bluuebunny/crossref_metadata_2025_split huggingface dataset:
Additional Parameters for Better Vibration Control
Authors: Eltrissi Mohammad M. 
Published: October 2009

Abstract
Excess vibration of the drillstring is a serious concern in drilling because it accelerates the fatigue process and reduces the life of the bottomhole assembly (BHA). In extreme cases, excess vibration can lead to premature failure of the equipment. Drillstring vibration can also produce borehole washout, increase the risk of sticking pipe, and reduce the rate of penetration (ROP). Although weight-on-bit (WOB) and rotary speed are the primary parameters used to control vibration, the study of other parameters, such as ballooning, contact and frictional forces between the drillstring and the wellbore, and the finite displacement of the drillstring may provide additional tools and methods for controlling and minimizing drillstring vibration during drilling. The dynamic behavior of an active drilling assembly is complex to simulate and analyze, and finite element numerical models are used to investigate the influence of various factors on drillstring vibration.
The objective of this study is to derive additional options that will improve ROP by providing more flexibility in BHA design than those provided by traditional WOB-rotary speed methods. We focus on the influence of mud density, borehole inclination angle, and the choice of drilling fluid rheology model on the drillstring vibration.
New Approach to Drilling and Completing Horizontal Wells in Extremely Shallow and Unconsolidated Reservoirs
Authors: Saebi Shahryar , Staal Timo W. , Dawson Graeme , Miguel Dennis , Ooms Robert , Shield Chris , Paimin Mohd Razali 
Published: October 2009

Abstract
This paper discusses novel approaches that resulted in the successful drilling, completion, and production from shallow and unconsolidated clastic reservoirs, offshore Brunei.
As a result of these new approaches, detailed planning, continuous and open communication throughout the development project, the candidate well was drilled successfully, with the directional, well placement, and completion requirements being achieved. In addition, the application of new sand control technologies coupled with specifically engineered procedural solutions assured sand-free production at a rate above expectations.
Deployment Strategies to Reduce Risk in the Acquisition of Formation Evaluation Data
Authors: Kuchinski Robert 
Published: October 2009

Abstract
Effective reservoir management requires sound decision making that is based on formation evaluation data acquired during all stages of the life of the well. Without this data, reservoir understanding is compromised, which can impact long term well productivity. Given the increasing challenges of acquiring data in today's geometrically complex wells, new methods of data acquisition are constantly being developed and refined. This has led to a new area of oilfield innovation called conveyance. This paper is an analysis of the risks associated with the acquisition of formation evaluation data.
These risks are generally classified as follows: Non Productive time due to the inability of logging tools getting to bottom. (bridging)Non Productive time due to delays associated with making last minute arrangements for alternative logging methods when bridging problems become too severe.Lost in hole charges associated with permanently sticking logging tools due to challenging hole conditions.Unsound decision making throughout the life of the well, because challenging hole conditions, made the acquisition of formation evaluation data impossible.
The risks outlined above can also be assessed depending upon the data requirements and the conveyance method employed. A new risk assessment will be presented that discusses the risks associated with acquiring the data that provides insight into the six main formation properties required by the industry to understand reservoirs. Several conveyance techniques that assure the acquisition of data will be discussed along with case history's of some of these applications.
This paper will serve as a means to understand and assess the risks associated with the acquisition of formation evaluation data. It will also increase awareness of the techniques that exist for acquiring data, and ultimately allow for developing the best strategy to acquire formation evaluation data.
A New Riserless Method Enable Us to Apply Managed Pressure Drilling in Deepwater Environments
Authors: Rajabi M. Mir , Nergaard A. I. , Hole O. , Vestavik O. M. 
Published: October 2009

AbstractManaged Pressure Drilling has been proven to be a tool for extending access to previously unattainable drilling targets in many deepwater areas across the world, such as deepwater Gulf of Mexico. 21" Low-Pressure risers do not allow for application of Constant Bottom Hole Pressure (CBHP) technique by floaters. Since it is not designed to hole the pressure, it prevents setting up a closed circulation loop in our drilling system which is an essential tool for MPD.A high-pressure riser along with a surface Rotating Control Device is required to perform CBHP drilling technique. However, we know that deployment of such high pressure risers in long lengths and harsh environments has not come to be practical.An alternative drilling method from floaters at any water depth proves to be Reelwell Drilling Method (RDM). Reelwell AS, Shell, StatoilHydro, and the Research Council of Norway launched a JIP in 2005 to develop RDM, which is a riserless drilling method based on concentric drill pipe. Mud is circulated in a closed loop in this system. The pressure and flow of mud is dynamically controlled by a computer system on the return path on the surface. Many tests including the latest pilot test in March 2009 has proven that the downhole pressure can be controlled precisely and that the system fits perfectly for CBHP.Deployment of this technology by smaller floating rigs is possible with no limitation on water depth as huge and long 21" LP riser is eliminated from the system. The volume of mud is limited to bring about even more cost and rig space savings.
Improving Drilling Efficiency Through Wellbore Stability Analysis in the Gulf of Suez, Egypt
Authors: Van Steene Marie , Dutta Dhruba J. , El Fotoh Ahmed Abu 
Published: October 2009

Abstract
An increasing number of deviated wells are being drilled to maximize production and hydrocarbon recovery in the mature reservoirs of the Gulf of Suez (GoS). Successfully drilling a high-angle well in a tectonically disturbed and structurally complex area like the GoS is very challenging, especially in depleted reservoirs. Selecting the optimal mud weight is absolutely essential. Stress orientation and magnitude also have a major impact on wellbore stability.
The region poses significant drilling challenges that vary widely from reactive shale and salt creep to stress-related instability. From the findings of multiple wellbore stability projects we conducted in the GoS, we review the dominant mechanisms of wellbore instability in the GoS. We provide a summary of the failure mitigation measures and an overview of stress magnitude and orientation in the region, demonstrating how it impacts the knowledge of the most stable drilling direction.
Understanding the main causes of rock failure in the GoS resulted in improved drilling efficiency and reduced drilling costs. We show an example, where a new, nearly horizontal (86º) well was successfully drilled through the Asl formation with less than half a day of non productive time during the entire drilling process.
We conclude that acquisition of new, high-quality data would considerably reduce the uncertainty surrounding drilling complex wells in the area and reduce their cost.
Utilizing Top Drive for Casing Running System Reduce Well Construction Costs and Increase Safety
Authors: Shahin Nazir , El Messiri A. Amir , Haddad Abdel Hamid A. 
Published: October 2009

Abstract
A new portfolio of remotely operated casing running and casing drilling tools that connect to the rig's top drive and use the top drive's rotational power, hoisting and circulation capabilities for improved casing running operations. The value is increased safety and efficiency compared to conventional running operations, plus the ability to instantly push down or reciprocate while rotating and circulating, helping to get strings to bottom.
Applications include normal casing installation in pre-drilled wells on most rigs with a top drive system, and extended reach, deviated, and troublesome wells. Additional application includes casing drilling technology where the entire well bore can be drilled with the casing string; eliminating the need for drill pipe and bottom hole assemblies.
The new system combines several conventional casing handling tools into one: Power TongMain Hoisting ElevatorSingle Joint ElevatorFill-up and Circulation ToolWeight CompensatorLink Tilt (Stabber)Safety Interlock SystemTorque turn monitoring
Lab and field test results have proven that the new technology provides: Greater casing running efficiencyIncreased safety by reduction of personnel and remote operation.
Step change in technology will allow oil & gas operators to increase drilling performance and reduce well construction costs.
Study of Jilh Formation Overpressure and its Prediction
Authors: Zhou Shaohua , Al-Hajhog Jamil , Simpson Michael A. , Luo Maolin , Mohiuddin Mohammed , Tan Chee 
Published: October 2009

Abstract
The Jilh formation (JILH) is a tight, predominantly dolomitic Triassic formation occurring from 8,000 ft true vertical depth (TVD) to 10,000 ft TVD across the Ghawar field in Saudi Arabia. Drillers experienced extremely high pressured saltwater, oil and/or gas flows in about 20% of the wells that traverse it. The highest recorded flow rate from the JILH was 25,000 barrels per day (BPD) of saltwater and the highest mud weight required to control the JILH flow was 164 pounds per cubic foot (pcf) (22 ppg). The majority of the observed flows have been saltwater, which required a mud weight of 120 pcf to 155 pcf (16 ppg to 20.7 ppg) to control the well. This unpredictable nature of the JILH flow has not only mystified the drillers, but also plagued them across the Ghawar field.
If abnormal pressure is encountered in the JILH, a casing string is required to isolate it prior to drilling the Khuff gas reservoirs. If abnormal JILH pressure could be reliably predicted, 80% of the Khuff gas wells could be drilled with a "Slim Hole" casing design resulting in substantial reductions in overall well costs.
This paper presents a recent pilot study for predicting abnormal pressure in the JILH in the central area of the Ghawar field, Saudi Arabia. The 3D pore pressure distribution is estimated using a state-of-the-art integrated 3D pore pressure modeling software (PP3D), which is a combination of basin modeling and data inversion techniques. All available data sets (geological, logs and drilling reports) in the area of interest were used to conduct extensive log analyses.
This study identified the main cause of abnormal pressure in the JILH as fluid migration from the Sudair shale, due to formation compaction during burial. Well developed anhydrite stringers at the bottom of the base Jilh Dolomite (BJDM) blocked fluid migration to the JILH from the Sudair shale. Abnormal pressure exists in areas where these anhydrite layers did not develop well.
The pore pressure along well trajectories of four wells was blind tested with the predicted 3D pore pressure distribution. The average difference in pore pressure for these blind tested wells was −4.5 pcf (−0.6 ppg). Pore pressure in eight additional wells was also blind tested and good agreement between the actual and predicted pressures was found (average difference of −0.75 pcf i.e., −0.1 ppg). It was concluded that the accuracy of the model prediction would be adequate to optimize the drilling plans and casing programs in future wells.
Successful Casing Cementation in Total Loss Conditions—Case Histories
Authors: Dasgupta D. , Suyan K. M. , Banerjee S. , Ravi S. A. , Chakraborty Soumitra , Mondal Pradip , Jain V. K. 
Published: October 2009

Abstract
Total loss of circulation is a common problem during drilling through the fractured limestone in western offshore fields and coal seams in the CBM fields of eastern India. Most of the the times the wells are completed in total loss conditions either by drilling blind or by use of sub hydrostatic drilling fluid as conventional loss control measures were not effective. Moreover requirement of long cement column to cover multiple coal seams with excellent zonal isolation for fracturing in CBM wells during the production stage makes the cementation a big challenge in these wellls. To overcome these challenges, an inert dispersible fiber based cement system alongwith an improved placement techniques have been tested in the field with great success the details of which has been presented in this paper.
An innovative inert fiber based cement system has been formulated and evaluated in the laboratory for plugging fractured formations under simulated conditions prior to its application in total loss condition. Computer simulation studies were performed with field data and permissible slurry density and displacement rate were determined to minimize losses and formation damage during cementing. Limiting friction pressure by adjusting the rheological properties & displacement rate of the slurry during slurry placement also minimizes the lost circulation problems. Using this combination of improved cement system and placement techniques, circulation of the slurry was regained while cementing and the designed cement top could be achieved thereby avoiding anticipated repair jobs. Case histories of wells drilled with total loss conditions where successful implementation of this cementation technique prevented cement invasion into the production zone and lead to improved zonal isolation are presented in this paper.
This paper established the significance of application of these innovative cement system and cementing techniques in terms of better well completion and improved productivity in cementing across formations having total loss condition during drilling.
Minimum Requirements for Multi-Station Analysis of MWD Magnetic Directional Surveys
Authors: Nyrnes Erik , Torkildsen Torgeir , Wilson Harry 
Published: October 2009

Abstract
Multi-Station Analysis (MSA) is a technique widely used in MWD directional surveying to provide additional quality control and to correct for systematic errors. Although the method's potential to enhance survey quality has been demonstrated through several publications, experience has shown that MSA can produce unstable solutions and poorly interpretable results. In such cases, it is likely that the uncertainty estimate assigned to the data is invalid. Unfortunately, there is no standard in the oil industry defining the correct use of MSA. Different companies have developed different requirements and acceptance criteria, making it difficult to judge and compare survey quality between companies. The industry should therefore seek to establish a common standard for the application of MSA.
This paper presents a set of fundamental requirements that have to be fulfilled in order to ensure the correct application of MSA in drilling operations. The requirements consist of a set of mathematical rules and corresponding acceptance limits. Survey quality can be verified against any MWD error model by using the same mathematical framework, but changing the acceptance limits. Requirements and acceptance criteria are presented for two specific error models: Basic MWD without axial interference correction (Williamson 2000) and the same model assuming enhanced geomagnetic referencing.
The results presented in this paper show which systematic errors can be estimated for any given data set. A mechanism for determining tolerable survey noise is also included. This prevents misapplication of MSA under poor surveying conditions such as magnetic storms and drill-string vibration. The objective has been to develop requirements that are easy to apply in operations and which can form the basis for standardization across the industry.
Ultra Slim Rotary Steerable System Achieves World Record Performance in the Middle East
Authors: Barton Steve , Teasdale Paul , Robson Ian , Cartier Paul , Gohel Prashant 
Published: October 2009

Abstract
A 3 ¼″ ultra slim rotary steerable system (US-RSS) has been developed for use in through tubing rotary drilling (TTRD), with the objective of extending the production profile of offshore maturing fields. The introduction of RSS increases the capability of enhanced reservoir development by extending the reach of TTRD, improving drilling performance, increasing production from precise directional control, and lowering overall drilling costs. This development project was a collaborative effort involving several major operators to partially fund production of this ultra slim RSS that could pass through 5″ completion tubing.
This paper provides an overview of the RSS tool development including system testing at a full scale rig. This testing clearly demonstrated the directional functionality as well as successful communication between the measurement tools and RSS. The testing also allowed design iterations to be made to the drill bit so that the stability, side cutting and hydraulics were optimized and specifically matched to the operating mechanism of the tool. Due to the success in testing, the RSS and bit was taken forward into field trial.
Several runs were undertaken with the US-RSS for Dubai Petroleum. In an initial application, the assembly was utilized to drill a dual lateral oil producer / injector that traditionally would have been cost prohibitive due to time, or impossible due to torque and drag considerations. This lateral was achieved, including successful completion of the first ever ultra slim open-hole sidetrack.
The objective of a recent application was to drill the horizontal drain of a re-entry well. Use of the US-RSS delivered a saving of 6 days in time and approximately $1.8million in cost. The assembly also achieved a world record for footage with a US-RSS, drilling over 2000' with ROP 30% higher than the average produced with downhole motors.
Combined Technologies Offer Time-Saving and Efficient Alternatives for Zonal Isolation
Authors: Dickenson Robert , Fritsch Jerry , Noel Greg 
Published: October 2009

Abstract
Effectively managing resources encompasses accurate engineering of target formations and prudent execution of project capital. Attaining both requires employing current technologies and implementing efficient operations, especially with today's challenging drilling environments and economic climate.
In multiple cases these objectives have been realized by combining solid expandable tubulars and swellable elastomers to effectively isolate zones without cementing. Swellable elastomers on openhole expandable systems installed in hard rock eliminated not only the need for cementing, but also for underreaming (usually a necessity when installing expandables). The dual technology, when coupled with coiled tubing, enabled isolating multiple zones while optimizing casing diameter to accommodate high-rate fracturing operations. This approach enabled implementing a flexible fracturing process for operational efficiency.
In addition to drilling and completion applications, solid expandable tubulars and swellable elastomers provide a solution for challenges encountered when producing from mature reservoirs. A major challenge in reservoir management lies in controlling water production as the well life ages. An intervention project that combined solid expandable and swellable elastomer technology shut off unwanted water production that resulted in a sustained increase in oil production.
This paper describes how the respective evolution of solid expandable tubulars and swellable elastomers provided a step change in technology. Applications and case histories will be cited to illustrate the resulting savings of time, money, and consumables, and exemplify the technology's efficiency, reliability, and cost effectiveness.
Remote Real-Time Monitoring of Particle Size Distribution in Drilling Fluids During Drilling of a Depleted HTHP Reservoir
Authors: Ronaes Egil , Vik Siv Elisabeth , Taugbøl Knut , Sjåholm Åse , Kaageson-Loe Nils 
Published: October 2009

Abstract
This paper describes the successful use of Focused Beam Reflectance Measurement (FBRM) for remote real-time monitoring and management of drilling fluid Particle Size Distribution (PSD) while drilling in a depleted HTHP gas reservoir in the Norwegian sector of the North Sea.
Drilling into depleted reservoirs is challenging as the fracture strength of the reservoir is reduced due to pressure depletion from production. Experience has shown that adding suitably-sized blends of calcium carbonate and synthetic graphite to the drilling fluid can significantly improve the fracture strength. Optimum particle blends and size distributions are designed based on expected fracture and formation pore size. In order to maintain the formation strengthening effect, the PSD of the designed blend must be maintained during drilling and circulation of fluid. Furthermore, the method employed must be able to capture the changes in size distribution from the accumulation of drill solids and the mechanical attrition of particles in circulation. Monitoring and managing PSD effectively while drilling has been hindered by lack of suitable equipment for real-time measurement. The successful application of the FBRM technique has shown that reliable data can be obtained and that these data compare well with other conventional PSD measurement techniques.
This paper describes how the online PSD measurements were utilized to improve engineering of the drilling fluid to obtain full effect of the formation strength enhancement provided by the added particulate material. The improved PSD control can be used both to ensure sufficient concentration of correctly sized particles to effectively bridge the pore throats in the sandstone formation and at the same time include an ideal concentration of larger sized particles to plug fractures. Good solids control management allowed efficient screening of particles and when combined with addition of new material, provided full control of the total particle concentration.