bluuebunny/crossref_metadata_2025_split huggingface dataset:
En Route to the e-Field: Effective Decision Making Assisted by E&P Web Portal Solutions
Authors: Giménez L. 
Published: December 2007

Abstract
Currently, nearly all oil and gas upstream organizations utilize some sort of digital workspace tools to access their petrotechnical data. This paper provides an insight into the role of the digital workspace in improving operations based on data browsing and access in real- or near-real time by utilizing Web portal tools that ▪Reduce exploration and development cycle times▪Enhance reservoir recovery▪Optimize production▪Significantly decrease personnel needed in high-risk, high-cost areas.
These improvements are made possible by leveraging network connectivity (Intranet, Internet) and intelligent systems. By bringing E&P-qualified data and information to the user's petrotechnical desktop, productivity increases, collaboration is promoted, and knowledge is shared among members of the communities within the organization.
Field data is either captured manually or digitally streamed from automated devices that take readings directly from wells and/or production facilities. High-frequency data historians are linked to corporate master data stores. Users access the information from these disparate repositories through a common standard single-point Web interface that is fully customizable. This information is extracted and can be displayed in the form of location maps, bubble maps or pie charts, tables, reports, and charts. Users also have access to systems for faster effective decision making that warn them based on thresholds, key performance indicators (KPIs), and smart alarms. These systems integrate finance and petrotechnical information, including lifting cost per asset team, production sales, field/facility/well production volume, highlights on recent well tests, well test and/or production (injection) variations, well status (downtime) alerts, well trend analysis, comparison detail on distinct operations types, casing running time, wellbore schematics, daily drilling reports, completion and workover information, health, safety, and environmental information, etc. By connecting people to data and information, upstream organizations ensure access to exactly what geoscientists and engineers need to do their jobs in a better and more efficient way, improving the quality and speed of the decision taking.
Three specific Middle Eastern case implementations are herein detailed as examples of how Web portal data access solutions provide optimization and automation of E&P workflows.
Stress Corrosion Cracking of Corrosion Resistant Alloys in Brine Packer Fluids
Authors: Craig B. D. , Webre C. M. 
Published: December 2007

Abstract
There have been several recent failures of corrosion resistant alloy (CRA) tubing strings in brine packer fluids as a result of stress corrosion cracking (SCC). These failures have been unexpected based onearly studies that only examined the various brine fluids and common CRAs without concern for the impact of inhibitors added to the brine and the charging of the brine with acid gases from leaks in the tubing or packer connections. This paper presents laboratory work that demonstrates 13Cr and 22Cr alloys are very susceptible to SCC in brines charged with CO2 and H2S even at moderate temperatures but that the high nickel alloys, such as Alloy 825 are much more resistant.
Stimulation of High-Temperature Sandstone Formations From West Africa With Chelating Agent-Based Fluids
Authors: Ali S. , Ermel E. , Clarke J. , Fuller M. J. , Xiao Z. , Malone B. 
Published: December 2007

Abstract
Fluids based on chelating agents have been developed for matrix stimulation of high-temperature sandstone formations. These fluids dissolve sizeable amounts of calcite and clays and maintain high levels of dissolved metal in solution over time with minimal precipitation. A series of field samples from high-temperature (149°C) sandstone reservoirs in a West African formation bear carbonate concentrations ranging from 2 to 37% (w/w). The effects of matrix treatment using a chelating agent-based system on these field samples were studied using coreflood and slurry reactor experiments.
Linear coreflood test data show dramatic increases in the formation permeability after treatment with the chelating agent-based fluid. The improvement in permeability is ascribed to the removal of carbonate minerals and soluble clays, without secondary metal-precipitation. Slurry reactor tests elucidated the kinetics of mineral dissolution in mechanically ground field samples. Treatment with acidic chelant fluids generated high levels of dissolved calcium, silicon, and aluminum that remained in solution over time. For comparison, conventional mineral-acid treatment of the field samples generated high levels of metals in solution that declined over the same period of time, indicative of secondary precipitation. The effectiveness of the chelant fluid for stimulation of this high-temperature formation was confirmed through increased formation permeability and high levels of dissolved minerals.
A Pore Network Modeling Approach to Predict Petrophysical Properties of Diatomaceous Reservoir Rock
Authors: Jia L. , Ross C. M. , Kovscek A. R. 
Published: December 2007

Abstract
A novel three-dimensional pore network model of two-phase flow was developed to compute permeability, relative permeability, and capillary pressure curves from pore-type size and shape data information measured via high resolution image analysis of rock samples. The diatomite model is constructed using pore-type proportions obtained from image analysis of epoxy-impregnated polished samples and capillary pressure curves for diatomite cores. Multiple pore types are measured and each pore type has a unique pore size and throat size distribution that is incorporated in the model. Network results present good matches for relative permeability and capillary pressure when compared to experimental measurements. The pore network model is applicable to both drainage and imbibition within diatomaceous reservoir rock. Correlation of network model results to well log data is discussed, thereby interpolating limited experimental results across the entire reservoir column. Importantly, our method has potential to predict petro-physical properties for reservoir rocks with either limited core material or for which conventional experimental measurements are difficult, unsuitable, or expensive.
Exposing Accidents: Moving Safety Focus from Likelihood to Exposure
Authors: Spigener J. 
Published: December 2007

Abstract
This paper discusses how changing the organizations focus from preventing accidents to exposure reduction is a critically necessary step to achieving a zero injury culture. This focus adjustment allows a company to no longer try to define which actions and judgments will be at the root of the next injury or event. The initial discussion begins with an examination of the problem with an injury-focused safety program as well as the working interface between the worker and the equipment. The difference between making decisions on actions based on whether I think there is a likelihood of an injury and whether exposure is changing regardless of the possible outcome will be explained. This seemingly small obtuse point will be illustrated with the use of several everyday examples. We will examine five areas in which a shift to exposure focus can occur. Lastly, we will leave you with some suggestions about going forward in your safety focus planning.
A Novel Approach to Eliminating Sulfur Deposition in Liquid Redox Hydrogen Sulfide Removal Systems
Authors: Roberts J. A. , Roberts R. S. 
Published: December 2007

Abstract
Hydrogen sulfide-rich natural gas is a common by-product of thermally enhanced oil production in California's San Joaquin Valley. Regulatory emission limits necessitate the removal of sulfur compounds prior to incineration of the natural gas in steam generation units. Aera Energy LLC utilizes the SulFerox® process for sulfur removal at several operating locations. Sulfur deposition is a common problem within the piping and vessels throughout SulFerox systems.
The Aera Moco SulFerox facility produces over 1.5 long tons of sulfur per day. Plant shutdowns were typically required every six weeks to remove solid sulfur accumulation within the gas sparger vessel and skid piping. An engineering study was initiated to determine how to best reduce the operational disruptions caused by these frequent cleanings. Following the investigation of several alternatives, a daily online cleaning method involving the redesign of the sparger gas injection piping was installed. This redesign involved retrofitting the sparger vessel with an improved lateral design that resulted in increased gas velocity as well as improved gas distribution. In addition, the laterals were configured so that each one could be individually taken offline and cleaned with a "blast" of natural gas while the sparger vessel remained in service. This method was chosen over several alternatives due to its relatively low installation cost, low operating cost, high reliability, and elimination of personnel exposure hazards. Since implementing the online cleaning system in September 2003, the sparger vessel remained in service for one year before it was taken offline for cleaning and inspection.
This paper discusses the online cleaning system design as well as several alternatives that were investigated. The successful results to date are reviewed along with potential future system enhancements.
Combining Geostatistics with Dynamic Modeling to Improve Reservoir Management Strategies: A Case Study from the Balingian Province
Authors: Finol J. , Dronamraju S. , Zakaria A. A. , Koraini A. M. 
Published: December 2007

Abstract
This paper presents an application of geostatistic in the context of a full field review study for D18 field. A two-stage stochastic modeling approach is applied to distribute the reservoir heterogeneities resulting from different rock types and the inherent spatial variability of the petrophysical rock properties. Firstly, facies distribution is simulated while preserving the main fault features. Secondly, porosity and permeability images are simulated on the basis of facies distribution, providing small-scale variability of these two properties. The fine-scale stochastic grids are upscaled to coarser simulation grids for dynamic reservoir modelling and initialized to static equilibrium condition. Production history match is used as the ranking criterion for selecting the reservoir model to be employed for production forecasting.
A Method for Pattern Recognition of WOR Plots in Waterflood Management
Authors: Yang Z. , Ershaghi I. 
Published: December 2007

Abstract
Pressure maintenance by waterflooding is a prominent recovery process in many of California oilfields. Majority of these turbidite sandstone reservoirs contain highly heterogeneous permeability profiles affected by alternation of sand shale sequences and the clay content. A typical signature of such heterogeneous profiles is often the existence of a high permeability streak serving as a "thief zone". Mechanical or chemical blocking of such layers on the injection or production side has been an objective of water flood management.
This paper presents a novel method for using a series of customized type curves to scrutinize the WOR characteristics plots of producing wells in stratified reservoirs. From a library of systematically generated performance plots for several combination of rock and fluid properties, and various architectural position of the high permeability zone, the actual data for a given well or a group of wells can be matched against various patterns to identify the degree of heterogeneity and the potential existence of a high permeability streak. With such a pattern recognition tool, opportunities to enhance the performance of individual wells or group of wells can be ascertained. Additionally, the impact of permeability modification by mechanical or deep chemical zonal isolation has also been studied. In brief, we have generated yardsticks by which the effectiveness of wellbore isolation or in-depth plugging of high permeability streak can be examined.
Applications of Pulsed Neutron Capture Logs in Reservoir Management
Authors: Morris F. , Morris C. , Quinlan T. 
Published: December 2007

Abstract
Pulsed neutron capture (PNC) tools are considered a primary evaluation means in reservoir monitoring and surveillance. Systematic time-lapse PNC logging gives a detailed and dynamic picture of the reservoir saturation response to production and injection operations. The neutron capture cross section measurements offer the essential means to monitor hydrocarbon saturation, water breakthrough, and fluid contact changes in a timely manner.
The recent introduction of a new generation of pulsed neutron capture logging tools has lead to a reappraisal of the design of reservoir monitoring logging programs. Efficient reservoir management requires that the latest PNC tool technology be comparable with the older measurement results to provide continuity, precision, and accuracy in the monitoring program. A new sigma processing technique was developed for the dual-burst pulsed neutron capture measurements to accomplish this objective. This technique maintains the resolution and repeatability of the new-generation tools but provides results needed for reconciliation with the older generation tools used for more than 20 years in reservoir monitoring.
The sigma processing technique is described relative to the old and new generation tools, which utilize radically different approaches. Diffusion, borehole, and lithology effects must be considered when transforming observed quantities such as decay times or near-to-far ratios to actual physical quantities. General considerations of repeatability and accuracy are discussed which apply to PNC logs and their use in both stand-alone and time-lapse techniques.
More than 30 cases have been evaluated with the new processing technique. Examples are presented that show reservoir monitoring results obtained in a wide variety of formation lithologies, formation fluids, and borehole environments to illustrate the robustness of the technique. These cases include detailed analytic studies between the PNC tools. The results indicate that the new sigma processing can provide direct time-lapse reservoir monitoring continuity and yield accurate reservoir saturation analysis.
Direct Monitoring of the Performance of Scale Control Programs Across the Produced Water Life Cycle Via Suspended Solids Analysis
Authors: Jordan M. M. , Buckman J. , Johnston C. J. 
Published: December 2007

Abstract
Effective scale control in production of hydrocarbon deposits is in many fields essential to the economic and safe production of hydrocarbon and associated fluids. Chemical inhibitors of inorganic scale (carbonate and sulphate) have long been applied to subsurface (continual injection or squeeze) to flow lines/process equipment along with the growing area of produced water reinjection. The following paper will outline a method of improved performance monitoring of such chemical treatments. The measurement of suspended solids is a common practice to determine injection water quality but the measurement of the type, amount, texture and composition of solids within produced fluids via environmental scanning electron microscopy (ESEM) combined with energy dispersive analysis (EDX) has not until now been used as a routine method to monitor the effective scale control programs applied downhole, topside and for produced water reinjection. The collection/filtration of small quantizes of produced water that are subsequently analyzed for the texture and composition of sulphate/carbonate solids has been used in a number of fields within the North Sea and Gulf of Mexico as a direct method of scale inhibitor performance. This novel method of measuring chemical performance that does not rely on chemical or brine analysis and allows drilling related solids to be differentiated from scale formed within produced brine. The paper will present results from 4 fields to illustrate the value this method of monitoring was able to bring the field operators to optimize scale squeeze treatments and topside treatment rates.
Low Salinity Oil Recovery: An Exciting New EOR Opportunity for Alaska's North Slope
Authors: McGuire P. L. , Chatham J. R. , Paskvan F. K. , Sommer D. M , Carini F. H. 
Published: December 2007

Abstract
Laboratory studies conducted over a period of many years have indicated that oil recovery could be improved by injecting lower salinity water (less than about 5,000 ppm). Although the recovery mechanisms are still uncertain, they appear to be similar to those found in alkaline flooding. Recent successful field trials have led to serious evaluation of field-scale implementation of low salinity EOR.
Four sets of single well chemical tracer tests (SWCTT) performed in Alaska confirmed that the favorable laboratory results could be replicated in the field. The SWCTT results (two in the Ivishak sandstone, one each in the Kuparuk and Kekiktuk sandstones) showed that waterflood residual oil saturation (Sorw) was substantially reduced by low salinity water injection. The low salinity EOR (LoSal) benefits ranged from 6 to 12% OOIP, resulting in an increase in waterflood recovery of 8 to 19%. Based on these encouraging results, low salinity oil recovery is being actively evaluated for North Slope reservoirs.
A New Method to Evaluate Cement Systems Design Requirements for Cyclic Steam Wells
Authors: Myers S. , El Shaari N. , Dillenbeck L. 
Published: December 2007

Abstract
Evaluating a cement system for zonal isolation and its ability to support the casing have always, among other parameters, used compressive strength as an important set cement slurry requirement. Recent studies have concluded that compressive strength is not the most important characteristic of the cement to provide zonal isolation and casing support. Elasticity and tensile strength of the cement system is more important for casing support and zonal isolation. In Kern county California, cyclic steam wells are a common completion method for heavy oil recovery. These wells may have temperature variations between production and steam injection cycles of up to 300°F. These extreme wellbore temperature swings create a large amount of induced stress on the cement sheath. Currently, the industry approach is to develop the highest compressive strength cement system possible to maximize cement bonding. However, advanced modeling now available indicates that such systems might not be optimized for such applications. A lightweight cement system has been developed and laboratory tested utilizing fit-for-purpose additives to give the set cement enhanced elastic and tensile properties. This paper will discuss the design and development, along with the potential application of an enhanced set-cement mechanical property system. The results of a Cement Stress Model, and the impact on cementing cyclic steam wells will also be presented.
Performance of Downhole Separation Technology and its Relationship to Geologic Conditions
Authors: Veil J. A. , Quinn J. J. 
Published: December 2007

Abstract
Management of produced water presents challenges and costs to operators. If the entire process of lifting, treating, and reinjecting can be avoided, costs are likely to be reduced. Oil and gas industry engineers have developed various technologies that separate oil from water or gas from water inside wells. These devices are known as downhole oil/water separators (DOWS, or according to some, DHOWS) and downhole gas/water separators (DGWS). This paper summarizes a recent report by Argonne National Laboratory that provides data on 59 DOWS trials and 62 DGWS trials from around the world. The report focused on the performance success of each trial and the geological conditions of the producing and injection formations. The goal of the study was to identify the types of geological formations that would present the best chance of success for future DOWS or DGWS trials. Upon reviewing these DOWS and DGWS installations, we concluded that it was not possible to predict the success of an installation solely on the basis of the geology of the production formation or injection formation.
Evaluation and Optimization of Solids-Control Equipment Systems Reduce Waste Volumes, Improve Safety, and Lower Costs
Authors: Rengifo R. , Browning K. , Carruyo F. , Bernal G. , Figueroa V. , Medina J. 
Published: December 2007

Proposal
In their efforts to optimize solids control systems, companies in this region have implemented improvements in both the equipment design and operational performance, in order to reduce fluid maintenance costs and decrease the volumes of fluid lost on the cuttings. These improvements helped to optimize the operation and the number of units used during the operation, while maintaining excellent mechanical removal efficiency in the solids control units.
In 2001, after completing a comprehensive evaluation of the "dryer centrifuge" system used in Venezuela by PDVSA-Oriente, a major drilling fluids company proposed that PDVSA test a new array in the solids control equipment (SCE) system. The first phase addressed the incorporation of a flow distributor at the end of the return line and the redistribution of the flow line shakers in parallel form. The results obtained in this first phase made it possible to propose new recommendations implemented in a second phase of the optimization study, which was based on reduction of the number of units (de-incorporation of the screw conveyor and the dryer screen) and optimization in the design of the screen mesh.
This paper presents the results obtained by applying a new focus for evaluation and optimization of solids control services on drilling rigs. The optimization plan was carried out on nine rigs. Costs associated with solids control service were reduced because fewer units were needed, less fluid volume required processing, the screen design allowed for a more efficient consumption rate, and the volume of fluids to be disposed of environmentally were monitored and managed better. Moreover, the technical competency of the field personnel was improved and, even though fewer units were used, a good balance was maintained between efficient service and the removal of fluid from the drill cuttings.
An Effective Solution To Repair Severely Corroded Casing Strings: Applications in the Oriente Basin of Ecuador
Authors: Simbala V. , Palomeque M. , Evers R. , Ordonez E. 
Published: December 2007

Abstract
In the Oriente basin of Ecuador several operators, including the National Petroleum operator, are producing oil at approximately 455,000 B/D and having high numbers of workovers. Many wells have been closed because they were considered uneconomic, and studies have been carried out to re-open them and increase the production.
Some operators have big problems because of aggressive corrosion in the old strings. In many wells the corrosion is so great that a part of the casing literally disappears. Splits and cracks are very common in old strings. Under these conditions, the life of the well is limited to the life of the casing if a good solution is not found.
To solve these problems, we demonstrated a use of special fibers technology that is outside its original design purpose. From the economical side to close a well means to lose the investment made in the well and lose the oil production. For this reason, finding a good technical solution that allows the wells to be reopened adds value to an existing asset and contributes to ultimate recovery.
In the past conventional cement slurries were used to address the problem with poor results; the cement could not support the pressure test.