bluuebunny/crossref_metadata_2025_split huggingface dataset:
Determination of the Skin Factor for a Well Produced at a Constant Bottomhole Pressure
Authors: Kutasov I. M. , Kagan M. 
Published: December 2007

Abstract
A new technique has been developed for analyzing the constant bottomhole pressure (BHP) test data. The method presented in this note allows to calculate the skin factor for damaged and stimulated oil wells. Advantages of the BHP test are: (1) they do not require that well be shut in; (2) the fluid production can be easily controlled (at constant flow rate tests the BHP is changing with time); and (3) wellbore storage effects on the test data are short-lived. It is assumed that the instantaneous flow rate and time data are available from a well produced against a constant bottomhole pressure. Only records of the flowing time and cumulative production data are required to compute the value of the skin factor.
A semi theoretical equation is used to approximate the dimensionless flow rate. This formula is used to obtain a quadratic equation for determining the skin factor. The accuracy of the basic equation will be shown below. The paper includes an example o calculation.
A Simple Empirical Pipeline Fluid Flow Equation Based on Actual Oilfield Data
Authors: Osisanya S. 
Published: December 2007

Abstract
The selection of pipe diameter or length depends on the pressure drop available or anticipated flow rate. A simplified empirical pipeline fluid flow model equation is developed for sizing pipeline based on actual field data. The data used were the actual flow rates and pressure drops for four loading pumps and two booster pumps during the loading of two tankers. The model was used to calculate pressure drops for various flow rates while varying the pipeline length and diameter. The model was validated using classical Fanning/Reynolds number approach, API RP 41E design procedure for piping systems, and the famous Hazen-Williams equation for flow of water through pipelines. The loading pump performance characteristics were also evaluated by comparing the actual performance during pumping operation with the manufacturer's performance curve.
The pressure drops calculated for various flow rates and pipeline configurations using the model equation were in agreement with results obtained using the three methods listed above with a maximum pressure difference of about ± 25 psi. Evaluation of the pump performance showed the maximum mechanical efficiency as 79% compared to 89% originally specified by the manufacturer. The results of this work are applicable to designing pipelines based on actual field data. It is also useful for the periodic evaluation of pump performance.
Foam Rheology Characterization as a Tool for Predicting Pressures While Drilling Offshore Wells in UBD Conditions
Authors: Martins A. L. , Lourenço A. M. F. , Sá C. H. M. , Silva V. 
Published: December 2007

Abstract
The use of foam is a highly attractive alternative for drilling depleted, loss circulation or gas zones. Due to its complexity, a foamed system requires special attention while designing field operations.
This paper summarizes an extensive experimental program developed at PETROBRAS R&D Center facilities, coupled with a set of real scale tests under foam circulation conditions and numerical simulations, aiming the development of a comprehensive and useful model for predicting bore hole pressures while drilling under-balanced or near balance with foams.
The lab work steps include foaming agent selection, rheology lab equipment development and/or adaptation, definition of test procedure and matrix, besides discussion and analysis of results. After about 60 rheology tests performed in several lab and pilot scale equipment, correlations were proposed to predict rheological parameters as functions of foam quality. Based on the experimental data, a set of correlations was developed to predict foam rheological properties as functions of base fluid rheological properties and foam quality.
The next step was to evaluate the lab results by comparing pressure predictions with experimental data obtained by circulating different quality foams in a real scale vertical well located at PETROBRAS Training Center. The proper fitting of the proposed model and the experimental results supported its implementation in PETROBRAS lightweight fluid drilling software.
ROMEO: A New Powerful Tool for Drilling Rigs
Authors: Thomas S. , Cummins I. , Parfitt S. 
Published: December 2007

Abstract
This paper presents the new Integrated Mooring and Riser Analysis software developed by Noble Denton Europe Ltd. (NDE), called ROMEO. This software has been designed to be as useful a tool as possible for the management of drilling rig mooring and riser systems.
The theory behind the program is described and its use illustrated through an example study of a drilling rig operating in 6000ft of water.
Titanium Drill Pipe for Ultra-Deep and Deep Directional Drilling
Authors: Smith Jackie E. , Chandler R. Brett , Boster Patrick L. 
Published: December 2007

Abstract
This paper discusses the modeling and analysis of 5, 5-1/2, 5-7/8 and 6-5/8 in. titanium drill pipe in ultra-deep and deep directional drilling programs. Using a computer based drill string simulator, modeling a representative deep directional well, titanium drill strings were compared to the same size steel drill strings using two design criteria: margin of overpull and hydraulic efficiency.
Lateral Buckling of Pipe with Connectors in Curved Wellbores
Authors: Mitchell Robert F. 
Published: December 2007

Abstract
This paper brings together several buckling and pipe deformation analysis themes. Clearly, connectors should have an effect on the loading of pipe. For non-buckled pipe, Lubinski analyzed the effect of connectors on pipe in tension in a curved borehole and Paslay and Cernocky extended this analysis to pipe in compression. Connectors have an effect on the buckling of pipe, but the effect of connectors has only recently received attention. Three-dimensional helical buckling of pipes with connectors were analyzed by Mitchell, presented at SPE/AIDC 1999. Laterally buckled pipe with connectors was presented at SPE/AIDC 2000. In these papers, analytic solutions of the beam-column equations were developed in three-dimensions, and critical loads for buckling initiation were determined. Conditions for positive contact forces were determined and compared to previous buckling criteria, such as Paslay-Dawson.
In this paper, the wellbore curvature effects studied by Lubinski, Paslay, and Cernocky are included in the buckling effects studied by Mitchell. The modifications necessary to the analysis of lateral buckling are made for a curved wellbore. The resulting model gives a buckling criterion similar to He and Killingstad's results for pipe without connectors. The buckling model is integrated with the Paslay-Cernocky analysis to resolve some of the odd bending stress results developed by their model. Pipe deflections, contact loads, and bending stresses are determined with explicit formulas. Sag between connectors is calculated so that pipe body contact with the wellbore between connectors can be determined. Conditions for positive contact forces are determined and compared to previous buckling criteria, such as Paslay-Dawson and He-Kyllingstad.
Applications include the analysis of bottom hole assemblies, drill pipe, casing, and tubing. The solutions are simple formulas that are suitable for hand calculations.
Successful Application of MMH Fluid to Drill in Narrow Pressure Window, Ultra Deepwater Situation. A Case History
Authors: Fraser L. J. , Aragão A. F. L. 
Published: December 2007

Abstract
A mixed metal oxy hydroxide (MMH-type) system, which exhibits unique flow and gelation characteristics, was used to successfully drill an ultra deepwater well offshore Brasil. Despite ECD values that exceeded the measured leak off pressure and the calculated fracture threshold for the shale, no losses of fluid to the formation were reported. Subsequently rheological investigations of laboratory-prepared and field fluids were carried out under temperature and pressure conditions similar to those encountered on the subject well. The study unveiled unusual temperature responses of some key rheological measurements. This phenomenon may have played a part in the successful completion of the application discussed. Further work is being undertaken to better understand both this phenomenon and its implications for field application.
This paper discusses the development and application of the MMH fluid that is now a real alternative for the operator in deepwater applications where narrow pressure window circumstances have to be addressed.
Case History: Drilling Techniques Used in Successful Redevelopment of Low Pressure H2S Gas Carbonate Formation
Authors: Kinchen D. , Peavy M. A. , Brookey T. , Rhodes D. 
Published: December 2007

Abstract
This paper will provide a case study of the evolution of the drilling systems and techniques used to redevelop a dolomite formation located in the Indian Basin Field, Eddy County, New Mexico, USA. This study will compare data on wells drilled by Kerr-McGee over the past five years in this field where gas productivity ranges from 1000 MCFPD to 10,0000 MCFPD per well from the Upper Pennsylvanian (U. Penn) Cisco and Canyon formation.
The following drilling fluid systems utilized to drill 16 subject wells will be discussed:

Conventional
Four wells were drilled using conventional water based drilling fluids. When mud loss was encountered in the U. Penn, lost circulation materials (LCM) were used to regain and/or maintain circulation.

Drilling "blind" or "dry"
Two wells were drilled with this modification of the conventional system. Once returns were lost, an initial attempt was made to regain returns with LCM pills. If this did not restore returns, fresh water was pumped down the drill string to keep the bit face cleaned and drilling would proceed to total depth.

Air/Mist
Three wells were drilled using this medium. A string of casing was set prior to drilling into the U. Penn. An air/mist system was then utilized to drill to total depth. The well was completed open hole.

"Aphron" drilling fluid
This method was similar to the conventional drilling operation, but the drilling fluid system was converted to an "energized air bubble" mud system prior to drilling into the main pay. A total of seven wells were drilled with this system.
Using Multi-Function Fishing Tool Strings to Improve Efficiency and Economics of Deepwater Plug and Abandonment Operations
Authors: Going Walter S. , Haughton David 
Published: December 2007

Abstract
This paper discusses procedures and tool systems developed to optimize the efficiencies and economics of subsea plug and abandonment (P&A) operations. The tools and techniques described in the paper address removal of intermediate casing strings and final removal of the subsea wellhead. Included in the discussion is a new deepwater plug and abandonment system that employs a string of multi-function fishing tools that work cooperatively to minimize the number of trips required for casing and wellhead recovery (significantly reduce pipe-cutting time) and prevent wellhead damage without the use of motors.
Before the development of multi-function fishing tools, recovering a subsea wellhead required three or more drillpipe trips to remove each string of intermediate casing. This was followed by another trip to cut and recover the wellhead. During the 1990s, cut-and-pull technology consolidated cutting and recovery of the wellhead into a one-trip procedure. However, multiple trips were still required for each intermediate casing string. Given today's rig rates for deepwater work and the amount of time required to cut the large-diameter, thick-walled casing that ties into subsea wellheads, it is easy to see why any opportunity to improve the efficiencies of subsea P&A operations is welcome. The new systems and procedures addressed in this paper rely on proven technology to reduce risk and minimize field training required for successful deployment.
This paper compares time and costs for old and new methods. It describes a universal wellhead retrieval system and a unique procedural sequence in which casing is cut before seals are extracted. The system results in the ability to cut and recover the wellhead in a single trip without damaging the wellhead. The paper explains the safety, environmental, and economic advantages of eliminating motors and explosives and cutting the wellhead in tension. Case histories quantify results obtained in deepwater operations in the Gulf of Mexico and West Africa.
Continuous Direction and Inclination Measurements Revolutionize Real-Time Directional Drilling Decision-Making
Authors: Lesso William G. , Rezmer-Cooper Iain M. , Chau Minh 
Published: December 2007

Abstract
Strong economic and environmental pressures have led to the continued growth in the directional drilling business over the past few years. Parallel to this growth has been the complexity of the wells being drilled. These intricate trajectories have forced the development of more accurate sensors and surveying methods. However, directional drilling technology has not evolved rapidly enough to utilize the sophistication of the new measurements. Most directional drilling decisions are still based on traditional survey calculation methods, and regional knowledge concerning the behavior of the bottomhole assembly (BHA).
The use of conventional survey interpolation methods to determine well trajectories can conceal problems due to high doglegs and tortuosity that can lead to stuck pipe, missed targets, an inability to run casing, or may necessitate sidetracks,. High-speed transmission from measurement-while drilling tools can now take surveys in a near-continuous fashion. Therefore, direction and azimuthal information can be available every 2–3 ft while drilling. The continuous data, in addition to at-bit inclination measurements, contains rich information concerning the true nature of the wellbore tortuosity, and can be used to yield an accurate representation of the directional tendency of the BHA in both rotary and slide drilling modes, and may eventually make conventional survey measurements redundant.
A case study from the Gulf of Mexico highlights how the continuous direction and inclination measurements, and the surface and downhole drilling parameters, can be combined with a novel method to both calibrate and predict the directional tendency of a BHA in real-time. This methodology systematically reduces the ‘regionality’ in directional drilling operations, yielding the following: Early information concerning tool parameter settings for both conventional steerable and rotary-steerable drilling systems, for a more accurate approach to targets,Optimized slide/rotate sequences,Smoother wellbores, reducing torque and drag forces while drilling, and also minimizing the risk in running casing.
Innovations in Reservoir Navigation
Authors: Coghill J. , Benefield M. , Poppitt A. , Skillings J. 
Published: December 2007

Abstract
In order to maximize recoverable reserves in both new marginal satellite developments and bypassed oil in mature fields it is vital that a horizontal wellbore is optimally positioned within the reservoir. Recent innovations in drilling technology, three dimensional (3-D) visualization and logging while drilling (LWD) sensors have been integrated into a Reservoir Navigation Service focusing on maximizing the value recovered from every geosteered well.
Trends in Shallow Sediment Pore Pressures – Deepwater Gulf of Mexico
Authors: Ostermeier R. M. , Pelletier J. H. , Winker C. D. , Nicholson J. W. 
Published: December 2007

Abstract
As part of the effort to understand the problem of shallow water flow (SWF) in the Gulf of Mexico (GOM), and to obtain data and develop design criteria for offshore production structures, geotechnical wells were drilled in several different prospects. These prospects cover a 200+ mile swath across the central deepwater GOM where SWF control problems have been experienced. In these wells, pore pressure measurements, as well as core and other in-situ measurements, were taken in the deepwater shallow sediments.
Key facts and observations from these measurements include the following: A majority of the pore pressure measurements were made in low permeability clay rich material, predominant in the shallow sediments. Some measurements were proximal to more permeable sand and silt zones. A few measurements were made in sandy/silty intervals.Where significant over-pressures were present they were found to begin at or very near the mudline, and to increase more-or-less linearly with depth below mudline (BML).Over-pressures in the shallow sediments of the central deepwater GOM are due primarily to rapid sedimentation rates generated by the Mississippi River depocenter. This is supported by the fact that measured over-pressures exhibit regional trends generally consistent with sedimentation rate.Regional trends in over-pressures are also correlative with drilling experience and the incidence and severity of shallow water flow (SWF) occurrences.The degree of over-pressuring is consistent with sediment porosity based on core measurements, i.e., higher over-pressures are associated with higher porosities.There are exceptions to these general regional trends. Most notable is that over-pressures in shallow permeable sand or silt zones may not be in equilibrium with their bounding shales. Both pressure depletion and hyper-pressuring have been observed in the geotechnical-well pore pressure measurements and in drilling operations. Thus well location (up dip, down dip), faulting, fracturing and other factors need to be considered in predicting pore pressures in these permeable zones.
Successful Sealing of Vent Flows with Ultra-Low-Rate Cement Squeeze Technique
Authors: Slater H. J. , Stiles D. A. , Chmilowski W. 
Published: December 2007

Abstract
In the western Canadian sedimentary basin, tens-of-thousands of wells currently are leaking gas between the surface and production casings. Often this leakage manifests itself as a surface vent. While much work has gone into preventing gas vents during primary cementing, little has been done to improve the chances of successfully sealing existing leaking wells. The work described in this paper focuses on new materials and techniques that have been developed to seal vent flows. The paper describes the theoretical physics behind the process and gives case histories to demonstrate the successful application of the technology.
Pride Africa - Successful BOP and Riser Recovery Offshore Angola
Authors: Contarini P. , Zanchetta A. , Jeannet P. , Choquet M. , Sauteron D. , Puyaubran J. L. , Duhen T. 
Published: December 2007

Abstract
On the well JACINTO 01 (Angola), by 1 632 m of water depth, while pulling out the BOP stack to check a malfunction during the pressure tests of these BOP, before starting the17"1/2 phase, the breaking of the drilling line, while the BOP was at 620 m, caused the fall of the BOP and about 600 m of riser. The top drive felt and passed through the rotary table and, some other parts (bails, balls back-up wrench, elevator, riser running tool and few other metal debris) felt on the seabed with the BOP and the riser.The vessel returned to Cape Town for repair, inspections and preparation of the BOP recovery. In accordance with specialized service companies, we decided to try to recover it and we prepared tools:
For Example : ➩Lasso tool, Pride design➩Modified riser running tools➩Use of excavators➩Special jet subs with different designs …
The BOP recovery operation program, that will be developed in the presentation, is: Installation of a protection cage on well headRecovery of metal debris around BOPRecovery of laying riser joints by using jet tools, lasso tools…Excavation around BOP using excavators, jet tools …Cutting first riserFishing BOP using two strings in the same time…
The operation ended in success on the 26/01/2000, the entire BOP and the risers has been recovered.
Key Elements in Ultra-Deep Water Drilling Riser Management
Authors: Brekke James N. 
Published: December 2007

Abstract
Understanding the response of the drilling riser in ultra-deep water is critical for effective riser management and successful drilling operations. Due to the relative shortage of industry experience in ultra-deep water, analysis conducted prior to an operation is a key supplement to judgement and common sense. Damage or loss of the riser or the BOP leads to high costs for riser replacement and rig downtime.
The riser can be subjected to various loading configurations during a drilling operation. Storms and/or high current conditions can be encountered while the riser is in the following configurations: deployment; connected and tensioned; subjected to vessel drift-off; subjected to recoil after an emergency disconnect; and suspended in a hang-off condition. The unique aspects of each of these riser loading configurations in ultra-deep water warrant careful attention by riser analysts to provide operations personnel with well-founded guidance and an idea of what to expect in the field.
This paper provides an overview of the key elements of drilling riser analysis in ultra-deep waters. Analysis results are presented on the topics listed above, along with operational applications for several ultra-deep water drill ships. Shortcomings and uncertainties in riser analysis are discussed. The results show that analysis of key drilling riser configurations is critical for understanding riser response during operations and effective riser management.
Meeting Future Drilling Planning and Decision Support Requirements: A New Drilling Simulator
Authors: Booth J. , Bradford I. D. R. , Cook J. M. , Dowell J. D. , Ritchie G. , Tuddenham I. 
Published: December 2007

Abstract
Minimizing the cost of wells and the associated risk requires that construction techniques be optimized as rapidly as possible. This is a demanding task, particularly in an environment where fewer, higher value, more difficult wells will be drilled; it also necessitates a significant strengthening of drilling planning and decision support capabilities.
This paper presents an automated process for integrating well planning and real-time decision support. The process is encapsulated in a prototype software drilling simulator and incorporates recently developed real-time wellbore stability1and rate of penetration optimization modules. The simulator has three key features: Allows drilling practices to be closely linked with geological models.Provides a framework which integrates previously standalone aspects of drilling planning and decision support.Uses visualization techniques to convey complex models and results simply; this is a known driver of improved drilling performance2.
Examples illustrate the value of this integrated drilling planning and decision support tool.