bluuebunny/crossref_metadata_2025_split huggingface dataset:
Training for the Future: Are Your Potential Liabilities Covered?
Authors: Roberts R. 
Published: December 2007

Abstract
Corporate liabilities in conjunction with training can be concerning for many Oil and Gas companies across the world. The regulatory aspect of training is very cumbersome and unique to the oil industry due to the complexity of work environments, time restraints and reduction in production hours. Numerous consultants, engineers and various workers throughout the Oil Field sites are performing safety meetings, yet are lacking in appropriate hours spent on environmental and safety compliance. Most companies have trained employees in some aspect although, regulatory compliance is not achieved due to the numerous O.S.H.A. standards and training competency mandated levels. The resolve to some of the concerns involve alternative learning styles such as computer based training, hands-on training and hired consultants to provide training.
Underground Gas Storage in Porous Media - Operating Experience with Bacteria on Gas Quality
Authors: Kleinitz W. , Böhling E. 
Published: December 2007

Abstract
The purpose of underground gas storage in porous media is to allow compensation for peak shaving in gas consumption. Especially during the winter months, the stored gas must then be supplied at full capacity for short periods. However, it must be ensured that the characteristic properties of the gas, such as the calorific value, the Wobbe index, etc., are not qualitatively impaired during the storage period. These values also include the concentration of H2S, which must remain below a specified limit of 5 mg/m³ (Vn).
During many years of operation with gas storage facilities, however, practical experience has shown that substantial technical efforts are necessary for observing this limiting value. Among the various possible causes, H2S can be generated as a result of dissimilatory sulphate reduction.
The activities of isolated SRB strains are discussed with respect to substrate utilisation (hydrate inhibitors), life conditions (temperature, pH value) and stimulation of storage wells.
Development of Low-Permeability Carbonate Reservoir by Use of Horizontal Wells in Mature South Umm Gudair Field in the Neutral Zone–A New Approach
Authors: Jha M. , Tran T. , Hagtvedt B. , Al-Haimer M. , Al-Harbi M. 
Published: December 2007

Abstract
The South Umm Gudair (SUG) oil field located in the Neutral zone between Kuwait and Saudi Arabia has produced since 1968 from an active water drive carbonate reservoir of Lower Cretaceous age. The lower zones are homogenous intervals of higher permeability which appear to be sufficiently swept by natural water drive over a period of time. The upper zones of the reservoir are more heterogeneous and have lower permeability in the range of 50-150 millidarcies. These upper zones are relatively thin and are bound by tighter intervals that act as effective barriers to the natural water drive system. Due to the presence of barriers and low permeability intervals, these zones have been poorly swept resulting in significant volumes of by-passed oil remaining in these parts of the reservoir.
The new approach of exploiting these reserves by drilling and completing 4 horizontal and 2 horizontal side track (HST) wells targeting the lower permeability portions of the reservoir in the SUG field since January 2004; have yielded considerable success in extracting significant incremental oil production with the added benefit of very low water cut. This success has led to field development plan to recover un-swept oil reserves from these low permeability zones. This paper summarizes the various aspects of field development plan taking into consideration geology, reservoir data and production data while highlighting the successes of the new horizontal and HST wells in the low permeability reservoir portions of the SUG field.
Detailed in Situ Stress Measurements for Qualifying the Safety of Underground Gas Storage Overburden
Authors: Fourmaintraux D. M. , Bois A. -P. , Le Goff C. , Cantini S. 
Published: December 2007

Abstract
Operations performed on one underground natural gas storage facility detected gas traces in its overburden. This led the safety management to request that the sealing of the overburden of this storage facility as well as of a sister facility be checked and re-qualified.
Gas is injected in the top of two gentle tertiary anticlines within a regional aquiferous sandy layer overlaid by a thick molassic shaly overburden. The main risk for leakage is the risk of "hydro-fracturing the cap rock", which is controlled by the value of the minimum horizontal in situ stress.
This paper focuses on data acquisition of 37 mini-frac tests and 3 ELOTs. These tests allowed drawing a representative profile of the minimum horizontal stress between 150 m to 525 m deep, and also to evaluate its direction.
These data were used as input to numerical simulations that showed that gas injection and withdrawal result in in-phase displacing the overburden up and down and that no damage mechanical damage occurs.
Hydraulic Jet Pumps Prove Ideally Suited for Remote Canadian Oil Field
Authors: Anderson J. , Freeman R. , Pugh T. 
Published: December 2007

Abstract
With 150 Million Barrels of recoverable reserves, the Nexen Hay River Bluesky oil pool is among the largest oil discoveries in Western Canada in the past two decades. Initial pilot production testing lead to the conclusions that, in order to produce the field in its most economical fashion, the following would be needed: Triple lateral horizontal producing wellsIn field horizontal water injection/water disposal wells for pressure maintenanceArtificial Lift from the outset
Further complicating production of the Hay Pool, which is located in a remote area of North-Eastern British Columbia, was the fact that road access would be limited to 4 months of the year because any road through the muskeg would need to be "frozen in" prior to use. It was therefore extremely important to the economic viability of the project that whatever means of artificial lift were chosen should be highly reliable and require minimal maintenance. The method chosen, apart from being reliable and safe, would also need to be capable of lifting large volumes of fluid with a significant pressure drawdown. In addition it would need to be able to operate successfully in the extreme well deviations common in the "build" sections of the development wells.
This paper will review the development of the Bluesky oil pool and present the case for the choice of Jet Pumps for artificial lift. The authors will go on to detail the performance of the Jet Pump system installed in the field that has met or exceeded all performance expectations.
Technical Improvements in Mill Profile Design and Cutting Structures: Case Histories and Developments
Authors: Voden G. S. , Pfannenstiel G. , Matthews R. 
Published: December 2007

Abstract
The ever increasing operator demands and objectives to mill fast and efficient windows has led to the development of innovative milling technology. New lead mill profiles and cutting structures have replaced old crushed carbide technology.The new design utilizes inserts brazed into pockets machined in the mill head. Mills dressed with the new cutting structure are able to effectively mill a casing window and drill formation rat hole in less time than it took with the welded-on crushed carbide technology.
With this new design, operators are now afforded an option. In medium to hard formations, the new cutting structure can be used to mill the window and drill rat hole in one trip. While sidetracking in formations with high compressive strengths, Polycrystalline Diamond Compact (PDC) inserts can be utilized. The use of the new cutting structure in a one trip sidetrack system can result in substantial cost savings, improved milling reliability and a higher quality window.
The combination of new cutting elements and mill profile has proved to be economically sound allowing for consistency of product manufacturing and has eliminated the potential variances inherent in the welding processes. The system design and cutting structure reduces torsional resistance providing for smoother in-gauged milled windows in one trip.
This paper updates an earlier paper with the concepts of using the new cutting structure and presents the new technology and recent case histories of four sidetrack operations.
Determination of Multilayer Reservoir Inflow Profiles Using Pulsed Neutron Logs
Authors: Poe B. D. , Butsch R. J. , England K. W. 
Published: December 2007

Abstract
This paper addresses the development and validation of a production logging analysis methodology and associated formation inflow interpretation model for wells that have their production tubing string setting depth below the top of at least the shallowest completed interval in the well.This type of completion technique is commonly utilized in wells that produce formation liquids and in which the tubing is lowered in the well below the top of the shallowest(and possibly additional deeper) completed interval(s) in order to assist in unloading the well of the produced liquids.When this is done, conventional production logging tools and techniques can not be used to measure the inflow profile of the completed intervals that are shallower than the tubing setting depth in the well without raising the tubing above the shallowest completed interval, which can alter the inflow profile of the well.
This paper specifically considers the development of a reliable means of performing an equivalent inflow performance analysis, analogous to that which would be obtained with conventional production logging analyses if those inflow profile evaluation techniques could be used in wells with this type of completion.The liquid holdup of the multiphase flow in the well is determined from the Inelastic Ratio measurements of a Pulsed Neutron log and the annular water velocity is directly obtained from the analysis of water flow measurements in the annulus of the well.
Preventing Asphaltene Deposition in Oil Reservoirs by Early Water Injection
Authors: Wang S. , Civan F. 
Published: December 2007

Abstract
A comprehensive modeling and simulation of asphaltene precipitation and deposition in petroleum reservoirs is carried out. The effects of the asphaltene deposition on reservoir properties, and the productivity of the vertical and horizontal wells during primary oil recovery are demonstrated. An early water-injection development scheme for suppressing asphaltene deposition is proposed and its feasibility is investigated by means of simulation. The performance of the early water-injection development scheme is compared with the direct depletion development scheme. The results indicate that the early water-injection not only increases the oil recovery significantly but also extends the economic production life of the reservoir considerably.
A Review of Downhole Separation Technology
Authors: Ogunsina O. O. , Wiggins M. L. 
Published: December 2007

Abstract
In recent years, a technique of separating water downhole to reduce the volume of produced water and decrease the chance of surface pollution has been developed. It is called downhole oil-water separation (DOWS) technology. This technique allows water to be separated in the wellbore and injected into a suitable injection zone downhole while oil with traces of water is produced to the surface.
Subsequent to the introduction of the DOWS technology to the oil industry in the 1990's, several trial applications have been undertaken to test the technology. These trials allowed significant information to be collected on the feasibility of the DOWS technology. Through the joint efforts of Argonne National Laboratory, CH2M-Hill, and the Nebraska Oil and Gas Conservation Commission, a comprehensive technical report was issued in January 1999 discussing this technology. Additional reports on trial applications and feasibility studies have been presented by various study groups.
This paper reviews the status of and issues surrounding the application of downhole separation technology. This review summarizes the various papers and reports dealing with DOWS technology and its application in the oil and gas industry. This technology has the potential to provide significant reductions in produced water as the technology is adopted by the industry. It can also reduce produced water handling costs and increase oil and gas production in the right application. The wide-spread adoption of DOWS technology is dependent on improving the understanding of the process and its applications throughout the oil and gas industry.
Friction Pressure Correlations for Newtonian and Non-Newtonian Fluids in Concentric Annuli
Authors: Singhal N. , Shah S. N. , Jain S. 
Published: December 2007

Abstract
Flow through annulus is frequent in drilling and work-over operations. Annular flow is also utilized in some fracturing treatments. In all these applications, Newtonian and non-Newtonian fluids are widely used. Therefore the knowledge of annular flow performance of these fluids becomes important for planning and design of well-bore hydraulics. Existing knowledge about the behavior of non-Newtonian fluids in annulus is very limited due to their complex behaviour. A range of correlations is available in the literature for both Newtonian and non-Newtonian fluids in laminar and turbulent flow regime. Selection of the appropriate correlation for the desired fluid and flow regime is very important for the accurate determination of friction losses.
Experimental and simulation study has been undertaken to investigate the flow behavior and friction pressure losses of Newtonian and non-Newtonian fluids in concentric annuli. Computational Fluid Dynamics (CFD) has been used along with limited experimentation on a field-scale set up to validate the simulation results. The fluids investigated are water and frequently used concentrations of guar and Xanthan fluids. CFD simulations have been performed for different annular dimensions in flow range encompassing both the laminar and turbulent flow regimes. The annular dimensions used in the simulations cover the range used in the industry. The frictional losses of non-Newtonian fluids exhibiting drag-reducing characteristics have been investigated through experiments.
Based on the comparison with simulation results recommendations are made to use the appropriate correlations for Newtonian and non-Newtonian fluids in the laminar and turbulent flow regime.Improved correlations are proposed to determine frictional losses of non-Newtonian fluids exhibiting drag-reducing characteristics. These correlations are based on experimental data gathered for a wide range of concentrations of guar and Xanthan fluids. The recommendations made along with the correlations presented in this study will greatly improve the accuracy of determining friction pressure losses in concentric annuli.
Locating Remaining Oil in a Mature Waterflood: A Case History
Authors: Calogero D. B. , Stevens G. A. , Hall R. 
Published: December 2007

Abstract
The Walnut Bend Field was discovered in 1938 and consists of over 70 Pennsylvanian channel sands draped over an elongated, anticlineal structure approximately 3 miles long and 1.5 miles wide. The main body of the field had produced over 99 MMBO by 1999 when a field revitilization project was initiated. This project was a success, both technically and commercially. The success of this program was due in large part on a new volumetric-balancing technology that provided accurate present day oil in place maps. Some of the highlights of this project are: 80% accurate prediciaon rate of current day hydrocarbons1,080,000 bbls of reserves added35% increase in productionComprehensive multi-year revitalization plan.
Using Chemical Tracers and Production Analysis for Early-Time Assessment of Stimulation Effectiveness and Reservoir Quality for Barnett Shale Completions
Authors: Townsend A. , Anderson K. , Gunderson D. 
Published: December 2007

Abstract
For every well drilled, there is a performance expectation.At a minimum, there is a forecasted Pi, initial production rate, and time to payout. When the well's production does not meet expectations, it is common to wonder whether the problem is the reservoir, the completion, or the wellbore.Answering these questions quickly, accurately, and inexpensively is difficult enough with single-zone completions; however, it has been virtually impossible for wells with commingled production.Historically, even simple wells defied rigorous investigation without costly and time-consuming pressure buildup analysis.To determine the critical characteristics that dictate a well's performance, a non-intrusive method is necessary.When employed with robust, post frac, drawdown production analysis, the Chemical tracer technology unlocks the keys to understanding important reservoir parameters in single and multiple zone completions.
Several Barnett Shale well case histories will be presented to demonstrate the application of this methodology.These case histories illustrate the value of being able to allocate production to individual zones in Barnett Shale wells with commingled production.
Environmental Impact of Oil and Gas Operation: A Case Study of Drilling-Mud Disposal in Niger Delta, Nigeria
Authors: Ndufor P. N. , Idehen K. I. 
Published: December 2007

Abstract
The paper report is the technical assessment on the environmental impact of burried drilling chemicals, which were later exhumed, the study parameters includes the physical, chemical, biological and socio-economic status of the dump site of chemical waste, recommendation cum mitigative measures was proferred.
Contact Pressure Threshold: An Important New Aspect of Casing Wear
Authors: Hall Russell W. , Malloy Kenneth P. 
Published: December 2007

Abstract
Drilled wellbores have evolved from nearly vertical, shallow holes to tortuous, deep, directionally drilled wells. As wellbore geometries have increased in complexity, so has the potential of damage resulting from casing wear. It is not unusual to routinely install ditch magnets in the returned drilling fluid circuit to catch the iron filings created by tool joint wear against the casing or riser interior wall.
While most "straight" holes attempt to control inclination, azimuth control is often times neglected, potentially creating a tortuous path. In directionally drilled holes, including horizontal and multi-lateral wells, the drill string tension holds the rotating tool joints against the inner wall of the casing for extended periods. This results in the generation of crescent shaped wear grooves (key seating) in the inner wall of the casing, often dangerously weakening casing or riser strings making them more susceptible to burst or collapse.
Some investigators have sought to quantify this damage process. Computer models describe, measure, and predict damage from casing or riser wear. From these on-going studies, advances in technology continue to minimize casing and riser wear.
A Two-Phase IPR for Horizontal Oil Wells
Authors: Wiggins M. L. , Wang H.-S. 
Published: December 2007

Abstract
This paper investigates the rate-pressure behavior of a horizontal oil well with a fully penetrating wellbore producing during the boundary dominated flow regime. Based on linear regression analysis of simulator results, two empirical inflow performance relationships (IPRs) are developed to estimate well performance. A future performance relationship is also developed to allow estimates of future rate-pressure behavior from current test information. The IPR relationships are compared to other horizontal IPRs available in the literature and yield reasonable estimates of well behavior over a wide range of operating conditions.
Improved Treatment Methodologies for Removing Low Concentrations of H2S in South Texas Natural Gas Systems
Authors: Lillard D. M. , Macias J. M. 
Published: December 2007

Abstract
Removal of hydrogen sulfide from natural gas is a primary concern for many producers. Many natural gas systems throughout the South Texas area have H2S concentrations that range from less than 10 ppm to more than 1000 ppm. While amine units are usually efficient at removing H2S cost-effectively, the high capital cost has encouraged the development of other treatment methodologies for the removal of low to moderate quantities of H2S from natural gas. One such method is the injection of liquid chemical scavengers directly into the gas stream. The chemical scavenger reacts with the H2S and forms a product that is removed from the gas by separation equipment, such as a scrubber.
Although the chemistries of the scavenger reactions are fairly well known, the efficiency and therefore the cost-effectiveness of removing H2S by this method is highly dependent on system conditions and architecture. Many parameters impact the efficiency of liquid H2S scavenger application. Important factors include mixing, a function of several parameters such as gas velocity and injection method, and retention time, which is the time available at a specific set of conditions to achieve maximum scavenger efficiency. Based on these and other factors, a field study was undertaken to evaluate the effects of system conditions, architecture modifications, and of specialized equipment types on improving the efficiency of H2S removal. This paper will present field data and describe the mass balance efficiencies of several types of scavenger applications including injection into existing systems, the use of retention treating loops, and bubble towers for the removal of H2S.
The use of mass balance calculations during the project allowed for careful assessment of scavenger efficiencies in a variety of conditions and treatment scenarios. Mass balance is a useful tool when liquid scavenger testing includes several formulations of varying concentrations. The results of the field evaluation provided data that led to a better understanding of liquid scavenger usage and applications limits. The improved understanding of treatment envelopes allows field users to more efficiently identify candidate scavenger processes and make more informed decisions on process selection for removal of H2S from natural gas streams.