bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Offshore Heavy Oil Development Challenges in Brazil
Authors: Trindade W. L. , Branco C. C. M. 
Published: December 2007

Abstract
The largest accumulations of heavy oil and bitumen under development in the world are located in Venezuela and Canada1. So far, Canada and Venezuela have developed technologies that make it technically and economically feasible to develop these accumulations. The successful thermal methods as steam injection, combustion in-situ and its variations applied in the onshore heavy oil projects have severe limitations to be applied in offshore deep waters. The technological and logistic aspects of the offshore environment make these methods unsuitable if considering the current technologies.
Nowadays, cold production is the only method that could be applied for offshore fields located in deep waters. Even if this technology is applied, it should have some limitations. Unlike the cold production in operation today in Venezuela and Canada, where sand is produced with oil, offshore sand production would be prohibitive due to the high costs of processing or transporting the sand to shore.
The crude production in Brazil is increasing and more and more heavy oil has been produced. In addition, large resources of heavy oil have been discovered during the last 6 years and are under evaluation. In this scenario, the development of technologies that improve the economics of such discoveries is critical for the country to reach and maintain the so aspired self-sufficiency in petroleum.
This paper will summarize the planned path to overcome the challenges related to the exploration, development, production and marketing of the offshore heavy oil in Brazil.
Real-Time Azimuthal Laterolog Image Interpretation for Successful Horizontal Drilling in a Carbonate Reservoir in the U.A.E.
Authors: Ribeiro M. T. , Hendrawan I. , Karrani S. , Griffiths R. , Greiss R. -M. , Chakravorty S. , Bazara M. , Sirum B. 
Published: December 2007

Abstract
Achieving the objectives of drilling horizontal wells is greatly dependent on accurate placement of the drainhole in the reservoir. Careful pre-job planning using offset well data and seismic maps helps to reduce the uncertainty to some extent. However, the unpredictability of structural and stratigraphic variation between the planned and offset wells and uncertainty inherent in seismic data are always associated with horizontal well planning. The formation dips computed from seismic and offset wells are therefore prone to some degree of error.
Advances in real-time data transmission technology have made it possible to transmit image data uphole while drilling, through improving the robustness of the real-time signal, signal bandwidth and data compression. Logging-while-drilling (LWD) real-time azimuthal resistivity images can be used for accurate estimation of the dip and strike of formations intersected along the well trajectory. In addition, structural surprises such as faults can be detected, and remedial actions taken immediately. Such information is of great value in making geosteering decisions while drilling into reservoirs within structurally complex geology or in an area with sparse geological information. Using image data, trajectory adjustments can be made during drilling yielding optimal well placement.
We descibe the use of real-time image interpretation during the drilling of two horizontal wells within a block bounded by major faults on the north and south, with a series of smaller associated faults, anticipated but not confirmed prior to drilling from existing data, in a carbonate field in United Arab Emirates. The image data provided crucial input to guide the well trajectory through the target reservoirs resulting in the wells objectives being achieved. In addition, the image data clarified the regional geology of the area around the wells, thus helping to update the geological model for better description of the structurally complex reservoir.
New 4 3/4" Rotary Steerable System is Combined With a Performance Drilling Motor to Reduce Risks Associated While Rotary Drilling With Small-Diameter Pipe
Authors: Kellas R. , Ruszka J. , Gruenhagen H. 
Published: December 2007

Abstract
Building on the application's success in larger diameter holes, rotary steerable drilling is becoming an established drilling method in 6" hole sections. Rotary drilling in these smaller hole sizes does, however, bring with it some concerns. These include the requirement for high surface rotary speeds to achieve acceptable penetration rates. As a result, these rotary systems may need to place very high dynamic loads on small diameter drillpipe. A new rotary steerable system has been developed which integrates a high performance drilling motor into the bottom hole assembly. By driving the drill bit with the downhole motor, drillpipe rotary speeds and weight on bit can be reduced while simultaneously increasing rate of penetration. This reduces the stress on the drill string and increases drilling performance. This paper describes this new system illustrated with results from real wells.
Quantifying Remaining Oil by Use of Slimhole Resistivity Measurement in Mixed Salinity Environments - A Pilot Field Test
Authors: Al-Sunbul A. H. , Ma S. M. , Al-Hajari A. A. , Srivastava A. , Ramamoorthy R. 
Published: December 2007

Abstract
Quantifying remaining oil in waterflooded reservoirs is critical for successful reservoir management. For wells with narrow producing tubings, the slimhole induction tool is used because of its deep depth of investigation (DOI). Mixed formation water salinity is characterized using bottomhole samples. Ideally, running an induction tool requires non- or low-conductive borehole fluid uniformly distributed in the borehole. This may not always be achievable under production conditions. In this study, the following were investigated: The slimhole induction tool was first tested in a newly drilled well and its measured data were compared with that of the standard induction log.The tool was run in a borehole under both flowing and shut-in conditions. In this case, the effect of borehole fluid distribution was evaluated.The multiple DOI capabilities of the slimhole tool were used to study the phenomenon of borehole fluid reinvasion during both flowing and shut-in conditions.
From this study, the following were concluded: Slimhole induction measurement agrees well with standard induction measurement.Mixed formation water salinity can be characterized using bottomhole samples and production logs.The following borehole characteristics affect shallow DOI measurements, but not deep DOI measurements: Borehole rugosity.Borehole fluid contact and conductivity.Borehole fluid re-invasion.
Guidelines for running slimhole induction log and collecting bottomhole samples for quantifying remaining oil in mixed salinity environments are summarized based on experiences learnt from this pilot field test of more than 30 wells.
Circulating Usage of Partially-Produced Fluid as Power Fluid for Jet Pump in Deep-Heavy-Oil Production
Authors: Chen S. , Li H. , Zhang Q. , He J. , Yang D. 
Published: December 2007

Abstract
Jet pumping driven by light oil is one of the preferred lift methods for producing heavy oil in a deep heavy oil reservoir. Generally, the amount of light oil is too large to be accepted. One solution of reducing the amount of light oil is that partial produced fluid can be combined with the light oil at any reasonable ratio and then the produced fluid-light oil mixture is reinjected into the well as the power fluid. In this case, viscosity of the mixture keeps increasing and eventually reaches its equilibrium value, which is found to be a function of the reservoir oil viscosity, the light oil viscosity (VLO), the ratio of light oil (RLO) in the mixture (volumetric percentage) and the ratio of the well rate to the diluent rate (M ratio). Thus the optimal ratio of light oil in the mixture can be determined by using an iterative algorithm. All of the above-mentioned parameters result in a change of the viscosity of the produced fluid-light oil mixture and the pressure loss in the production string, especially the VLO and the RLO. A field application example shows that the amount of the light oil used can be reduced by more than 50%.
An Innovative Application to Reduce Petrophysical Uncertainty in Reservoir Monitoring: Case Studies from Giant Saudi Arabian Fields
Authors: Eyvazzadeh R. Y. , Kelder O. , Phillips C. , Hajari A. A. 
Published: December 2007

AbstractReservoir monitoring requires an accurate assessment of hydrocarbon saturation. As oil fields mature, reducing uncertainty in this parameter can yield major economic benefits in field development and reservoir management.Recent advancements in resistivity tool design and enhancements in pulsed neutron and NMR tools have expanded the scope of petrophysics in reservoir monitoring projects. Optimal utilization of these technologies requires an understanding of the uncertainties that are associated with these measurements in different types of environments.A new application has been developed that uses numerical analysis to compute the range of uncertainties inherent in petrophysical analysis. These uncertainties are then used as guidelines to optimize data acquisition.This methodology defines petrophysical uncertainties on a foot-by-foot basis; consequently decisions are based on prior knowledge of the uncertainty of two of the most important petrophysical parameters, water saturation and porosity.Several wells have been used in this paper to demonstrate the utility of this application and how this analysis is used to design cost-effective logging programs. Even though this technique can be used with any logging measurements, the focus of this paper will be on resistivity and pulsed neutron devices which are widely used in reservoir monitoring. The examples will show how quantifying uncertainties of key petrophysical parameters reduces reservoir management risk.
Gelled Oil: New Chemistry Using Surfactants
Authors: Samuel M. , Nasr-El-Din H. A. , Jemmali M. 
Published: December 2007

AbstractWater-based fluids can damage some sandstone formations due to various reasons including clay swelling, emulsions, water-block, and wettability alternations. Oil-based fluids are less damaging than water-based systems to the hydrocarbon bearing formations. Conventional gelled oils (GO) have numerous limitations; however, they are used in formations that are highly sensitive to water. Aluminum carboxylate technology has been used for several decades, aluminum phosphate ester, however, has remained the preferred gelled oil system for the last thirty years.This paper describes the development of novel surfactant-based gelled oil (S-GO). This new technology uses surfactants to develop the viscosity of diesel. Unlike conventional gelled oil systems, this gelled oil is not sensitive to the nature of base oil or additive concentrations.The S-GO system, with an order of magnitude higher low shear viscosity, has much better solids suspension characteristics. This cleaner fluid also exhibits low friction characteristics, allowing pumping at higher rates. These unique features make the new S-GO system highly attractive for fracturing, frac-packing, sand control, coiled tubing cleanouts, and as kill pills. This fluid system can be used for applications up to 300°F.
Exploring Dispersion Effects and Crossflow Mechanisms in the Nearly Miscible Gas Drives
Authors: Hossein A. A. , Esmaiel T. E. H. , van Kruijsdijk C. P. J. W. 
Published: December 2007

AbstractMiscibility is an important parameter to optimize oil recovery in the gas drives. Additionally 2-D effects such as channeling, gravity tonguing, and crossflow can impact the level of miscibility and both local displacement and sweep efficiency. The adverse fingering or channeling tendencies will be mitigated to varying degrees by crossflow effects induced by the following physical mechanisms: (i) mass diffusion, (ii) dispersive mixing, (iii) viscous forces, and (iv) gravity forces [10]. All these factors are rate and process dependent, so that the effectiveness of a nearly miscible displacement needs to be analyzed in a manner which takes quantitative account of these interacting mechanisms. When mixing between layers of fast and slow flow occurs, the composition paths occurred in one dimensional flow change, and hence the development of miscibility is altered, to some extent at least in heterogeneous flow systems where crossflow occurs. In any real miscible floods the flow will be anything other than one-dimensional, as reservoir heterogeneity and viscous instability produce faster flow in some zones than in others. Therefore better understanding of the scaling of those interactions is an important part of improved accuracy of performance predictions for reservoir scale flows. Furthermore as numerical dispersion can cloud the interpretation of the results by artificially increasing the level of mixing in the reservoir, the effects of numerical dispersion should be clearly analyzed for each fluid displacement at the beginning of simulations. This has been done by selecting both the appropriate grid details and the compositional representation to achieve a solution which is not overcome by numerical functional errors.The objective of this study is to understand each individual key dispersion mechanisms induced by reservoir parameters. The second step is to identify the parameters that have strong influence on the displacement process. The numerical simulations of x-y and x-z cross sections are used to quantify the effects of various mixing factors and reservoir heterogeneity.
Combined Axial Tension/Compression and Internal Pressure Testing of Mini-Pipe Specimens in H2S Environment to Determine Three Dimensional (Triaxial) Stress States which Produce Crack Initiation Failure: Explanation of the New Test Fixture, Mini-Pipe Specimen, and Preliminary Test Results
Authors: Cernocky E. P. , Aaron V. D. , Paslay P. R. , Wink R. E. 
Published: December 2007

Abstract
The oil and gas industry is heading toward development of Extreme-HPHT wells which can expose low alloy, carbon steel production casing to shut-in pressures over 18,000 psi, 50-450°F changing temperatures, and a sour environment containing H2S, CO2, and water. These conditions represent a step increase in the severity of the service conditions acting on well casing. The completion of such wells requires a new, comprehensive understanding of the relationship between three dimensional service stresses (caused by load and pressure) and the capability of the pipe material to resist crack initiation. This step in understanding is aided by an evolution from the one-dimensional, pass/fail, NACE-A tensile test to an environmental test of a hollow pipe specimen loaded with a three dimensional stress state. The same type of test is able to calibrate the accuracy of a formula for pipe performance based on fracture propagation in a sour environment. This paper reports development of a compact (less than 2 ft x 1 ft), inexpensive test frame and hollow specimen geometry to address this testing need; and the paper reports initial results from such testing. Combined-load testing specimens in this frame provides a means to quantitatively determine the way that principal stresses in the well combine to cause (1) crack initiation and (2) crack propagation in low alloy carbon steel pipe in a sour environment. The testing is able to simulate the pipe combined loading which can occur in the well.
Part I of the paper explains the key features for the new test frame and specimens. The paper is intended to help enable the reader to build similar frames and specimens. The frame is able to passively apply axial tension or compression combined with internal pressure; internal H2S environment; and/or external H2S environment. The low cost and passive mechanism enable several frames to be run at the same time. The mini-pipe specimens are cut from the wall of coupling stock or heavy walled casing. The paper explains the specimen geometry, threading, end caps, H2S containment, and surface finish; the methodology for controlling loading of the coupon; and the low stiffness designed into the frame
Part II of the paper provides preliminary results of seventeen tests with combinations of tension, compression, and internal pressure; and internal/external H2S exposure. Additional tests are planned for 2005. The tests are intended to determine a critical combination of combined axial-pressure loading stresses, H2S corrosion exposure, and pipe material toughness which leads to crack initiation and failure in pressurized pipes. The role of the initiation failure formula is shown to be separate from a different formula for pipe failure due to crack propagation.
Evolution of Material Requirements and Products Answer For Critical Environments
Authors: Lepine E. , Orlans B. , Verdillon L. 
Published: December 2007

Abstract
Development of wells combining high pressure and high temperature (HPHT) containing hydrogen sulfide (H2S) has increased the need for high strength and sulfide stress cracking (SSC) resistant heavy wall tubular products.
The material requirements for these severe environments are continuously evolving. This trend is particularly evident in the evolution of HPHT well requirements, Sour Service applications and the associated testing protocols. On this basis, a precise combination of steel chemistry and heat treatment has enabled the development and qualification of C110 proprietary grade materials. This grade has been used in environments such as the North Sea, and is qualified under fit-for-purpose conditions. These products used worldwide and more particularly in the GoM (Gulf of Mexico), are suitable for sour service applications in heavy wall casing with various premium connections.
OCTG tubular products answer to key challenges such as dimensional specifications and mechanical properties. Unusual wall thickness and higher yield strength grades push back further exploration and production limits. In addition to the R&D effort, the high quality of such products is ensured thanks to a dedicated manufacturing process.
The Design of Tubing and Casing Premium Connections for HTHP Wells
Authors: Carcagno Gabriel 
Published: December 2007

Abstract
The design of premium connections for casing and tubing applications in HT/HP wells, especially in sour environment, require the consideration of extreme design conditions not present in common applications. The high pressures to stand and seal-both internal and external, and the limitations on steel yield strength due to sour environment provokes an increase of wall thicknesses, adding challenges to obtain simultaneously enough structural resistance, good seal response and low resistance to galling. The design of specific and very tight stress relief procedures is a key element to keep the material resistance to sour environment, when swaging or expansion required. Regarding design performance verification, it is based on the use of a combination of very refined non-linear Elastic-Plastic Finite Element Analysis, together with the testing concepts of new standard ISO 13679 / API 5C5, which expose the connection to a very demanding evaluation in terms of resistance to galling, extreme combined loading conditions –tension, compression, internal pressure, external pressure, bending, thermal cycling, and limit load.
This paper describes, through actual examples, the design process and the key elements that need to be considered in the design of a high performance premium connection for HP/HT Sour wells, from the paper to the manufacturing process, including the ways to balance the design features for optimum performance, and the different tools and evaluation methods required to validate the designs.
HPHT Completion Challenges
Authors: Zeringue Ron 
Published: December 2007

Abstract
The industry makes a pioneering discovery: 20,000 psi SITP, 100 ppm H2S, 10 % CO2, 400 °F flowing wellhead temperature. Now what?
Everyone wants production as soon as possible. What challenges need to be overcome? What equipment is available, and what needs to be designed and tested? How long will it take to design, build, test (and redesign, re-test), certify, and deliver? What challenges have yet to be identified? If you have a failure, can you work it over? Is there well control equipment in place?
Recent HPHT history indicates that infantile failures happen, usually caused by something that no one considered an issue. What are the hidden obstacles awaiting the first ultra HPHT completion? This paper will summarize current industry HPHT capability and more importantly, propose questions in an attempt to stimulate discussion on issues that we may be missing.
Improved Decision Making During Drilling Operations: Using a Wireline Coring System, Offshore Brazil
Authors: Shankel C. P. , Chachula R. 
Published: December 2007

Abstract
The Corion ™ Express coring system was used Offs coring programs. The Wireline system offers an efficient way to trip core while maintaining a large diameter core necessary to achieve high recovery rates and high quality cores. It also allows the operator to quickly decide as whether or not to simply drill ahead or to retrieve additional cores without additional trips in and out of the well. The coring/drilling assembly has been designed to either drill ahead in a conventional fashion or to core while drilling ahead.
The Corion Express cored the entire 3- ENC-2 reservoir interval and then deployed the drilling insert to TD the well without tripping the Drill String. 3 ½" cores of unconsolidated sand were recovered to surface conveyed by wire line through the ID of specialized drill pipe and BHA. At the completion of coring, and confirming the presence of the base formation, the drilling insert was deployed through the drill string and BHA via wire line, latched into place and the drilling to TD was completed.
This technology has the capability to provide the operator with a step level change in the acquisition of high quality cores in a more cost effective fashion. By eliminating trips the tool becomes very cost effective for long interval or multiple interval coring programs. The major advantage over existing technologies is the large diameter of the core head. The significance lies not only in larger diameter core capable of replacing conventional coring, but also in the fact that logging tools may be lowered through the bit and into the open well bore. The flexibility of a tool that offers coring, drilling, and open hole logging without tripping pipe can have a significant impact on exploration programs.