bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Field Experience Against Corrosion: Performance Report of Bronze
Authors: Olmos D. , Ameglio A. F. , Tapia R. , da Silva L. , Ramirez G. , Poli M. 
Published: December 2007

Abstract
This work describes the experience in the use of Bronze-Aluminum coated sucker rods at Chihuidos de la Sierra Negra and Lomitas fields, operated by REPSOL-YPF (Rincón de los Sauces - Neuquén).
This new material was developed specifically to work in the corrosive environment of the oil producing wells of those fields. This development was a result of a team work, manufacturer and user. Its objective was to find an acceptable solution (technical and economics) for the sucker rods used at these fields.
Experience on implementation of Environmental Management System (EMS), according to ISO 14001, in Complejo Campo Durán, Salta Province, Argentina
Authors: Díaz Norberto Daniel 
Published: December 2007

Abstract
The target of this paper is to transmit the experience of the people of Refinor S.A., about the environment management system implementation, focusing in the motives which caused such a decision, the difficulties we had and the benefits obtained, getting a final conclusion.
New Techniques for Risk and Hazard Management in the Petrochemical Industry
Authors: Chamberlain G. A. 
Published: December 2007

Abstract
In today's regulatory and business environment in the petrochemical industry, the onus is placed increasingly on the plant operator to demonstrate that safety risks are tolerable and as low as reasonably practicable. The physical effects of accidents, such as explosion overpressure, heat radiation and toxic dispersion, have to be calculated to assess the threat to people and whether escalation and further threat are real possibilities. Accurate assessments based on realistic accident scenarios can avoid costly over-design in terms of protective measures and ensure that all hazards and effects are correctly identified. This paper reviews recent developments in the science, validation, quantification and application of these physical effects to improvements in plant safety. Some examples using the latest hazard assessment tools as applied to refineries, gas plants and offshore platforms will be discussed.
Integrated Reservoir Study in El Tordillo Field
Authors: Muruaga E. , Antunez E. , Nogaret C. , Stancel S. 
Published: December 2007

Abstract
An Integrated Reservoir Study was performed in El Tordillo Field, a very complex stratigraphic area located on North Flank of the San Jorge Basin, Argentina. Despite some limited and scarce information, Reservoir Compartments, Barriers and Original Oil/Water contacts were defined by integrating fluid content estimates derived from a Fluid Saturation Model built before, with well production, test and completion data and with the detailed mapping performed during Phase 2. A waterflood project performed in the area, was analyzed in detail in order to get sweep and recovery efficiencies.
Stochastic methods were employed to estimate the OOIP. Based on the Electrofacies results, these methods were statistically used to distribute rock types and properties in space within the volume under analysis. Consequently, statistical ranges of OOIP estimates were obtained for several intervals within the Study Area.
Qualitative Maps of Original Mobil Oil were constructed on the simulation model of the water-flooded area. Qualitative Fluid Movement Maps were constructed from the result of the numerical simulation.
Application of Decline-Curve Analysis Technique in Oil Reservoir Using A Universal Fitting Equation
Authors: Fekkane Abdelhafidh , Tiab Djebbar 
Published: December 2007

Abstract
The analysis of oil production data using decline curves is a modeling and forecasting technique. Actual production rate and time data are history matched to a theoretical model using specialized graphs known as type curves.
This study begins with a review of the previously developed decline curve construction and analysis methods. It consists of reproducing Arps-Fetkovich type curves and the derivative type curves for advanced decline curve analysis. A Program was developed to generate the dimensionless rate-pressure and time data necessary to construct Fetkovich type curves.
Combining the analytical solution derivative for transient flow based on numerical analysis, and the empirical solution derivative for boundary dominated flow develops the derivative type curves.
The type curves is used to identify the transient versus depletion stages and to estimate reservoir parameters and future decline paths.
Field production data are generally difficult to match with the type curve for this reason a Universal Fitting Equation is proposed as an alternative to manual type curve matching. This equation combines both Arp’s empirical equation and Fetkovich analytical solutions. It equation offer the following advantages: Fitting with the equation is more precise than type curve matching to obtain reservoir dimensionless radius reD, Arp’s exponent b, matching points q/qDd, and tDd/t.The real production data can be fitted directly by the equation without using smoothing techniques.The radial and pseudosteady state regions are determined automatically and easily from fitting.Some production data that were insufficient to be analyzed with manual type-curve matching can be interpreted with the Fitting Equation.
This procedure has been applied to some Real field data from Hassi Messaoud field cases and it has given significant results.
Cased Hole Formation Resistivity: Changing the Way We Find Oil and Gas
Authors: Bartenhagen Keith J. , Bradford Jon C. , Logan Dale 
Published: December 2007

Abstract
In today’s competitive market it is increasingly important to improve production and increase reserves in the most efficient way possible. One alternative is to add new wells, but this can be an expensive and time-intensive endeavor. Another alternative is adding and optimizing production from the thousands of existing wellbores already in place. To do this, the ability to detect and evaluate bypassed hydrocarbons and track fluid movement in the reservoir is vital. Current methods of through-casing saturation determination using nuclear tools are limited because of their shallow depth of investigation.
With the introduction of the CHFR* cased hole formation resistivity technology a new dimension has been added to cased hole evaluation. A deep-reading formation resistivity can now be obtained through steel casing. Although this measurement is analogous to exsisting techniques for saturation determination, it has two distinct advantages: In many cases there is a need to monitor saturation changes in a producing interval. In the past sigma-based interpretation methods were the only option. However, saturation determination in low-porosity reservoirs (&lt;15 pu) using sigma requires a very detailed and accurate lithology description because small errors in the lithology answer have a significant effect on the saturation from sigma. Because many reservoirs in the Permian Basin combine complex lithology with low porosity, answers can be somewhat unreliable. This is often the case in shallow water-flooded carbonates, where the presence of gypsum, anhydrite and salt makes sigma measurements almost impossible to interpret.Cased hole saturation is also needed to detect bypassed pay and occasionally as the primary evaluation method. In these cases, sigma-based measurements fail because of their shallow depths of investigation. Because the zones have not been produced yet, the invading fluid (brine) still occupies the pores around the borehole. This is particularly true in the Permian Basin because no fluid control measures are used during drilling and deep invasion is normal. The CHFR tool reads deep enough to avoid this complication. In fact, it is commonly superior to openhole resistivity since it reads significantly deeper than openhole resistivity tools.
When the CHFR tool is used in conjunction with porosity and lithology tools, run either in openhole or through casing, accurate hydrocarbon saturation can be determined. This methodology can be used to find bypassed pay or to determine the depletion level of producing pay intervals. It has also been used extensively in time-lapse surveys to evaluate the sweep efficiency of secondary recovery, ensuring that no producible hydrocarbons are left behind. This paper reviews the application of this technology in several U.S. basins, including the Permian Basin and California.
Producing The Well In Artificial Lift By a Subsurface Compensated Pump: A New Production Method
Authors: Buchman Smil S. 
Published: December 2007

Abstract
This paper presents a new production method in which the reservoir energy spent to lift the production from perforation-depth to the dynamic liquid level is replaced by surface energy, and consequently the well daily rate and cumulative production is increased by 200 - 250 %. The method can be used in any well at any time.
The paper is based on the analysis of how the reservoir energy generated by the expansion of the reservoir fluids is used to produce the well:PROFITABLE USAGE: Moves the production through the pay zone into the well boreWASTEFUL USAGE: Sends the reservoir energy to:Overcome the liquid friction along the productionflow path.Lift the production from perforation-depth to thedynamic liquid level.
Present production practice recognizes and reduces only the reservoir energy wasted to overcome the liquid friction through the pay zone by using better and cleaner perforations, acidizing, fracturing, and other techniques. When less reservoir energy is used to overcome the frictions through the pay zone, the well performance, in both rate and cumulative production, is increased.
To date all artificial lifting methods are spending surface energy only to lift the production from the dynamic liquid level to the surface. However, the energy needed to lift the production from perforation-depth to the dynamic liquid level, the largest waste of reservoir energy, is now overlooked and has not been recognized as the most important way to significantly increase well performance. The proposed new production method substitutes the reservoir energy by surface energy in order to lift the production from perforation-depth to the dynamic liquid level. Accordingly the well performance in day rate and cumulative production is increased by 200 - 250 % compared to the actual well performance.
The quickest and easiest way to produce the well according to the new production method, is to run a subsurface compensated plunger pump assembled from the API Spec-11AX parts, and work with the same beam pump. A subsurface compensated pump, is a liquid lifting device, which can not be drawn by the well pressure.
Fracturing Fluid Evolution Plays a Major Role in Codell Refracturing Success
Authors: Shaefer Mark T. , Lytle Denise M. 
Published: December 2007

Abstract
Refracturing wells, completed in the Codell formation, has caused a resurrection in activity in the Wattenberg Field of the Denver-Juleseburg (D-J) Basin. HS Resources (HSR) has increased average oil and gas rates by greater than 500% by restimulating over 750 Codell wells. The evolution of applied fracturing fluid technology has played a major role in the success of the Codell refrac program.
This paper will identify and evaluate the benefits to well performance and economics gained from the evolution of fluids used in the Codell refracture program. In this effect, the fluid systems will be compared using treating pressure characteristics, production analysis, fluid properties, and rheological property evaluation via specialized testing apparatus and economic results.
A Type-Curve-Based Spreadsheet Program for History Matching and Forecasting Tight-Gas Production.
Authors: Munoz Juan D. , Chen Her-Yuan , Teufel Lawrence W. 
Published: December 2007

Abstract
This paper describes an Excel™ spreadsheet program for history matching and forecasting production of tight-gas wells. The program is based on a set of recently developed type-curves. This set includes pure- and near-linear flow regimes that are lacking in the original Fetkovich type-curves, but are important for tight-gas production data analysis. The program provides constrained cross-matching between rate, cumulative production, and time to obtain a unique and consistent interpretation regardless of the type of analysis. Main features of data input, cross-type-curve matching, parameter estimations, and forecasting are described using a field example from San Juan Basin (New Mexico) and a numerically simulated example. The spreadsheet program provides a simple method to quickly analyze production data when no other means is available, or when a quick-look is needed before a detailed study. The developed program is for general purposes, however, is most attractive for low-permeability, hydraulically-fractured wells because of the likely occurrence of long-transient, strongly-liner flow.
Impacts of Permeability Anisotropy and Pressure Interference on Coalbed Methane (CBM) Production
Authors: Chaianansutcharit Thotsaphon , Chen Her-Yuan , Teufel Lawrence W. 
Published: December 2007

Abstract
This study analyzes the impacts of permeability anisotropy and pressure interference on CBM (coalbed methane) performance with emphasis on identifying any unique feature that might allow us to diagnose permeability or flow anisotropy. Simulation results indicated that a "dual-peak" behavior in the gas rates arises if drainage boundaries are not influenced at the same time. Examples include anisotropic permeability in a square area and isotropic permeability in a rectangular area. The dual-peak behavior does not present if the drainage area is scaled according to the permeability anisotropy (the "square-root rule"). As noted in the literature, well interference has positive impact by accelerating gas production. The "dual-peak" behavior may potentially provide a methodology to diagnose permeability anisotropy and drainage shape from CBM performance. Further research, however, is needed.
Hydrogen Sulfide Removal from Sour Condensate Using Non-Regenerable Liquid Sulfide Scavengers: A Case Study
Authors: Salma T. , Briggs M. L. , Herrmann D. T. , Yelverton E. K. 
Published: December 2007

Abstract
Hydrogen sulfide (H2S), a corrosive and toxic gas, when present in produced fluids such as condensate, gas and water, poses serious health and operational hazards. Non-regenerable H2S scavengers have been in use for H2S removal from sour gas and condensate for over a decade. Selection of an appropriate non-regenerable chemistry is dictated by the downstream treatment processes that the gas or condensate will be subjected to after H2S removal is accomplished. Successful selection and application of non-regenerable H2S scavengers requires a thorough evaluation of operating conditions such as temperature, pressure, mixing, etc., that affect H2S removal from sour fluids. Most of the applications require on-site optimization to achieve maximum scavenging performance.
This paper presents results and observations from a field trial for sweetening a large volume of sour condensate held in a 70,000 bbl storage tank using a water-soluble triazine-based scavenger. Mode of application of the triazine-based scavenger was found to be one of the most important factors for successful reduction of H2S in liquid hydrocarbons held in large tanks. Another important factor affecting H2S scavenger performance was the presence of sulfide species other than H2S in the sour fluid. Experiences gained from the trial illustrate the importance of a systematic approach required for effective sweetening in liquid hydrocarbons.
Design and Execution of a State-of-the-Art Water Shutoff Treatment in a Powder River Basin Tensleep Producer
Authors: Giangiacomo Leo A. 
Published: December 2007

Abstract
This paper summarizes the literature research on water shutoff treatment technologies, distills the critical elements for designing a treatment in a naturally fractured Tensleep producer, presents the treatment design process, and shares the field operations experiences and treatment results.
The subject well is located in the Teapot Dome Field in the Naval Petroleum Reserve No. 3, Natrona County, Wyoming. The project was funded by the U.S. Department of Energy and the Rocky Mountain Oilfield Testing Center.
The literature and interview research illuminated the aspects of the treatment that are scientifically sound, as well as the areas that are in need of additional research.
The most important factor in treating wells for excessive water production is the characterization of the water production mechanism. This paper outlines some simple graphical techniques used to identify water flowing through a natural fracture system from an underlying aquifer.
Selection of treatment technology, treatment volume, concentration schedule, and quality control issues are discussed. Critical logistics and operational matters are also covered.
An unusual approach to the treatment was taken by stimulating the well with a propellant stimulation treatment prior to the water shut-off treatment. This technique is designed to improve the communication with the natural fractures in the near-wellbore area, and allow the treatment to be pumped at lower pressures with less polymer dehydration problems and more effective treatment placement. It is hoped that the improved placement will extend the life of the treatment.
The job procedure, cost estimate, schedule, and project economics are presented, and compared to the actual job execution.
The treatment had some unexpected pressure behavior during the placement. Ideas are proposed to explain the behavior, and suggestions are made to gather additional data during future treatments to verify the theories and better understand treatment design.
The treatment was performed on October 13, 2000 and three months of production data are used to judge its success. Pre-treatment production rate was 14.1 barrels of oil per day (BOPD) (2.24 m3/d) and 7,817 barrels of water per day (BWPD) (1243 m3/d). Post treatment rates after two weeks were 18 BOPD (2.9 m3/d) and 1,880 BWPD (299 m3/d). After three months, production seems to be stabilizing around 12 BOPD (1.9 m3/d) and 3,150 BWPD (496 m3/d). Problems were experienced with ESP pump sizing following the treatment.
Handling, Treatment and Transportation of Fluids Tailor-Made for Faja Crudes
Authors: Padrón Aaron , Morros Francisco 
Published: December 2007

Abstract
The extensive development of the Orinoco Belt has been supported by the concourse of various worldwide companies with different philosophies. Thus, Exxon-Mobil, Conoco, Phillips, Texaco, Totalfina, Veba Oel, Statoil and PDVSA are participating in the Orinoco Belt development and their participation has been determinant in the operation and design criteria for each of the particular project.
To face the challenge of developing this huge field, with more than 1,2 MMM Bls OOIP, of a crude with extreme characteristics such as 7-9°API gravity and dead crude viscosity between 20,000 and 100,000 cst, as well as the foamy oil and topography effects, it has been necessary to implement the following: Conventional Technologies, such as gas separators, electrostatic dehydration and desalter, heater treater, etc.Advanced Technologies, such as multiphase pumping and measurement.New developments jointly with the suppliers, such as high volume capacity Progressive Cavity Pumps (PCP).
This paper summarizes and compares the different technologies and methodologies utilized by various companies currently involved in the Orinoco Belt such as Petrozuata, Sincor, Ameriven and Cerro Negro, for handling, measuring, treating and transporting crude, water and gas which were tailor-made for the Orinoco Belt crude.
Predicting Permeability From Well Logs in Carbonates With a Link to Geology for Interwell Permeability Mapping
Authors: Jennings James W. , Lucia F. Jerry 
Published: December 2007

Abstract
A fundamental component in the construction of most reservoir performance models is an empirical relationship between permeability as measured in a limited number of cored wells and other petrophysical properties measured in well logs. This paper presents a permeability model specially designed for carbonates. The model relates permeability to interparticle porosity, makes special accommodation for separate-vug porosity, and includes a rock-fabric classification scheme with an important dual petrophysical-geological significance. Methods to estimate the separate-vug porosity from sonic logs and the rock-fabric from initial saturation are presented.
The dual petrophysical-geological significance of the rock-fabric classification is important for providing a link to geological models for use in distributing permeabilities between wells. Porosity and permeability are highly variable and difficult to predict spatially in most carbonate reservoirs, but rock-fabric changes tend to be systematically organized in a predictable manner within a sequence stratigraphic framework.
Evaluation of the Potential of High Angle Wells for the Najmah-Sargelu Reservoirs in Kuwait
Authors: Briggs Peter J. , Gaona Michael T. , Kamal Dawod S. A. 
Published: December 2007

Abstract
The Najmah-Sargelu reservoirs are fractured carbonates and have been penetrated by several vertical wells. Productivity from these wells depends on chance intersection with vertical fracture clusters and as a result has varied from zero to quite productive wells. The chances of intersecting major fracture clusters will be improved if high angle wells are used. This paper investigates and compares the expected performance of vertical and high angle wells based on assumptions about the density of major vertical fracture clusters also, the azimuth, length, width, and rock matrix properties. The analysis tool developed incorporates uncertainty in these parameters using the algorithm below and Monte Carlo Simulation.
Define vertical or HAW well locations. Then, for each Monte Carlo trial:
Select fracture density. 2 Select fraction of fractures in primary and secondary azimuth. Randomly map fractures in reservoir area, sampling length and width distribution for each fracture cluster location. Count intersections of fixed location high angle or vertical wells with fracture clusters. Use cluster intersection statistics to determine the number of multiple fracture clusters connected to each well. Calculate average matrix volume associated with each fracture cluster and compute matrix fracture feed. Calculate OIP and recovery for each well. Sample well costs and perform economics.
The analysis allows the comparison not only of vertical and high angle wells, but also high angle wells with different completion lengths. The method provides a quick and simple method of screening and prioritizing fractured reservoir opportunities for more-detailed analyses.
An Integrated Work-Flow Model to Characterize Unconventional Gas Resources: Part I—Geological Assessment and Petrophysical Evaluation
Authors: Newsham K. E. , Rushing J. A. 
Published: December 2007

Abstract
This paper presents a systematic methodology to describe and characterize unconventional natural gas reservoirs. We have modified the Petrophysical Integration Process Model (PIPM), originally developed at Amoco (Gunter, et al,1,2), for specific applications to unconventional gas systems. Our modified PIPM, which is divided into four discrete analysis stages, integrates data from multiple sources and different reservoir scales. In this paper, we describe each PIPM stage and show how petrophysics can be used as the critical link between geology and reservoir engineering. Although we illustrate the process with examples from a tight gas sand study, the modified PIPM is applicable to other unconventional gas systems. The ultimate goal of this process modeling is to build realistic three-dimensional wellbore and reservoir flow models to predict future performance and optimize field development.