bluuebunny/crossref_metadata_2025_split huggingface dataset:
Well Work Challenges in a Matured Offshore Operations
Authors: Ismail Abdul Malek , Ahmad Azmeer , Lane Tom 
Published: December 2007

Abstract
This paper will address and discuss the planning and operational challenges encountered in non-routine wellwork operations / well interventions in ExxonMobil Exploration and Production Malaysia Inc. (EMEPMI) oil and gas fields off the east coast of Peninsular Malaysia.
The introduction will provide a brief overview of EMEPMI wells, typical conventional workover rig (CWR) and non-rig wellwork operations such as coiled tubing operations, well servicing and wireline/slickline work. Subsequently, case examples will describe the planning and execution of non-routine non-rig wellwork operations, namely:–Coiled tubing milling of tubing retrievable surface controlled subsurface safety valve (TR-SCSSV) dislodged flapper,–High angle coiled tubing operations; static bottom hole pressure (SBHP) survey, setting tubing plug and sleeve shifting at well angle in excess of 75°,–High angle coiled tubing operations; setting through tubing inflatable packers at 88° well angle,–High angle well interventions with slickline; slickline fishing, and–Hot tap milling of stuck closed production casing x production tubing annular (B Section) wellhead valve.
Finally, the conclusion of this paper will share general lessons learned from the case examples in terms of applying best practices, planning the work and executing the work.
Formation Pressure Application for Correlating Miocene Turbidite Reservoirs in the Deepwater Gulf of Mexico
Authors: Russell C. , Luise N. , Kuecher G. , Lee J. 
Published: December 2007

Abstract
Thick allochthonous salt masses that pierced the seafloor in the formation of salt-cored folds flowed laterally downdip to form canopies above turbidite exploration targets. This acoustic configuration has created ray path and contrast difficulties for seismologists attempting to carry reservoir reflections beneath the salt and updip to their terminations against it. Initial attempts to correlate these turbidite channel and sheet reservoirs include standard log goodness-of-fit methods, paleontology, surface seismic, and expected hydrocarbon occurrences such as gas-updip-to-oil or oil-updip-to-water. Unfortunately, these methods seldom provide a definitive correlation. Formation pressure data, however, does prove effective in correlating and defining connectivity in these deepwater sediments, especially when exacting pressure gradients and detailed hydrocarbon characterizations have been performed.
HP/HT Drilling Fluids Challenges
Authors: Bland Ron , Mullen Greg , Gonzalez Yohnny , Harvey Floyd , Pless Marvin 
Published: December 2007

Abstract
Accurate knowledge of drilling fluid behavior under actual conditions is required to maximize operational efficiency and to minimize cost and drilling fluid related risks on extreme high-pressure / high-temperature (HP/HT) wells.
This paper identifies and discusses the major HP/HT drilling fluid challenges, recent innovations in fluid viscosity measurements under HP/HT conditions, drilling fluid designs stable to extreme HP/HT conditions, and other considerations in HP/HT drilling.
Experience of Using Services By Local and Foreign Companies in Drilling Wells on South-Priobskoe Field
Authors: Fecenec R. M. 
Published: December 2007

Abstract
The South-Priobskoye field simulation model was built in 2005 based on the seismic and logging data obtained in the wells of the pilot area. The field development program stipulated 200 wells to be placed on production on the annual basis.
Optimization of drilling process became a key issue to expedite field development and to save costs.
The JSC "SibNeft" hold several meetings with the leading international companies with the purpose to identify the best drilling technologies.
The discussions helped verifying the main approach to settle this issue as follows: drill 200 wells per year as minimum;reduce costs, as it will be the key factor to evaluate the efficiency;reduce drilling time, as it will be the key factor to evaluate the process efficiency;the proposed drilling and completion technologies have been substantiated.
All prospective options to improve the process were reviewed and identified. The proposals covered drilling technologies and other aspects, including drilling equipment upgrade, personnel training and project management issues.
The effect of these improvements was evaluated for all three drilling intervals (324 mm, 245mm and 178 mm). The evaluation method allowed identifying the quantities and prioritizing the improvement options. It also helped to calculate the reduction of time and costs per well. In order to implement the project, we need to properly prepare for it and to build a so-called "learning curve", which will identify time needed to collect the knowledge and the information, which in its turn will ensure the success of the project.
The best quality and profitability in the drilling process can be reached through the proper analysis, learning process and evaluation of the lessons learned, when drilling each individual well.
The key to success is a collective approach, when all the project parties share their interest in the "commercial drilling" project, where almost all aspects are optimized and oriented to the final product with minimum costs and time.
Surface BOP—Recent Experience and Future Opportunities
Authors: Kozicz John 
Published: December 2007

Abstract
Recent application of Surface BOP from floating drilling rigs to drill offshore wells began in early 1996 in the relatively benign environments of Southeast Asia.
The techniques and equipment required to use surface blowout preventers from floating rigs have evolved progressively from the initial application in relatively shallow water benign environments using moored semisubmersible rigs to recent application in very deepwater moderate environments using dynamically positioned drilling rigs (Fig 1).
While much of the industry focus has been on developing floating surface bop deepwater applications, a significant number of wells have been drilled effectively in shallow water depths using Surface BOP drilling units. The appeal for utilizing floating drilling rig-based surface bop technology in these areas is that the technique can address a number of site-specific issues facing bottom-supported rigs. These include:
Bottom-supported rig site assessment issues related to soil conditions. Risk mitigation associated with shallow geo-hazards. Improved operational efficiency compared with conventional subsea BOP or bottom-supported rig alternatives.
Additionally availability of an economic alternative to bottom-supported units effectively expands the available rig fleet thereby mitigating possible rig availability project constraints.
In addition to providing viable alternatives to bottom-supported drilling units in certain shallow water circumstances, floating drilling rig-based surface BOP is more readily adapted to other emerging drilling methods than a conventional subsea BOP configuration.
This paper will:
Review current practice with respect to surface BOP application from floating drilling units. Review alternative applications of surface BOP from floating drilling units Introduce surface BOP from floating drilling units as an enabling technology for deploying emerging drilling methodologies and equipment.
Production Performance Monitoring Workflow
Authors: Stundner M. , Nunez G. 
Published: December 2007

Abstract
The availability of accurate production volumes, at the well level and throughout the production network, is fundamental to the workflows that target the optimization of the economic potential of the reservoir. Without an accurate understanding of production volumes, the company's field development and operational decisions may not support the maximum economic value of the reservoir and can undermine the accuracy of the reserves estimates.
With current Digital Oilfield technology it is possible to measure production volumes at the well level and at intermediate outlets of the production facilities. However, for many fields this isn't a cost effective solution. Building non-parametric (Artificial Intelligence) production rate models based on pressure and temperature measurements has proven to be a valid and cost effective solution.
Several processes are necessary to measure and validate oil production at the well level as follows: Virtual Rate Measurement (VRM): ensuring accuracy of the volumes at the well level.Back Allocation: focussing on accuracy of the volumes at outlets of the facilities. To minimize the error in the volumetric measurements at both ends of the production network, both processes should be reconciled.The reconciliation procedure allows the comparison of the data coming from two different sources. By using this procedure, engineers can detect discrepancies that affect future decisions.
The sum of all these processes working together in a workflow is defined as "Production Performance Monitoring" (PPM).
The objective of this paper is to provide recommendations on how the PPM process should be properly implemented as an automated workflow to improve well productivity as well as to standardize process and data management. To fulfill this objective, the paper will address the following topics: brief introduction of current work practice, processes and workflows descriptions, technology available, real time environment, automated workflow application recommendation and potential benefits.
Multiazimuth Seismic to Well Tie for Fracture Characterization
Authors: Nawab Ramin , Maultzsch Sonja , Yuh Sung , Mouly Benoit 
Published: December 2007

Abstract
One of the ways to optimize the production of tight sand reservoirs is to take advantage of the geometry and density of the existing natural fractures in order to optimally design and locate the production wells. The detailed mapping of the reservoir fracture network is therefore essential.
To achieve such a detailed fracture mapping, a wide azimuth 3D surface seismic acquisition has been acquired and is being processed for azimuthal anisotropy estimation. The azimuthal variations of P-wave AVO and velocity are analyzed in terms of TIH anisotropy. In order to interpret the resulting anomaly maps in terms of fracture orientation and density, it is necessary to tie the measurements of anisotropy derived from the 3D surface seismic analysis to existing well data, such as well bore electric imaging and dipolar sonic logging. The multi-azimuth VSP technique is used to link these measurements with the surface seismic data.
Initial logging measurements carried out over the field show a very clear correlation between open fracture azimuths (determined by borehole electric imaging), the direction of fast shear azimuths (determined by dipolar sonic analysis) and the direction of tectonic maximum stress. Furthermore, the depth intervals with significant anisotropy correspond to the producing reservoir units.
Multi-azimuth VSP surveys are used to tie the interpretations of azimuthal anisotropy, carried out at the seismic scale, to the anisotropy and fracture measurements, which have been carried out inside the wells. Such well-seismic surveys should help to guide the surface seismic anisotropy processing by identifying the most suitable anisotropy attributes. It should also help to tie the 3D fracture interpretations to the well anisotropy and fracture observations.
Optimized multi-azimuth VSP surveys have been designed to link the ongoing surface seismic azimuthal anisotropy analysis to available well measurements.
The survey design is based on both 3D anisotropic modeling and synthetic multi-azimuth VSP data analysis.
This paper presents preliminary results on the multi-azimuth seismic anisotropy to well tie.
Horizontal Drilling Application to Recover Incremental Oil in Low-Permeability Carbonate Reservoirs, Partitioned Neutral Zone
Authors: Tran Thanh , Barge David , Ingham Stan 
Published: December 2007

Abstract
The Ratawi Oolite carbonate reservoir in the Partitioned Neutral Zone (PNZ) is located between Kuwait and Saudi Arabia and has been a prolific oil producer in the area. Several billion barrels of oil from this reservoir has been produced within the PNZ. As the fields mature, the easy produced oil in the high permeability intervals is diminished by increasing water cut. Considerable by-passed oil remains in the tighter and lower quality intervals. These oil reserves cannot be produced efficiently and economically by vertical wells through primary or secondary methods. Without different techniques of drilling and completion, most of the oil in the low permeability intervals will be left unrecovered.
A combination of horizontal drilling with geosteering tools and technology for precise lateral placement in the low permeability reservoirs in addition to a low fluid loss drilling fluid system have resulted in significant incremental oil recovery that would not be produced by existing or additional vertical wells. The success has led to new opportunity for horizontal drilling and horizontal sidetracking targeting low permeability reservoirs in mature fields.
Evaluating Expandable Tubular Zonal And Swelling Elastomer Isolation Using Wireline Ultrasonic Measurements
Authors: Herold B. H. , Edwards J. E. , Kuijk R. V. , Froelich B. , Marketz F. , Welling R. W. F. , Leuranguer C. 
Published: December 2007

Abstract
New completion techniques using expandable casing with swelling elastomers to seal the annulus, or just swelling elastomers used as packers are becoming available. Diagnostic services are required for these new completions such as evaluation of the annular seal, analogous to cement evaluation. Both conventional and new generation Wireline ultrasonic measurements have been used to characterize and possibly evaluate zonal isolation using swellable elastomers. So far, the following 360 degs circumferential measurements were studied: Ultrasonic radii, acoustic impedance (AI), as well as attenuation and third interface Echo (TIE) reflections from flexural wave data. Radii measurements show a "springback" effect, indicating that expansion against the formation has been achieved. Flexural attenuation has a much better dynamic range over the elastomer sections compared to the acoustic impedance measurements. Both measurements do not consistently distinguish rubber-backed casing with ordinary casing in our examples.
The TIE from the latest generation imaging tool tracking the external rubber interface, may provide the measurement the industry needs. First results look promising and further experiments to characterize the tool response are ongoing. The casing geometry of expanded liners was also studied.
Thermal Design of Wells Producing Highly Viscous Oils in Offshore Fields in the Gulf of Mexico
Authors: Ascencio-Cendejas F. , Reyes-Venegas O. , Nass M. A. 
Published: December 2007

Abstract
This paper shows the results of conceptual studies for the design of thermally bundled wells to optimize the heavy oil production of the offshore fields in the Gulf of Mexico.
During the last recent years, PEMEX has found more offshore reservoirs in the Campeche bay, which contain heavy oils (6-12 °API). Finding more oil is good news at the times that the production from the super giant oil reservoir of Cantarell reached its maximum production level and starts winding down. The economic implications and technical challenges for the exploitation of the recently found heavy oil resources are highly demanding because of the high viscosities of these fluids (40,000 cp at 15 °C) and then the plethora of flow assurance problems that will be generated while producing, transporting, and processing these fluids. Thermal bundled wells will allow an efficient exploitation of these fields.
Heat transfer management achieved through novel and clever thermal design, operation and maintenance of the wells, pipelines and process equipment, maintains the viscosity of the oil at acceptable levels. As to keep an efficient deliverability of the fluid to the surface facilities at the same time that reduces the flow assurance problems, while improves the economics of the exploitation of these fields.
Advanced Technology Improves Drilling Economics/Sets New Benchmark, Southeast Mexico
Authors: Urbieta A. , Martinez M. , Escareño P. , Arias A. , Portillo R. , Castellanos E. , Buske R. , Overstreet J. , Dick J. 
Published: December 2007

Abstract
The majority of the fields in southeast Mexico require 1,000m to 3,400m of 17-1/2 hole to set 13-3/8 casing at the top of Encanto/Deposito formation. Lithology is typically weak sandstone with shale stringers (UCS 2,000-6,000 psi). Operators have attempted to use PDC to drill the hole section in one run with limited success. Operators required an updated steel-tooth rollercone to cut costs by reducing trips/bits to complete the section. Examination of steel-tooth dulls indicated erosive and abrasive wear due to the high sand content was the major factor limiting performance improvement.
To cut drilling time/costs, the service company implemented a new steel-tooth bit with a new generation metal bearing seal and improved cutting structure that has significantly increased total cumulative footage and ROP drilling the 17-1/2" hole section. The metal bearing seal has significantly increased bit life relative to offsetting performance. To further capitalize on increased bearing reliability, the cutting structure has been strengthened by high-performance hardfacing further enhancing tooth/spearpoint durability. New design has added gauge holding ability and reduced cuttings inflow to the seal area further improving bearing life. By comparison, standard steel-tooth bits were often pulled with half to none of the tooth height remaining. This added durability dramatically reduces dulling of the cutting structure allowing the operator to maintain maximum ROP throughout the run while almost doubling total meterage.
The authors will present case studies that document the new bit design has increased meterage by at least 46%, ROP by 12%. Total bit runs have decreased from six to four and the total cone revolutions have increased by 60% compared to average values of best offset runs in several fields. This has saved the operator an average of $140,000USD per 17-1/2" hole section per well.
Simulating Transient Behavior of Cuttings Transport Over Whole Trajectory of Extended-Reach Well
Authors: Naganawa Shigemi , Nomura Tsuyoshi 
Published: December 2007

Abstract
Based on our previously developed prototype simulator, a transient cuttings transport simulator using the two-layer model was developed with some modifications and improvements for more practical use. To evaluate functionality and potential of the simulator, a post analysis on hole cleaning were carried out for an actual extend reach well (ERW) drilled in Japan. Simulation results showed that the modified model successfully demonstrated transient distributions of cuttings bed height and annular pressure over the whole trajectory of the well. From the comparison with a conventional steady-state analysis, transient simulation over the whole trajectory was found to be crucial and useful for prediction of behaviors unrecognized by steady-state simulations.
Application of an Evolutionary Algorithm in Well Test Characterization of Naturally Fractured Vuggy Reservoirs
Authors: Gómez S. , Fuentes G. , Camacho R. , Vásquez M. , Otero J. M. , Mesero A. , Castillo N. del 
Published: December 2007

Abstract
During the last years, several efforts have been done focused on developing the automatic computer-aided well test analysis. Traditionally, conventional gradient-based algorithms such as Levenberg-Marquardt have been used for parameters estimations. However, recently the use of new approaches based on global optimization methods has been introduced in the literature, mainly attempting to eliminate the influence of the initial guess on the overall regression, and overcoming the uniqueness problems.
The aim of this work is to study the characterization of naturally fractured vuggy reservoirs via the automatic well test analysis by using a triple porosity model recently developed. Thus, an Evolutionary Algorithm (EA) was designed, taking into account the important fact that the triple porosity case may yield multiple solutions. Therefore, several aspects such as the parameters estimations with high precision and the necessity of developing analysis techniques computationally efficient are taken into account in the design of algorithms.
According to the above, it is demonstrated that the algorithm developed in this work allows finding the multiple optimal solutions, with the desired precision. Advantages of the EA over the classical Levenberg-Marquardt method for this specific well test analysis problem are also discussed.
Successful Drilling of Oil and Gas Wells by Optimal Drilling-Fluid Solids Control – A Practical and Theoretical Evaluation
Authors: Dahl B. , Saasen A. , Omland T. H. 
Published: December 2007

Abstract
Since the development of the drilling industry the process has culminated in using shaker screens as the primary or only device for removing drill solids from the drilling fluid. Therefore it is necessary to optimize both filtration efficiency as well as the screen life to hinder drilled solids entering the drilling fluid. Optimum solids control can be obtained by using the understanding on how damage of the filtration cloth arises, on how to reduce it and finally on how the particles in the circulation system influence the general picture of the drilling process. When this knowledge is accepted in the industry, established and implemented in the drilling organisation; it is possible to maintain proper drilling.
This paper describes in detail the theory and field examples on how wear arise on the shaker screen cloth. As will be shown, this knowledge has been used to increase the solids control efficiency at the same time as the screen wear has been reduced by more than 90 % in field cases were 17 ½" sections have been drilled with OBMs. The documentation is based on practical offshore result from these drilling operations including data from the drilling log, laboratory analyses of the drilling fluid and of the Particle Size Distribution (PSD) of the drilling fluid. The particular focus of this article is the application of double deck shakers.
Innovative Design Processes and Technologies Improve PDC Bit Performance in Harsh Drilling Environments
Authors: Mensa-Wilmot G. , Mikhail B. , Al-Saeedi M. , Sounderrajan M. , Al-Anzi D. , Al-Khaldi M. 
Published: December 2007

Abstract
PDC bits are still confronted with performance challenges, especially in hard and/or abrasive formations. In most instances, the bit development or selection process compromises ROP for durability or vice versa. These solutions do not create the types of conditions needed to ensure the expected measurable gains in performance. As such effective product development, which targets the ROP/durability relationship, based on the performance optimization requirements of different applications, must be sought.
This paper will discuss field proven design processes and technologies, which have successfully been used to improve PDC bit performance in harsh drilling environments. The importance and contributions of bit stabilization in this effort, as well as its effects on ROP and durability, will be discussed.
As part of the product development processes that will be presented in this paper, drilling efficiency (DE) will also be discussed. In addition, the effect and influences of bit durability on drilling efficiency will be presented. Field data showing the positive impact of the new process on PDC bit performance, especially in hard and/or abrasive formations, will also be presented.