bluuebunny/crossref_metadata_2025_split huggingface dataset:
Mitigating Infectious Diseases in Company Workplaces through Business Partnerships
Authors: Diara Malick , Johnson Clarion , Dockins Richard , Buford Deena , Edet Affiong Ben , Ngunjiri Susan , Brown Amanda 
Published: June 2014

Abstract:
This communication describes how the company established a corporate steering committee and programs built on operations systems to effectively protect its large globally mobile international workforces from vector borne diseases, outbreaks, and other communicable diseases.

Application:
Infectious diseases have potential for serious health consequences, operation disruption, loss of productivity, and impact on a company’s license to operate and reputation. Mitigation of such threats in the oil and gas sector requires corporate commitment, intricate partnership between Operations, Security, Safety, Health and Environmental (SSHE) organizations with consistent use of effective mitigation measures built on company processes.

Observations:
Global implementation of the Company malaria control program decreased reported cases from 230 in 2002 to less than 15 since 2005. Chemoprophylaxis compliance testing developed with corporate funds was instrumental in such success. Following the deployment of Infectious Disease Outbreak Management in 2010, average number of affected workers during outbreaks decreased from 23 in 2010 to 12, in 2012. The Steering Committee for Infectious Disease Control assembles Company executives, SSHE managers and Medical and Occupational Health (MOH) department representatives. The committee and attached unit periodically review program needs and performances while providing guidance and resources for program improvements. MOH and SSHE organizations work in partnership with Operations and providers for tool development and updates, program implementation, effectiveness reviews and reporting. The Company operations integrity management systems include also effectiveness reviews of infectious disease control program in operations sites.

Significance:
The visible engagement of Company Executives in workplace infectious disease control programs is critical. Embedding disease control program procedures in company mechanisms, and building internal partnerships between Operations, providers, MOH and SSHE organizations are essential for the effective protection of oil and gas workers exposed to emerging and re-emerging infectious diseases around the globe. It also prevents spread of outbreaks from the operation sites to surrounding communities.
An IPIECA Oil and Gas Framework for Water Stewardship
Authors: Wyness A. J. , Fennessey K. D. , Buttini P.. , Thorne K.. , Romer R. F. , Ruck P. S. 
Published: June 2014

Abstract
Water is an essential element in the upstream and downstream operations of oil and gas companies. Yet water, particularly fresh water, is already a scarce resource in many parts of world and further constraints are predicted. Continuing the development and implementation of water stewardship practices across the oil and gas lifecycle is therefore considered an important component in a company’s sustainability strategy.
IPIECA, the global oil and gas industry association for environmental and social issues, has recently made significant strides in this arena to raise stakeholders and the industry’s awareness of water management issues. IPIECA has developed a water management framework which adopts the principles of water stewardship. Uptake and adoption of the framework should lead to recognition by internal and external stakeholders that the oil and gas inudsty is proactively and collectively managing the issues related to sustainable water use and acting as stewards of this valuable resource.
The IPIECA water management framework outlines a series of industry guidelines, tools and initiatives providing a comprehensive approach through the full lifecycle of oil and gas development and production. The framework builds upon the systematic approach which is adopted by IPIECA to manage water risk – ‘global-&gt;local-&gt;guidance’ (SPE 157544). This approach includes the use of the IPIECA Global Water Tool for Oil and Gas and the Global Environmental Management Initiative (GEMI) Local Water Tool for Oil and Gas to help business better understand both the global and local level water risk from which specific guidance is then developed.
The World Water Forum Target 2.3.6 which was identified at the 6th World Water Forum in Marseilles in 2012, to "drive responsible water management in oil & gas exploration and production" is aligned with the IPIECA Water Management Framework. Work on this target is being led by IPIECA with support from the International Association of Oil and Gas Producers (OGP). The development of the IPIECA framework should support and improve the sector’s water management practices and approaches.
Results From Anular Injection in Heavy and Extra Heavy Oil Wells Producing With Rod Pumping in the Samaria Field: A Field Test
Authors: Jiménez H. M. , Naranjo J. E. , Herrera R. Pérez 
Published: June 2014

Abstract
Tertiary reservoirs of southern Mexico are mature reservoirs, producing mostly heavy oil since the sixties. Nowadays a massification program of steam injection it is being developed to produce extra heavy oil. Due to the low pressure and the oil properties, from 6° to 24° API of the tertiary reservoirs, an artificial lift system it is required, the most used are: gas lift, sucker rod pumping and progressive cavity pumps. The quantity of sucker rod pumping wells represents 52 % of the active wells of the field, which produce oils with viscosities from 100 to 90,000 cP, at a mean well head temperature of 33° Celsius. Wells producing high viscosity oil (less mobility) with sucker rod pumping system, have shown low efficiency problems mainly due to the rod string floating and fluid pound at the pump, as a consequence, flow improver injection was implemented. In order to determine the flow improver effect over the system, a field test was conducted.
The tests were conducted injecting flow improver by the annular at different concentrations and registering well parameters (well head pressure, temperature, liquid level, polished rod load, dynamometric cards, oil rate), also, the viscosity changes of the produced oil was evaluated. During the test, two different flow improver injection protocols were followed, one of them was established to inject from low to high doses, the other one, to dose form high to low doses.
The results obtained demonstrate that at the actual operation conditions, mechanical shaking is required to turn the hydrocarbon-flow improver mix homogeneous, reaching
Modification of the Kozeny-Carman Equation To Quantify Formation Damage by Fines in Clean, Unconsolidated Porous Media
Authors: Krauss Eva D. , Mays David C. 
Published: June 2014

SummaryEstimating formation permeability as a function of porosity, grain size, and the quantity and structure of fines is important in reservoir engineering. One can use the Kozeny-Carman equation to estimate the permeability of clean, unconsolidated media as a function of porosity and grain size, but it does not account for the quantity and structure of deposited fines. This study shows how incorporating of the volume of fines and a dimensionless bulk factor into the Kozeny-Carman equation can be used to model how the quantity and structure of deposited fines control permeability. Several experimental studies from the literature are analyzed, representing a range of fines (type and diameter), porous media, fluids, and Darcy velocity. These studies indicate that, when other variables are held constant, experiments conducted at a higher Darcy velocity result in less plugging. For each experiment, a dimensionless bulk factor in the Kozeny-Carman equation was fitted, with use of the root-mean-square method, to best match the experimental data. Fitted values of the bulk factor were then correlated with the Péclet number to investigate how the structure of fines, quantified by the bulk factor, depends on the characteristics of the porous media, the depositing colloids, and the Darcy velocity. Larger bulk factors are observed at a lower Péclet number, when diffusive transport dominates, which could result from more-dendritic deposits. Smaller bulk factors are observed at higher Péclet numbers, when advective transport dominates, which could result from deposits that are more compact. By understanding how the bulk factor, and, therefore, the extent of permeability reduction, depends on the Péclet number, one can optimize pumping schemes. The primary application of this work is to optimize well-pumping rates to prevent or manage plugging that results from the deposition of fines in initially clean, unconsolidated porous media, including both geologic formations and gravelpacks used for sand control.
A New and Practical Oil-Characterization Method for Thermal Projects: Application to Belridge Diatomite Steamflood
Authors: Zhang L.. , Pieterson R.. , Dindoruk B.. , Stoffels P.. , Fan Y.. 
Published: June 2014

Summary
Most of the oil-characterization approaches for thermal recovery are designed for heavy oils at moderate temperatures, in which oil can be represented in very simplistic ways (such as “gas” and “oil”). However, when oil is exposed to very high steam temperatures (i.e., 550°F), and/or the oil is lighter than the classical range defined for heavy oils and is exposed to a wide spectrum of thermal effects, such as distillation of the lighter ends, the conventional methods of representing the interaction of steam and the in-situ fluids are not accurate. In many cases, we have to first evaluate the quality of the data, and then represent the average behavior with a single most likely fluid model per reservoir segment (plus other scenarios, as needed) to simulate the production performance. There is a need to develop a streamlined approach to bring such data into industrial simulators in a practical way.
In this study, we have developed a fit-for-purpose approach to generate a consistent pressure/volume/temperature (PVT) model over the whole reservoir, reflecting both pressure and temperature changes through the entire oil accumulation. The model represents the oil viscosity for a wide spectrum of temperatures, from reservoir temperature to steam temperature (thermal-process range). A systematic lumping scheme enables conversion of the characterized PVT model for numerical simulators with the minimal number of pseudocomponents while still capturing the essence of thermal physics. To our knowledge, there is no systematic study of this nature available in the literature.
We have tested this approach in the Belridge diatomite steamdrive project. The study confirmed that steamflood incremental oil production in a light-oil reservoir is sensitive to the component-lumping scheme because of distillation of the lighter ends. We also found that a five-component PVT model, representing the physics in “fit-for-purpose” dynamic simulation, best compromises between minimal number of components and physical description of the light-oil behavior.
Estimation of Production Rates With Transient Well-Flow Modeling and the Auxiliary Particle Filter
Authors: Lorentzen Rolf J. , Stordal Andreas S. , Nævdal Geir , Karlsen Hans A. , Skaug Hans J. 
Published: June 2014

Summary
In the current work, we combine a detailed transient multiphase well-flow model and modern estimation techniques into a tool for better representation of flow rates in petroleum wellbores (influx or outflux). Accurate flow rates lead to better well control and reservoir management, which again are important for the improved recovery of oil from existing petroleum fields.
To achieve this, it is possible to use the fact that smart wells with multiple zones and laterals are more common, and they may be equipped with permanent instrumentation and control. Many wells have pressure and temperature gauges in each zone, or even distributed temperature sensing with high spatial resolution. Today, accurate flow-rate measurements or accurate estimates for each zone are lacking, and existing tools are often limited to steady-state models with no uncertainty analysis.
The estimation technique applied here is the auxiliary-sequential-importance-resampling (ASIR) filter, which has the advantage of being more-robust and -reliable than the traditional particle filter (PF). The ASIR filter is used to tune the output of specific stochastic models of the flow rates. To perform this tuning, we have chosen a jump-type model for the flow rates. These kinds of models are popular within areas such as econometrics and finance. More specifically, the model implies that the flow-rate process changes structure governed by an underlying Markov jump process. Using this type of model makes us capable of capturing not only smooth transitions but also more-abrupt changes of the flow rates.
We have applied the methodology on two synthetic studies (involving multiple zones and fluids), and our case studies clearly demonstrate the feasibility of the automatic identification of reservoir flow-rate distribution from wellbore measurements.
Multiphase Flow of Water, Oil and Natural Gas Through Vertical Flow Strings
Authors: Tek M. Rasin 
Published: June 2014

Introduction
Multiphase flow through vertical pipe is encountered in many engineering installations. In petroleum, chemical process, nuclear engineering and many other industries, problems associated with simultaneous flow of two or more phases through vertical pipe have been of interest for a long time. This interest has increased considerably during recent years due to applications to new processes in petroleum production and refining and to problems of steam generation and heat removal from nuclear reactors. One prominent example of vertical two-phase flow is provided by the gas-lift process where oil, water and gas flow simultaneously. If the pressure profile in a gas-lift well can be predicted within reasonable accuracy, it would be possible to get good estimates of the power required to lift the oil, the optimum depth, the pressure and the rate at which to inject gas. Furthermore, the effect of production rate and tubing sizes on these quantities can be evaluated before any design decisions are made on the installation and operation of the flow string.
The majority of experimental work available in the literature deals with two-component systems where individual phase flow rates in and out of the pipe remain constant. The general problem of prediction of pressure drops in multiphase flow systems is very complicated. The co-existence of numerous flow patterns of widely different geometry and mechanism, conditions of surface instability and the nature of force fields acting upon the system are among the major difficulties commonly encountered. The classical approach of fluid dynamics which would be based upon the formulation and solution of Navier-Stokes equations has been found by many investigators completely devoid of any hope of success -- not only because of inherent nonlinearities but also because of insurmountable analytical difficulties standing in the way of setting up the boundary conditions. The presence and effect of interfacial forces on multiphase flow systems further complicate the theoretical approach. For these reasons, many investigators choose to adopt semi-empirical if not purely empirical approaches in order to obtain solutions of engineering utility.
Analysis and Countermeasures on the Efficiency of the Pumping Wells System in the Old Oil-field
Authors: Suling Wang , Tiejun Zhou , Yang Gao , Ying Long , Siyuan Huang , Yuning Wang 
Published: June 2014

Abstract
In China, some old oil fields into the late stage of development, the wellbore fluid become complexity, and the production and the pump efficiency gradually decline, which lead to an increase in production costs. According to the statistics, the efficiency of 36.7% of the total wells are lower than 30%, By analyzing the main reason for the low efficiency of the pump and combined the status of oil well production, statistical analysis on the impact of system efficiency under different working conditions and establish a corresponding model. The model mainly analyses the impact of stroke number, the stroke, the pump diameter, the submergence depth and gas content on pump efficiency. According to the well structural characteristics, a geometric model of the downhole rod system is established and the finite element model is generated by unit discrete. Considering the boundary conditions of the contact boundary of the sucker rod and tubing, the frictional resistance between the sucker rod and well fluid, the frictional resistance between the plunger and the pump barrel and the process of loading and unloading of the oil column, the numerical solution technology is adopted, which can reproduce the state of deformation of the rod string in a stroke, and gain the indicator diagram of the down hole pump and the efficiency of the system the down hole rod. Selecting the test wells of the oil production plant in Daqing Oilfield to check the model, the results show the error of pump displacement is 0.7% and the error of rod efficiency is 7.8%. On the basis of this analysis, the different stroke, pump speed, dynamic liquid level and pump diameter impact on the rod efficiency is analyzed. The calculation results show: the rod efficiency decreases with the increase of stroke and pump speed, the rod efficiency increases with the increase of fluid level and pump diameter and when the product of the stroke and stroke number is a fixed value, high speed and low stroke is beneficial to improve the efficiency of rod.
Real-Time Azimuthal Gamma and Resistivity LWD Data Used to Navigate Complex Unconventional Reservoir - Western US Land
Authors: Martin Stephen J. , Thomas Mark G. , Hammons Shane D. , Wilke Nate 
Published: June 2014

Abstract
The Denver-Julesburg Basin in northern Colorado is an unconventional hydrocarbon play utilizing horizontal wells to access several targets, known locally as benches, including the Niobrara B-Chalk. The need to navigate and optimally place completion packers in the unconventional play with complex, laminated rock structure and sub-seismic faulting is important to effectively stimulate productive rock. While bulk gamma is primarily used to correlate the formation, more advanced real-time LWD technology is proposed to navigate effectively and maintain the wellbore within the specific target chalk. A high resolution LWD electrical imaging tool is also employed to optimize the completion strategy and confirm real-time interpretations.
An azimuthal gamma ray image was used to determine formation bed dip and stratigraphic complexity along with two different resistivity measurements to correlate position within the reservoir. Thedata was transmitted in real-time to a remote geo-steering center where a Reservoir Navigation Engineer incorporated the data into the geological model and provided the operator with real-time steering recommendations for remaining within the zone of interest. Additionally, the data were used toidentify faults and interpret the fault-throw direction and distance.
The well was drilled with 85% of the lateral section placed in a 10-ft-thick target zone compared to less than 50% in offset wells navigating with gamma only. This was accomplished despite crossing over one sub-seismic fault and having relative formation dips varying from 88 to 92 degrees.
The improved net-to-gross was a result of the utilization of azimuthal gamma, multiple propagation resistivity, and the real- time Reservoir Navigation Service (RNS). The increased "in-zone" footage indicates this method provided a significant advantage over gamma-only measurements when navigating such complex and faulted formations. Post well, the high resolution LWD electrical image logs were used to confirm the faults and determine packer placement for optimal completionefficiency.
Detection of Symptoms for Revealing Causes Leading to Drilling Failures
Authors: Skalle Pål , Aamodt Agnar , Gundersen Odd Erik 
Published: June 2014

SummaryWhen a diagnosis of a problem is known, the problem can usually be solved efficiently. This paper presents a method that helps reveal the most probable cause of a drilling-process failure immediately after occurrence. Normally, it takes some time to investigate and evaluate all available information before the correct cause can be determined. The method presented is targeted at reducing this time and at the same time improving the quality of the interpretation. The method relies on input parameters from the ongoing drilling process, parameters that behave irregularly and are referred to as symptoms or errors when the irregularity is severe. Recognized symptoms are used as input parameters in a knowledge-modeling method that relates symptoms to failures. The method was verified on the basis of historical drilling data, and its ability to point out the correct causes with high probability was demonstrated. Field testing the method is yet to be performed.
Gelled Emulsions of CO2-Water-Nanoparticles
Authors: AlOtaibi Fawaz M. , Kokal Sunil L. , Chang Yun C. , AlQahtani Jassi F. , AlAbdulwahab Amin M. 
Published: June 2014

Abstract
Enhanced oil recovery by CO2 injection is an effective method for recovering additional oil beyond waterflooding. In recent years it has garnered a lot of attention for two primary reasons: (a) the stable high price of oil and (b) environmental aspects of CO2 sequestration. Its use has been increasing steadily over the past few years. In many respects it is a win-win situation with CO2 sequestration and additional, incremental oil produced. However, the CO2-EOR process is handicapped, especially in thick reservoirs, by CO2 gravity override. Due to density differences between the injected CO2 and resident fluids in the reservoir, the lighter CO2 tends to rise to the top of the reservoir thereby bypassing some of the remaining oil. This results in poor sweep efficiency and conformance. Different techniques have been used to overcome the CO2 gravity override by either increasing its density, viscosity, or reducing its relative permeability. This paper investigates the use of gelling CO2-water emulsions, stabilized by silica nano-particles, to control the mobility of CO2.
The stability of nano-particles was first investigated using iso-octane (iC8) as a proxy for CO2. The stability of these emulsions, or foams, was investigated as a function of nano-particles concentration, type, hydrophilicity degree, and also as a function of iC8/water ratio. The silica nano-particles concentration ranged from 0.5 to 2 wt%, and iC8 phase volume ranged between 50 and 90%. Stability experiments were conducted at room temperature and up to 17 hours using both hydrophobic and hydrophilic colloidal silica nano-particles. Following the screening studies with iC8, rheological measurements were made using CO2 at 200°F and 1,800 psi at different (CO2/water) ratios and nano-particles concentrations. Compared to pure liquid CO2, high emulsion viscosities from 1.1 to nearly 2.5 cP were achieved. These values represent almost a 100-fold increase over pure sc-CO2 viscosity. Additionally, in some cases rigid gels were observed with time following emulsion generation. The CO2-water-nanoparticle emulsions were generally stable. This work provides the rheological results of the emulsion systems as a function of time, nano-particles concentration and CO2 phase volume. The high viscosity CO2/water emulsions have the capability to enhance CO2 mobility, act as a diverting agent during CO2-EOR, and improve sweep efficiency.