bluuebunny/crossref_metadata_2025_split huggingface dataset:
How to Minimize the Flow Rate Error in a Complex Gas Network
Authors: da Mata J. D. 
Published: December 2007

Abstract
Petrobras owns several natural gas networks, involving production, compression, process, transport and distribution systems of this important energetic source in Brazil. This paper presents the principles of a computational system developed for the gas measuring management and for the accounting balance closure of the entire gas network. The system calculates for each measuring point an uncertainty and a quality value, based on the gas features, the equipment and the variables involved in the flow rate calculation. A mathematical programming model closes the balance, minimizing the weighed sum of the adjustments of the flow rate values, for all the gas network, allowing to locate those meters which present the biggest measurement errors.
Laboratory Evaluation of the Effect of Treating Chemicals on Scale Inhibitor Performance
Authors: Kirk Joseph W. , Sin Romony E. 
Published: December 2007

Abstract
In producing systems several chemicals may be injected into a common line without regard to effect of one inhibitor upon the other. This paper examines the effect of various commonly used treating chemicals upon the efficiency of four commonly used scale inhibitors.

Introduction
The generally accepted practice of chemical treatment in the oilfield is basically "use what ever materials are necessary to get the job done." Unfortunately little if any thought is given to the possible interactions between the different species of treating materials and the result of that interaction.
This paper demonstrates some of the possible results of incompatibility between scale inhibitors and other chemical treating compounds normally employed in water handling systems in the oil field.

Description of the Experiments
Testing was carried out on the tube blocking type apparatus using a 0.02" PEEK tubing one meter in length as the test coil. The coil was immersed in a constant temperature water bath at 150 F. The brines were pumped through the test coil using peristaltic type tubing pumps.
Flow through the test coil was maintained at a constant 5.0 milliliters per brine, for a 10.0 milliliter per minute total flow rate. The pressure increase on the test coil was measured with a pressure transducer and a computer program to assimilate the data and display it in graphical form.
The scale Inhibitor under evaluation was added to the anion brine in all tests. Other chemicals were added to the cation brine.
All evaluations were carried out using the synthetic brine whose composition is shown in Table 1.
Commercial finished compound blends rather than the pure base inhibitor were used in all of the testing.
When working with completely water soluble materials, the required amount of compound to be evaluated was added to the cation brine. As previously noted the scale inhibitor was added to the anion brine.
With the oil soluble materials a slightly different approach was used. An amount of hydrocarbon equal to the amount of brine was mixed with the brine. (Making a 50/50-kerosene/brine mixture). In the testing depolarized kerosene was used as the hydrocarbon.
Kerosene and brine were added to a separatory funnel to which the required amount of scale inhibitor and other test material was also added. The separatory funnel was shaken vigorously by hand for one minute to assure intimate mixing. The fluids were then allowed to stand undisturbed for a period of one hour to allow the layers to separate. Water was then drawn off and used for the actual test procedure. The presence and amount of any emulsion layer was noted and recorded.
This hydrocarbon extraction procedure was used only with the oil soluble materials.
P. 501^
Sand Erosion Control by Using Chokes in Series in Deep, High Pressure Oil Producing Wells in North of Monagas, Venezuela
Authors: Ali J. 
Published: December 2007

Abstract
A design of chokes in series has been carried out in order to minimize sand erosion in choke boxes and beams. A multiphase flow simulation program was developed to determine the size of the choke orifices and the sequence of installation. Previous field experience determined beneficial effect of using chokes coated in their internal area from end to end with tungsten carbide.
Failures in choke boxes and beams have been occurring in about 59 out of the 222 production strings in the North of Monagas area in Venezuela to the present time. In fact, 139 failures due to sand erosion occurred during 1996 causing repair costs of about $339000.
The installation of a design consisting of chokes in series at the well head, drastically minimizes sand erosion, reducing production losses, oil leaks, maintenance costs and unsafe operations.
The multiphase flow simulation program based design resulted in the installation of three chokes in series protecting them from sand erosion in the two wells evaluated. During five (5) months, the pre-established period of time for analysis, well No. 1 kept producing continuously. Visual inspection confirmed that no sand erosion had occurred in any of the chokes.

Introduction
High gas and oil rates associated to sand production with high well head pressures passing through one choke box with conventional material usually causes erosion of the beam and its choke box; the severity of the erosion process may deteriorate them completely, giving place to leaks. Sand production erodes the internal parts of a well head including wing valves, tees, subsurface safety valves, choke boxes and beams affecting the well safety system and production operations. These accessories are inspected periodically, and frequently, they have to be repaired or replaced. This type of failure causes deferred production and dedication of production crews to correct erosion problems affecting operational costs.
Research has been carried out on the erosive processes in materials with and without the presence of sand. In the oil industry, an API formula has been developed to predict the limit velocity for flow of fluids, above which an erosive process, in non corrosive environments and without the presence of solid particles, can be initiated. Deffenbaugh showed results on the erosion velocity for carbon steels excluding its application for flow restrictions as chokes. Likewise, Deffenbaugh proposed a formula to predict erosion velocity in the presence of sand. Sontvedt reported the limit velocities for erosion for carbon steels in the absence of corrosive fluids based upon studies of materials for chokes, and also for other special materials resistant to erosion. P. 987^
The impact of reservoir characterization on oil exploitation from the Namorado Sandstone, Albacora Field, Campos Basin, Offshore Brazil
Authors: Barroso A. S. , Bruhn C. H. L. , Lopes M. R. F. , Beer R. , Sombra C. L. , Romeu R. K. , Mihaguti M. , Neto G. S. 
Published: December 2007

Abstract
PRAVAP 2 (Petrobras’ strategic project for reservoir characterization) aims mainly technology acquisition and development in reservoir characterization. The project is based on a multidisciplinary approach, and the synergism between operational and research teams. New technologies are put together with others already consolidated. This paper presents some of the developments acquired and how they impact the field development and oil production.
Gas Zones Detection Using the Dual-Spaced Neutron Tool Responses
Authors: Quintero Luis F. , Bassiouni Zaki 
Published: December 2007

Abstract
Gas zones are routinely identified with the neutron-density crossover. Many a times however, this crossover is not present or misleading because the lithology used in the tool's calibration is not representative of the formation of interest. Also the crossover could be completely obliterated by the shale effect. Furthermore, in cases where the well has been cased before logging only the neutron tool can be run.
We have developed a simple algorithm that determines three apparent neutron porosities. The porosities derived from the raw counts of the dual-spaced neutron tool have three different radii of investigation. All three neutron porosities read the true porosity in water-bearing zones. In gas-bearing zones the mud filtrate invasion profile will cause the three apparent neutron porosities to be different. The resulting neutron porosities crossover can be used in a way similar to the neutron-density response in detecting the presence of gas.
The validity of the algorithm has been tested using a numerical model and field examples.

Introduction
The detection of gas zones using the density-neutron crossover relies on the assumption that the lithology selected to calibrate the tool is representative of the lithology of the formation of interest. The absence of this condition leads to a complex interpretation problem as the neutron-density combination must be used to both determine the lithology and to detect the presence of gas.
The shaliness of the formation can also obliterate the neutron-density crossover, since shale and gas have the opposite effect on these logging tools. The presence of gas may be overlooked in cases where the shale effect offsets the gas effect.
In highly rugose boreholes, the reading of the density tool is much more affected than that of the compensated neutron. In these conditions, the crossover pattern may be misleading. Also, being a padded device, the density tool cannot be run through casing. In these scenarios the only porosity indicator is the dual-spaced neutron sonde.
A New Improved Method for the Design and Field Implementation of Air-Mist Drilling
Authors: Wilkes T. M. , Watson R. W. , Graham R. L. 
Published: December 2007

Abstract
Misconceptions with respect to the use of mist drilling have existed within the drilling industry since the 1950's. For example, industry has accepted the fact that a significant increase in the volumetric air flow rate was required when mist drilling. Calculations using Angel's1 approximation for conventional dry-air drilling, in fact indicated that approximately 35 to 40 % more air was necessary. This misconception2 has continued to this day and is contained in recently published drilling articles and reports. The primary objective of this paper is to correct this misconception and to demonstrate how a correct design can be accomplished at the field level.
Moreover, the paper also discusses the use of foam for the handling of the influx of liquids during air drilling. A new relationship between the fraction of soap to the fraction of liquid (including influx) is presented. The results of model-derived computations for predicting cuttings transport in a mist system are included for the purpose of demonstrating the concept. Field case study calculations using the model are documented. Comparisons between these new, improved calculations and incorrect calculations based on conventional air drilling techniques are included and discussed in terms such as cuttings size transport. Practical recommendations with respect to field operations are included.
The implementation of the recommendations and new methods in this paper will result in improvements in the design of air-mist drilling, increased use of air drilling, the implementation of mist drilling with percussion hammers, better understanding of cuttings transport in mist systems, and more efficient use of soap in the mist drilling.
Field Curves for Critical Buckling Loads in Curving Wellbores
Authors: Hill T.H. , Chandler R.B. 
Published: December 2007

Abstract
This paper gives a plotting technique and curves for estimating the axial compressive loads for the onset of sinusoidal buckling in curving wellbores. The analysis and data calculation are based entirely on previous work by others. Only the method of presenting the data is new. Curves are given for several common drill pipes.
P. 259
A New Generation of Dynamically Positioned Drillship for 10,000 Ft. Water Depth
Authors: Duhen Thomas , de Bonnafos Olivier , Rietveldt Bob 
Published: December 2007

Abstract
Following the first involvement of Foramer with Dynamically Positioned Drillships in 1966, IHC Gusto Engineering developed the "Pelican" design in 1972, with the assistance of Foramer for the drilling package.
The "Pelican" design became the most widely design used for DP Drillships, with 10 units built.
For the new challenge of ultra deep water depths up to 10,000 Ft., IHC Gusto design expertise and Foramer 30 years experience in operating up to four of the "Pelican" design DP drillships, joined forces to develop a new generation DP drillship.
A description of the design and the motion characteristics of the vessel, as well as operational considerations are included.
P. 409
Trends Extracted From 800 Gulf Coast Blowouts During 1960-1996
Authors: Skalle Pal , Podio Augusto L. 
Published: December 2007

Abstract
The cost of blowouts and the loss of lives incurred from blowouts warrant the study of past occurrences in order to reduce the possibilities of future blowouts.
Even though we continuously learn more about how to handle an unstable well, it seems that the problems of detection, handling kicks and loosing control do not change much with time in the real world - out on the rig. The small changes and improvements that do occur are first of all seen thorough statistical data. A new data base resently compiled will soon contain extensive data on more than 800 blowouts from the Gulf Coast area and adjoining states during the period 1960 through 1996. At the moment the compiling work has not been completed. However, at the 1998 IADC/SPE Drilling Conference an updated version of this paper will be available. Five agencies contributed blowout report information. The State Oil and Gas Boards/Conservation Office of Alabama, Mississippi and Louisiana, The Railroad Commission of Texas and the Mineral Management Service (MMS) of the Dept. of Interior.
At the moment the Texas blowouts make up approximately 50% of the blowouts in the data base but range below the average blowout frequency of 0.15 blowouts pr. 100 well-ft. drilled. The three major operations in progress when blowouts occurred were exploratory drilling, workover and development drilling. Most frequently blowouts occurred during the activity of actual drilling, tripping out and circulating/killing. The analysis indicated also that the major causes were related to swabbing, drilling into a high pressure zone or formation break down while the secondary barrier after a kick has occurred which most often failed were either failure to close BOP, failure to stab string valve or BOP failed after closure.
P. 539
Biodegradable Surfactants for Cosmetics Find Application in Drilling Fluids
Authors: Nicora Luigi F. , McGregor William M. 
Published: December 2007

Abstract
Alkylpolyglucosides (APG) are highly biodegradable surfactants which have not previously been used in drilling fluids and yet are commonly used in many other fields such as cosmetics. APG are shown in laboratory tests to act synergically with the polymers commonly used in drilling fluids. The addition of APG, even at very low concentrations, to a polymer mud can drastically reduce the fluid loss even at high temperatures. Moreover both fluid rheology and temperature resistance are improved.
P. 723
Eliminating the Stabber When Running Casing and Tubing: The Next Step in the Rig Mechanization Process
Authors: Hollingsworth Jim L. , Lorenz Joerg 
Published: December 2007

Abstract
While running a string of casing or tubing one of the crew works thirty to forty feet above the rig floor secured to the rig by a safety cable. He is known as the stabber and his is arguably the most physically demanding and potentially dangerous job on a casing crew. Due to the inherent danger of the stabber's job along with the industry's ongoing pursuit of accident reduction, a system was developed to eliminate the need for the stabber without requiring major rig modifications or new construction. This system incorporates all of the stabber's functions using a combination of both new equipment and existing tools that have been modified. A mechanized stabbing device, air-operated elevator and spider with an integrated safety interlock system, a flagging device and a redesigned single-joint elevator compose the system. The mechanized stabbing device and elevator and spider with safety interlock system have been used with great success in the running of casing and tubing in the Gulf of Mexico and North Sea. Trials on a test rig have been completed on the single-joint elevator and flagging device and both are awaiting field trials as of the submission date. With the introduction of this system, safety and reliability during pipe running operations will be greatly enhanced and from this will follow the economic benefits.
P. 779
Anaerobic Biodegradability of Oil Base Fluid For Invert Emulsion Drilling Fluid.
Authors: Blanchet D. , Audibert A. , Argillier J-F. 
Published: December 2007

Abstract
Environmental legislations restrict the use of oil based muds, specially in North Sea and their discharge under the form of oily cuttings. Different synthetic based muds (SBM) are proposed for replacing gas oil as the base fluid. These are low toxicity mineral oils, poly or mono olefins, acetals, esters… Controversial data exist concerning their biodegradability under aerobic or anaerobic conditions. Both conditions are representative of offshore drilling activities since the oil present in the cuttings deposited on the seabed can be degraded 6n the surface through oxygen process and in the center of the pile through anaerobic process. For examination of the easy and ultimate anaerobic biodegradability, the ECETOC screening test is generally employed. This procedure was here improved to evaluate the variability due to the digester sludge. The disappearance of the initial substrate is evaluated by gas chromatography analysis that gives information on the alteration of the base oil chemical structure. The potential for anaerobic biodegradability of an oleic acid ester is compared to an a olefin (C12-C14) and fructose used as a reference substrate. An important biodegradation of the oleic acid ester is observed i.e. more than 80 % of ultimate biodegradation to CO2 and CH4 and total primary biodegradability with no accumulation of the corresponding fatty acids. This attests the easy anaerobic biodegradability of the oleic acid ester In the same conditions, the test performed with the a olefin presents a low pressure evolution and low CH4 production confirming the poor anaerobic biodegradability of this type of compounds.
P. 799
Flow Behavior of Foam as a Well Circulating Fluid
Authors: Beyer A.H. , Millhone R.S. , Foote R.W. 
Published: December 2007

This paper was prepared for presentation at the 47th Annual Fall Meeting of the Society of Petroleum Engineers held in San Antonio, Tex., Oct. 8–11, 1972. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by who the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Equations for steady-state flow of aqueous foam in circular pipes were formulated from laboratory and pilot-scale experimental data. pilot-scale experimental data. These equations were incorporated into a mathematical model of foam circulation in oil wells. The model was tested in two oil wells, and predictions were satisfactory for predictions were satisfactory for engineering calculations. Accuracy of the model may be increased further by accounting for liquid holdup during foam circulation in large-diameter wells.

Introduction
Aqueous foams have proven effective and economic as circulating fluids in well cleanout and drilling operations, and are becoming increasingly important for a wide range of oil field work. Information on the flow behavior of foam in oil wells is important for designing and conducting these foam operations.
Previous work on foam rheology by David and Marsden pertained to capillary tubes only, and validity of results in oil field-size systems is not known. Mitchell measured flow characteristics of foam in tubes up to 0.1 inch in diameter. Results were used by Krug and Mitchell to develop a calculation method for circulation of foam in oil wells, but no field-scale experiments were reported to demonstrate accuracy of their predictions Work published by Wenzel et al. was for larger pipe sizes, but the foam was drier pipe sizes, but the foam was drier than that normally used in oil field applications.
The foam flow equations presented herein have been tested in field-scale systems. These equations should improve the industry's ability to design and conduct oil field foam operations.
Application Of Integrated Reservoir Simulation And Pipeline Network Modeling Software To The Sexsmith Gas-Condensate Field
Authors: Mogensen A.C. , Caswell G.R. , Trick M.D. 
Published: December 2007

Abstract
Over-simplification of the hydraulic component of the field production gathering network can often introduce serious errors in the reservoir simulation forecast. One principal problem involves determining the number of wells required to achieve a desired production target rate. Neither the engineer nor the automated drilling queue logic in the reservoir simulator can easily determine the effects of increased surface backpressure on existing wells caused by the connection of new wells to the surface gathering network.
The integrated simulation of the reservoirs and pipeline gathering network connecting wells to the 200 MMscfd (5635 E03 m3/d) Sexsmith, Alberta sour gas processing plant demonstrates an approach taken to provide answers to problems typical of gas production operations. The paper reviews alternate approaches pursued prior to committing to the integration of a reservoir simulator and a pipeline network model. A review of the history matching procedures conducted to "tune" the linked models to match historical production rates and pressure losses in the network are presented. Information which is "passed" between models is presented as well as suggested software improvements to the integration of the reservoir and pipeline network models.
P. 291