bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integration of Analog Data for Building Testable, Deterministic Geological Models in a Common Interpretation Environment: An Example from the Atokan Boonsville Gas Field, Fort Worth Basin, Texas
Authors: McCormick David S. , Carr David L. , Bryant Ian D. 
Published: December 2007

Abstract
A fundamental problem facing the petroleum industry is to effectively use the large amounts and diverse types of data that are collected to define and exploit stratigraphic and structural compartments that contain undrained hydrocarbons. The key is to build data-driven, deterministic geological interpretations to intelligently target infill wells. This approach is fundamentally different from that used in geostatistically-driven approaches which interpolate the sparse data support points without maximizing the value of the data that has been collected or geological knowledge.
We describe a workstation tool and interpretation method for that allows one to combine, in 3D, well-based interpretation and quantitative analog information from fields or outcrops to make testable predictions about the location of geological bodies that are prospective infill drilling locations. This tool combines (1) 3D visualization in a common viewing environment of diverse data that are viewed at true scale (e.g., 3D surface seismic; vertical seismic profiles, reservoir simulation results, conventional wireline and borehole imaging logs, core photographs); (2) a well-based interpretation environment; and (3) an archive of digital 3D geological analog shapes and textures that one can use to relate textures seen in image logs or core images to those observed in analog data, i.e., other fields or outcrops. These shape and texture analogs can then be used to place geological bodies that can be rescaled and oriented in 3D. Comparison with seismic data may then support or refute these interpretations.
We have applied this tool to the interpretation of the Atokan Bend Conglomerate in the Boonsville Field in north Texas, a mixed siliciclastic-carbonate succession containing deltaic, estuarine, and fluvial valley-fill sandstone reservoirs. The key to exploitation of this field is identifying sandstone bodies within the lowstand, incised valleys, which are commonly less than 500 meters in width, and 20 meters in thickness. By combining core, image log, and seismic information in the 3D visualization tool, we have recognized Bend Conglomerate reservoir sandstone bodies and further, we have been able to define them in inter-well space using sandbody shape analogs from the tool's digital archive.
The key advantages of this approach are that we preserve information about the interpretation process and multiple hypotheses; we see all data at the appropriate scale; and we view the implications of the deterministic geological interpretations within the same data volume as our measured data. This provides a means of capturing and applying geological knowledge of analog formations, as well as tracking the steps in the interpretation process.
High Pressure Crystallization of Deep-Water Completion Brines
Authors: Freeman Michael A. , Slater Kenneth S. , Carminati John R. , Lester G. Scott , Morganthaler Lee N. 
Published: December 2007

Abstract
Deepwater development presents drilling and completion fluids with a new set of conditions: HPLT. This new combination of High Pressure and Low Temperature can induce gas hydrates formation if uninhibited water contacts natural gas. Brine can be a powerful hydrate inhibitor at high concentrations, but solubility (TCT) at mudline temperature limits its use. Recent experience has shown that the brine concentration is limited further because pressure sometimes raises the crystallization point of brine. Testing the brine for solidification at HPLT conditions has required us to develop new instrumentation and through it, a correlation between TCT and PCT at 10,000 psi of deepwater bromide brines.
A Novel Gas-Hydrate Inhibitor for Deepwater Frac-Pack and Subsea Environments
Authors: Nelson Ron D. , Fleyfall Fouad , Dubois Richard , Vitthal Sanjay , Spies Blaine K. 
Published: December 2007

Abstract
A significant number of deepwater fields are being developed with subsea production systems. One of the challenges of using these systems is controlling hydrate formation during initial well startup. Current solutions to this problem are very expensive and operationally challenging. However, a new borate-crosslinked gel system has been developed to prevent hydrate formation under static flowline conditions. This paper discusses the results of experiments performed to validate and compare the new fluid system to conventional borate-gel systems. This inhibited gel system exhibits fracturing-fluid performance equal or superior to that of conventional borate-gel systems. Specifically, the fluid exhibits much lower leakoff than conventional systems. The formation-damage characteristics of this fluid are also superior to those of conventional borate fluids.
Screenless Completions: Cost-Effective Sand Control in the Adriatic Sea
Authors: Pitoni Enzo , Devia Fabrizio , James Simon G. , Heitmann Norbert 
Published: December 2007

Abstract
Many gas reservoirs in the Central Adriatic Sea, offshore Italy, are formed of laminated, low permeability dirty sandstones, with as much as 50% clay content. Initially, wells were completed with gravel packs, but due to the nature of the formations, productivity decreased in some gas fields as fines plugged the gravel packs. In the last few years frac-packs have been used to increase productivity by by-passing near wellbore damage, interconnecting multiple sandstone layers and decreasing fluid velocities in the formation, thus inhibiting fines production.
However, there are many gravel-packed wells which are either sanded up and shut in or underperforming due to fines plugged gravel-pack screens and which cannot currently justify the expense of an immediate full rig workover.
A candidate zone was selected to evaluate the viability of a screenless completion technique for competent sand control to provide a cost-effective and reliable rigless rehabilitation technique. A highly conductive matured tip-screen-out fracture was placed in the zone, using recent innovations in fracturing fluid technology and proppant flowback control additives, to eliminate sand production. Successful implementation of this technique was confirmed by post treatment production more than 2.5 times the normalised rate of the initial gravel-pack completion. No formation sand or proppant were produced back to surface during production.
Drilling with Casing: The Mexican Technique Uses the Casing as a Drillpipe
Authors: de León Mojarro José C. , Terrazas Martin , Santana Victor M. , Eljure Abraham Julián 
Published: December 2007

Abstract
Everybody believes to drill a well, it is obviously necessary to use Drill Pipe. Pemex Exploration and Production (PEP) has drilled with Tubing more than a 150 gas wells since June 1996. Now PEP went further, cause PEP already drilled with 5 ½" Casing Hydril Series 500 Type 521, the gas well Culebra 281 in the area of Burgos Basin in Reynosa, Tamaulipas, Mexico.
This Mexican Technique uses the Casing as a Drill Pipe. The 5 ½" HD-521 Casing drills the first section with a 12 ¼ in. tricone bit and the second section with 8 ½ in. PDC bit. After the first section is drilled, the 9 5/8" Casing with guide shoe and float collar is run and it is cemented from the bottom to the surface. The second section is drilled with the same 5 ½" Casing to the programmed depth and finally the same 5 ½" Casing is run with guide shoe and float collar in stands in order to be cemented as an Intermediate Casing.
In both sections, the 5 ½" HD-521 Casing is rotated during drilling and it is retrieved to the surface in stands to lay down the drill bit and bottom hole assembly (BHA).
The third section and last section is drilled with 2 7/8" HD-533 Tubing, 4 ¾ in. PDC bit and 3 ½ in. Mud motor and then it is retrieved to the surface to lay down the drill bit and bottom hole assembly (BHA); finally the completion is done with the same 2 7/8" HD-533 Tubing which is run in stands with guide shoe and float collar to be cemented as a Production Casing (Tubingless Technique). The Mexican technique improves the return on investment, due to the fact, No Drill Pipe is required to drill the well and also this technique reduces drilling time and well cost.
Using Particle-Size Distribution Technology for Designing High-Density, High-Performance Cement Slurries in Demanding Frontier Exploration Wells in South Oman
Authors: Jain Bipin , Raiturkar A. M. P , Holmes Chris , Dahlin Andrew 
Published: December 2007

Abstract
A promising oil source in South Oman is providing challenges to successful cementing operations. The formation is approximately 4200m deep with bottom hole pressure of 13000psi. There is a very narrow margin between the formation pore and fracture pressures. Also salt saturated mud with weights up to 17.5 lbm/gal is routinely required to drill these wells.
There has always been a conflict with conventional oilfield cements between optimizing slurry properties for mixing and placement and resulting mechanical properties of set cement necessary for long-term zonal isolation. This conflict is even more evident in high-density environment where achieving slurry which is stable, mixable and pumpable frequently results in sacrificing set cement mechanical properties as compressive strength, permeability and porosity.
The challenge has been successfully dealt with in cementing high-pressure wells in South Oman using a technology adapted from the concrete industry. Particle Size Distribution (PSD) optimizes both slurry and set cement properties simultaneously. Extensive lab testing and yard trial prior to field application demonstrated the superior performance of High Density High Performance Slurries (HDHPS) over conventional cements in both the liquid phase and when set.
To date eight jobs have been performed and following improvements have been seen.
Average waiting on cement time has been reduced by 50% for plugs. Much higher success for plug setting compared to three successful plugs out of the previous seven with conventional slurries. Reduced difference between the planned and actual cement heights for plugs. Well cemented critical production liners shown by Cement Bond Logs.
Details of the slurry technology are presented along with data documenting the jobs done to date in South Oman. The system is widely accepted by operator in Oman and is the preferred system for critical high pressure cementing.
Field Testing of Advanced Turbodrill
Authors: Cohen John H. , Maurer William C. , Long Roy C. , Johnson Orren , De La Rocha Baudelio Ernesto Prieto , Saucedo Nicolas Rodriguez 
Published: December 2007

Abstract
An advanced 9e-inch high-temperature turbodrill has been developed that uses a gear box to increase the turbodrill torque to 7,800 ft-lbs and reduce the speed to 80 rpm, making it ideal for use with roller and PDC bits in hard rocks. The high torque output eliminates stalling problems associated with high-speed turbodrills, making these turbodrills easier to run in the field. In laboratory tests, this turbodrill drilled a 12¼-inch hole in granite at 96 ft/hr, while in the field it drilled at rates of 207 ft/hr compared to 76 ft/hr for rotary drilling. The turbodrill will operate at temperatures up to 400• F, making it ideal for horizontal drilling in deep, hot gas, and geothermal wells
Riserless Drilling With CaCl2 Mud Prevents Shallow Water Flows
Authors: Turner K. M. , Morales L. J. 
Published: December 2007

Abstract
The Mars basin is notorious for having among the worst shallow water flows (SWF) in the deepwater Gulf of Mexico (GOM). In August of 1998, the SWF sands at the southern end of the basin were successfully drilled riserless to 2105' BML with 25,000 bbls of weighted CaCl2 mud stored in the ballast tanks of a semi-submersible drilling rig. The mud system was designed to (1) be mixed and pumped at 1000 gpm, (2) be independent of boats for resupply, (3) maintain constant properties during transport and storage, (4) build a filter cake across 4+ darcy sands, and (5) be quickly weighted up in response to changes in pore pressure as seen with a PWD tool and ROV camera.
This paper presents a case history of the Mississippi Canyon Block (M.C.) 941 #1 riserless drilling interval from planning to execution. It took 4 months to prepare for the 26" hole interval, which drilled in 19-1/2 hours. The unique mud system developed in the lab, and the modifications to equipment and procedures at the mud mixing plant, workboats, and drilling rig are outlined in this paper. It includes details of SWF incidents which occurred during the drilling and cementing operations and how they were successfully controlled/prevented with a weighted CaCl2 mud system.
Drilling Fluid Plays Key Role in Developing the Extreme HTHP, Elgin/Franklin Field
Authors: Fitzgerald B. L. , McCourt A. J. , Brangetto M. 
Published: December 2007

Abstract
The development of the extreme high-temperature/high pressure (HTHP) Elgin/Franklin fields is an example of extending the technical envelope in a safe and cost-effective manner. This paper outlines the successful role of the n-alkane synthetic-base mud (SBM) in the drilling phase of this project. This success was based on the design criteria of the drilling fluid being met in practice.
At-Bit Inclination Measurements Improves Directional Drilling Efficiency and Control
Authors: Skillingstad Torger 
Published: December 2007

Abstract
A system that provides inclination measurements 1 foot behind the bit has been developed to improve the operational efficiency of positive displacement motors while drilling directional holes. This paper illustrates how this new system improves the directional control and drilling efficiency of steerable positive displacement motors. Improvements have been seen in:
Superior sidetracking performance by providing immediate information of when the bit starts to drill new hole. As a result time spent using the traditional "time drilling" technique is greatly reduced. Optimization of sliding intervals. With direct measurement of angle change during "slide" drilling the interval drilled can be optimized to ensure that the required hole angle is neither overshot nor undershot. This reduces borehole tortuosity and improves the gross rate of penetration since the rate of penetration during slide drilling is typically much less than during rotary drilling. Accurate landing of horizontal wells. Targets are more precisely penetrated, hole lengths in the zone of interest are maximized and risks of unplanned sidetrack operations are reduced. Reduced well tortuosity leads to a reduction in torque and drag. The results are easier sliding, less risk of stuck pipe, increased departures and fewer problems with running casing and completions. Reducing wellbore undulations in horizontal wells reduces accumulation of water along the wellbore and leads to increased oil production. Increased response and control of 2-D rotary steerable systems.
Integrated Management Approach Meets Environmental/Operational Goals for Exploration Well Drilled in Peruvian Rainforest
Authors: Elsborg C. C. , Whitney W. S. , Wilde A. F. 
Published: December 2007

Abstract
This paper describes the coordinated approach to the planning and execution that was implemented to maximize all operational efficiencies for a remote exploration well drilled in the rainforest of southern Peru. This synergistic approach enabled the operator to meet all environmental and operational objectives.
For this well, all operations with regard to drilling fluids and waste management were managed as a single entity, allowing the drilling personnel to focus primarily on complex downhole and logistical issues.
The authors will discuss the new approach that combined the drilling fluids and waste management processes under a single site manager. In the planning stages of the well, the integrated process took into account the sensitive environment of the drilling location to develop an applicable site design, techniques to monitor for environmental compliance and to establish individual roles and responsibilities. A drilling fluid system was selected on the basis of its flexibility to promote drilling efficiency while simplifying de-watering and waste treatment efforts. Additional environmental compliance efforts included extensive onsite and laboratory testing of all fluids generated on location, as well as monitoring nearby streams adjacent the well-site to determine the impact of the drilling operation on the jungle environment.
Both the environmental and drilling efficiency objectives were met during the execution of the drilling program. The management processes employed in this well could be applied in other environmentally sensitive locations to minimize drilling wastes, while maintaining drilling efficiencies.
Competitive Performance Drilling with High-Speed Downhole Motors in Hard and Abrasive Formations
Authors: Reich Matthias , Picksak Aeint , John Wolfgang , Regener Thorsten 
Published: December 2007

Abstract
Very hard and abrasive formations are often drilled with impregnated bits and high speed turbines. Typical application areas include the Middle East, onshore Germany, the North Sea, West Venezuela, and Italy. As opposed to positive displacement motors, turbines do not need elastomers in the power section, which can result in better durability in high temperature environments.
Due to its hydrodynamic function principle the power output of a turbine is not linear with the flow rate. A 20% reduction in mud flow reduces the power output by 50%, which drastically reduces ROP in all deep wells, slim holes or lost circulation situations, where it is not possible to operate the BHA with the full flow rate. Furthermore, the use of hydrodynamic power sections does not allow a clear indication of the bit RPM for the optimum operating point or bit stalling via standpipe pressure readings.
In order to overcome these operational difficulties a special high speed positive displacement motor (PDM) was developed. Due to the new design and manufacturing pro-cesses this motor combines the advantages of turbines (high bit speed, low sensitivity with regards to temperature) with the advantages of PDMs (RPM proportional to flow rate and nearly independent of the loading). With the superior torque capability the power output of this new downhole motor is more than double as compared to turbines, resulting in the possibility of using more aggressive bits and increasing ROP.
The paper discusses case histories from Oman, Germany and Italy and directly compares the performance of turbines with the latest design high speed PDMs. The case histories also demonstrate that the use of additional performance tools (i.e. downhole thrusters) can not only significantly improve the steering behavior of the drilling assembly, but also extend the maximum possible horizontal displacement of a well, and minimizes BHA failures.
Novel Jar Technology – The Down-Hole Clutch
Authors: Wijsman C. J. 
Published: December 2007

Abstract
Jarring techniques to free stuck drill strings have been used for decades in the drilling industry. However, jarring in directional and horizontal wells often remains without success. One of the reasons for insufficient jarring success in wells with extreme drag, is the inability to get sufficient pull at the jar. The jar impact forces are insufficient to free the string.
A drill string tool has been developed to enable jarring at high firing loads: the ‘down-hole clutch’. The down-hole clutch enables drill string rotation in the event of getting stuck. Deployment of a down-hole clutch will significantly increase the jarring effectiveness.
The benefits of the down-hole clutch tool in stuck pipe scenarios tool are quantified via torque and drag, and jarring calculations. The calculations to predict the jarring effectiveness are performed using a recently developed jarring simulation program. This program allows modelling of clutch-aided jarring. Other important clutch benefits are the improved hole cleaning and the operational advantage of exactly knowing the jar firing force.
A 6-3/4 inch prototype of the clutch tool has been built in 1999. Based on the calculations and the clutch design, the operational implications of running a clutch tool are reviewed: the placement in the string, engagement and disengagement of the clutch, the loading of the string during jarring and the elimination of the need for a second jar. Future alternative applications for the tool are for instance casing liner running and the down-hole expansion of casing.
Increased Oil Tolerance of Polymer-Enhanced Foams: Deep Chemistry or Just "Simple" Displacement Effects?
Authors: Hanssen Jan Erik , Dalland Mariann 
Published: December 2007

Abstract
In recent years, foam treatment has moved towards field qualification as a practical method for gas shut-off in oil wells producing at excessive gas/oil ratio (GOR). However, the time of gas blockage achieved in most field trials is limited to a few months. This may be too short for general industry acceptance of this economically very attractive niche technology.
Laboratory and scattered field data show that addition of polymers can enhance foam performance in oil-reservoir rock. However, little is known on precisely how addition of polymer improves the application-critical properties of a foam system.
This paper reports new experimental data for gas-blocking foams that appear to have superior oil tolerance caused by the presence of polymer. The results are discussed in a context of field experience with gas shutoff foams and thin-film research.
Core tests were conducted at reservoir temperatures, with crude oils from fields where field trials were done or planned. Systems studied include AOS surfactants and polyacrylamide polymers, bulk chemicals used in the field. Foam performance was measured in gas-blockage mode and forced flow. At zero oil saturation in cores, good foam performance was obtained with or without polymer added and with no systematic trends. Film properties for the same systems similarly gave no clear correlation with polymer concentration.
A new high-pressure cell built to allow direct visual observation of oil/foam interaction at reservoir conditions was used to see if polymer influenced the oil tolerance of AOS-based foams. No effect on the spreading/entering regime was found.
With oil in the core, AOS foams gave positive results only if containing polymer. Foam performance correlated with the level of oil saturation. It was hypothesised that the apparent oil tolerance of AOS/polymer foam was caused by the lower oil saturation in the core during foam generation.
This hypothesis was tested by pre-flushing a core with the polymer/surfactant solution, but then generating gas-blocking foam from a polymer-free foamer solution. The resulting performance was identical to that of the polymer-enhanced foam. Hence, no chemical interactions of polymer and surfactant, or any liquid-film stabilisation mechanism, is required to explain these results. The role of polymer in the systems studied was only to improve the foamer/oil displacement by causing more efficient displacement of oil before or during foam generation. If generally valid, these results have two major consequences:
Product selection by optimising polymer-foam systems for oil tolerance at a given oil saturation level is bound to fail. Foam process design should emphasise the need to create and maintain low oil saturations in the treated zone.