyri. A region-of-interest analysis, independent of the voxel-wise analyses, confirmed that higher insulin resistance was related to medial temporal lobe atrophy. Atrophy itself corresponded to cognitive deficits in the RAVLT. Temporal lobe atrophy that was predicted by higher insulin resistance significantly mediated worse RAVLT encoding performance.CONCLUSIONSThese results suggest that insulin resistance in an asymptomatic, late middle–aged cohort is associated with progressive atrophy in regions affected by early Alzheimer disease. Insulin resistance may also affect the ability to encode episodic information by negatively influencing gray matter volume in medial temporal lobe.