bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Advanced Kick Simulator for High Angle and Horizontal Wells-Part I
Authors: Vefring E. H. , Wang Zhihua , Gaard Sigurd , Bach G. F. 
Published: December 2007

ABSTRACT
This paper presents an advanced kick simulation model for high angle and horizontal wells. The model is based on an existing kick simulator for vertical and inclined wells developed over several years. This paper describes the extension of the simulator to handle kicks in high angle and horizontal wells. The new important developments include: 1) consideration of the long horizontal section exposed to the reservoir and therefore the coupling of fluid flow in the horizontal section with the influx from the formation; 2) new models for the gas slip and rise velocities in near horizontal wells, and 3) various models for different gas removal mechanisms. Typical simulation results are also presented to highlight the potential problems when circulating out kicks.
The new models for the gas slip velocities in near horizontal wells are based on the experimental and theoretical work. The gas removal mechanisms include the transportation of gas as large bubbles, in the form of entrained gas, and through gas dissolution in the drilling fluid. Type of gas removal mechanism depends upon circulation rate and mud properties. Models for these mechanisms have been developed based on theory and results from laboratory experiments.
Woodie: A Tool to Support Overpressure Detection
Authors: Cheli Elena , Brancato Calogero , Vagnoux J. P. 
Published: December 2007

ABSTRACT
The quality of a drilling program, that is its reliability and applicability, is essential for the achievement of safety, operational and economical drilling objectives. The most relevant influence, with respect to these objectives, is exerted by a correct evaluation of a formation's pressure regime.
The operative effectiveness of the several methods developed by the petroleum industry for overpressure detection depends highly on the quality and quantity of data that can be accessed and interpreted by experienced personnel.
This paper deals with the description of WOODIE (Well Online Overpressure Detection Interactive Environment) [1], a computerised knowledge based system designed with the aim of supporting the complex task of overpressure detection.
A user-friendly interface allows drilling technicians, not necessarily specialised in overpressure evaluation, to browse and investigate in depth a large amount of information as well as to evaluate results processed by the system.
The WOODIE application is part of ADIS – AGIP's Advanced Drilling Information System [2] – aimed at obtaining better rig-site support, improving the management and reducing cost and risk.
Re-Defining the Exploration Drilling Technique in the North Sea: The First Step
Authors: Ehret J. R. , Carstens Eilif , Johnston Colin , Vagen Per 
Published: December 2007

ABSTRACT
Slim-hole exploration drilling and coring in the North Sea is limited. It is a concept that requires further evaluation. The full economic benefit of slim-hole drilling can be realised with a total slim-hole package, e.g., with sized down subsea BOPs, riser and floating vessel. Also, slim-hole drilling using coiled tubing is a technology requiring further testing.
Prior to expending considerable capital on a fit-for purpose slim-hole floating vessel, the slim-hole drilling technology must be fully proved.
The first step in exploiting this concept is to prove that high quality cores and electric logs can be obtained using slim-hole technology on a floating vessel.
This paper describes a test programme to determine the viability of drilling and coring a slim-hole with coiled tubing and drill pipe from a semi-submersible in the North Sea.
A Dynamic Model for Underbalanced Drilling With Coiled Tubing
Authors: Rommetveit Rolv , Vefring E. H. , Wang Zhihua , RF-Rogaland Research , Bieseman Taco , Faure A. M. 
Published: December 2007

ABSTRACT
A model for underbalanced drilling with coiled tubing has been developed which takes into account all important factors contributing to the process. This model is a unique tool to plan and execute underbalanced or near balance drilling operations. It is a transient, one-dimensional multi-phase flow model with the following components: Lift gas system model, multiphase hydraulics model, reservoir-wellbore interaction model, drilling model, models for multiphase fluids (lift gas, produced gas, mud, foam, produced gas, oil, water and cuttings). Various alternative geometries for gas injection are modelled as well as all important operations during underbalanced drilling with coiled tubing.
The model as well as some simulation results from its use are presented in this paper.
Behavior Based Approach to Creating a Strong Safety Culture
Authors: Hubler W. G. 
Published: December 2007

ABSTRACT
The attainment of world class safety by any organization is determined by its ability to eliminate unsafe work practices by its employees and contractors and gain the active involvement of its work force to prevent injuries. This paper begins by outlining foundation concepts of behavior based safety management (Part I). It then describes a behavior based safety process tailored to drilling operations which produces improved statistical and financial results (Part II). Implementation of the process produces greater organizational development and builds the foundation for a deep-rooted safety culture.
A Novel Approach to Initiating Multi-Lateral Horizontal Wells
Authors: Konopczynski M. R. , Hughes John , Best J. E. 
Published: December 2007

ABSTRACT
This paper describes the development and testing of a novel method to initiate multilateral horizontal wells that allows selective re-entry into any of the branches. The benefits of multilateral horizontal wells are reviewed, current methods, their benefits and drawbacks are described, and the criteria for designing a new method and tools for initiating multilateral horizontal wells are listed.
Previous systems designed to initiate multilateral wellbores with selective re-entry have been quite complicated and therefore, costly. This paper describes a system for orienting and cementing pre-cut window sections in a typical production casing string, which provides a positive method for positioning and orienting a retrievable whipstock. This design does not have the capability to conveniently tie back or cement liners in individual lateral wellbores, but it is well suited for application in medium radius and short radius horizontal multilateral wells where bore-hole stability or zonal isolation are not issues.
Dynamics Modeling of PDC Bits
Authors: Hanson J. M. , Hansen W. R. 
Published: December 2007

Abstract
A numerical bit dynamics model has been developed for the purpose of predicting PDC drill bit performance under conditions of a full-scale drilling simulator test. The model accounts for the interaction of the PDC cutters with the bottom hole and side wall rock surface and bit impact energy loss and friction between the bit gage and hole wall. It also accounts for the induced vibration of the main mechanical components of the full-scale drilling simulator. The model has been validated by comparing predicted bit performance with full scale drilling experiments.
Twenty bit designs (15 anti-whirl and five "conventional") ranging from 5 7/8" to 17 1/2" have been used in this validation. The numerical simulator correctly predicts for 18 out of the 20 bits whether or not the bit whirls and the rate of penetration at which the bit stops vibrating in the hole.
This paper discusses the development, numerical implementation, and experimental validation of this PDC bit numerical drilling dynamics simulator.
Environmental Safe Water-Based Drilling Fluid to Replace Oil-Based Muds for Shale Stabilization
Authors: Headley J. A. , Walker T. O. , Jenkins R. W. 
Published: December 2007

ABSTRACT
A recently developed, environmentally safe, water-based drilling fluid has been given its first field trials. The successful field tests have shown that the fluid is indeed very shale stabilizing, has the ability to solve some mud related drilling problems, is easy to formulate and maintain, and is non-hazardous and environmentally safe. These results have corroborated the laboratory testing which had shown that the fluid stabilizes shales by the same mechanism as does oil-based fnuds1.
The drilling fluid, which is based on methylglucoside (MEG), thus has the potential to replace oil-based drilling fluids in many operational areas. The use of this drilling fluid could reduce or eliminate costly disposal of oil contaminated drilled cuttings, minimize health and safety concerns, and minimize environmental effects.
A New Generation of Shale Inhibitors for Water-Based Muds
Authors: Stamatakis Emanuel , Thaemlitz C. J. , Coffin George , Reid William 
Published: December 2007

ABSTRACT
New applications of structurally unique organic cationic materials fOCMs) have provided a highly efficient and economical technology for inhibiting the swelling and yielding of hydratable shales. These OCMs are compatible with all common drilling fluid additives, thermally stable, and environmentally acceptable. The laboratory determined properties and field tests of the OCMs are discussed in detail.
1993 U.S. Beaufort Sea Offshore Exploratory Drilling Achievements: A Case History
Authors: McKay T. W. , Johnson F. C. , Pidcock G. A. , Johnson L. A. 
Published: December 2007

Abstract
This technical paper provides a case history of the exploratory drilling operations undertaken in the Beaufort Sea during the 1993 drilling season. Through a combination of extensive planning, operational teamwork, advanced technology and favorable ice conditions, a total of three wells were completed in one season. The successful completion of this many exploration wells during one season was an historic achievement for both the U.S. and Canadian Beaufort Sea operating arenas.
The operation involved the early mobilization of the drilling vessel "Kulluk" along with associated ice breaking support vessels from a stack location in remote northern Canada, to the drilling locations in Alaska's Camden Bay, offshore from the Arctic National Wildlife Refuge. Logistical support for the operation was maintained primarily from Prudhoe Bay, and the operation was managed from ARCO Alaska's offices in Anchorage.
The 1993 operation was a follow up to a program the previous year, in which a hydrocarbon discovery was made at ARCO's "Kuvlum" location. The paper will document the 1993 operations in which three wells were drilled, and contrast this with the 1992 season in which one well was drilled. The paper will show how advance planning, favorable environmental conditions, and management commitment enabled ARCO to achieve its aggressive exploration drilling goals for this project.
Management of a New Build Jack-Up for Drilling An HPHT Well
Authors: Mars Paul , Baranthol Christian , Carriay Jean , Cotterill M. D. 
Published: December 2007

Abstract
The successful commissioning, acceptance and performance of a large, harsh environment, highly automated new build jack-up rig to safely and successfully drill its first well (deviated HPHT) relies on the effective joint management by the Drilling Contractor and Operator. The key factors underlying this success are correct equipment, the application of established procedures and experienced well trained personnel. This paper presents how co-operative management between the Drilling Contractor and Operator successfully brought the new build jack-up West Epsilon through the initial commissioning and acceptance stage to successfully drill a deep, deviated HPHT Well.
Reducing the Risk of Stuck Pipe in The Netherlands
Authors: Hopkins C. J. , Leicksenring R. A. 
Published: December 2007

Abstract
Stuck Pipe in the drilling industry results in hundreds of millions of dollars wasted world-wide. After such costs in NAM escalated in 1992 and 1993 a team was set up to establish the causes and provide structural solutions to reduce the associated stuck pipe costs. Analysis of current and historical data was used together with the regular reporting of statistics to increase awareness within the drilling environment. Stuck Pipe Prevention courses were created for well site personnel. Current information used world-wide was evaluated and used where applicable. Early input into the design of each new well enables potential problems to be covered and solutions sought in a timely manner. Computer programs have been used to increase our understanding of rock failure and assist in optimising flow rates. This paper attempts to show the changes that NAM has made in the way we do business and the perceived benefits from so doing.
Case History of Floating Mud Cap Drilling Techniques—Ardalin Field, Timan Pechora Basin, Russia
Authors: Reyna Erick 
Published: December 2007

ABSTRACT
Floating Mud Cap Drilling Techniques have been used in the drilling industry since the early part of the 20th century. Rotating Heads have made this practice almost obsolete, but the practice is still used in areas where carbonate reservoirs and other highly permeable reservoirs experience either partial or full loss of returns[1-2].
The objective carbonate interval in the Ardalin field often experiences full loss of returns that cannot be controlled by conventional western or Russian techniques. Field operations occur in an ecologically sensitive tundra environment, under arctic weather conditions, accessible by only helicopter in summer and snow road in winter. Rotating heads would have been costly and difficult to design for a Russian rig. Floating Mud Cap Drilling operations, though basically a simple procedure, required fore thought and planning in order to be successful under these conditions. This paper will present the thought processes and planning used to successfully drill through the objective interval with full loss of mud returns.
Hole Cleaning in Extended Reach Wells: Field Experience and Theoretical Analysis Using a Pseudo-Oil (Acetal) Based Mud
Authors: Gao Erhu , Young A. C. 
Published: December 2007

ABSTRACT
To achieve adequate hole cleaning has been one of the greatest concerns in drilling extended reach wells. Effective hole cleaning is often difficult to obtain, especially when drilling reactive shale formations in large diameter holes. This paper presents both the field experience and theoretical analysis of the hole cleaning performance of a pseudo-oil (Acetal) based mud in drilling extended reach wells. Based on the analysis, a series of field guidelines for effective hole cleaning was developed and is also presented.
Safe Drilling of HP/HT Wells, The Role of the Thermal Regime in Loss and Gain Phenomenon
Authors: Maury Vincent , Idelovici J. L. 
Published: December 2007

ABSTRACT
Drilling through the overburden of an HP-HT reservoir located in the Central Graben of the North Sea (5400m TVD; pore pressure 110.7 MPa; Temp. 190°C) led to slight but persistant unstable conditions when flow checking the well. Progressive increase of the mud weight proved inefficient to mitigate a permanent increase of bottomhole gas. After the mudweight increase, the well became more unstable (flowing) and it further degenerated to pressure build up at the surface when the well was shut in for a B.O.P. test. A total of 30 rig days were lost in recovering the well stability including setting of a contingency liner.
The paper briefly describes the main features of the reservoir and drilling parameters used for drilling the 22/30 c-10 well, the observations made during the incidents. It gives an analysis of these observations which led to the identification of the cause of the abnormal behaviour as a transient thermal regime of the well combined with the effects of the ECD and the progressive mud weight increase.
The thermal and pressure regimes of the well during drilling and mud circulation interruptions consist of alternate cooling and reheating, with simultaneous variations of pressure (from static mud weight to E.C.D). Borehole stress evaluation shows how the near wellbore fracture gradient can be exceeded, when cooling is combined with E.C.D., inducing small fractures. Closure of these fractures on reheating is responsible for transient pressure build up and back flow, which are not true kick indicators, but were considered as such before correct identification of the mechanism. When the static mud weight is increased to "in principle" counteract the phenomenon, the far field in situ fracture gradient is exceeded. Numerical modelisations were made to quantify the mechanism.
Understanding the basic cause of the loss and gain allows us to propose a means to counteract it: no mud weight increase, attention to mud properties, precaution in the use of the mud heat exchanger. These recommendations were followed on the next well and similar symptoms were encountered but much less pronounced and of no risks for the well. Rig time lost, well control operation, and contingency liner setting could be avoided.
The conditions particular to HP/HT wells play a major role in this phenomenon.
Determination of Hydrostatic Pressure and Dynamic ECD by Computer Models and Field Measurements on the Directional HPHT Well 22130C-13
Authors: Baranthol Christian , Alfenore Jacques , Cotterill M. D. , Poux-Guillaume Gregoire 
Published: December 2007

Abstract
The margin between fracture pressure and formation pressure while drilling the HPHT section on the deviated Well 22/30c- 13 was marginal. To successfully drill this section required an accurate knowledge of the Equivalent Mud Weight (hydrostatic pressure) and Equivalent Circulating Density. This paper presents how field measurements in conjunction with computer model predictions of hydrostatic pressure and ECD were made and applied to drilling the HPHT section. The technique proved valid for use in future HPHT wells. This paper also presents the effect of barite sag on hydrostatic pressure and ECD in a deviated HPHT well.
A Case For University Credits For Industry's In-House Continuing Education Programs
Authors: Carlile R.E. 
Published: December 2007

Abstract
THE MINERALS INDUSTRIES HAVE LONG RECOGNIZED THE TANGIBLE AND INTANGIBLE RETURNS FROM CONTINUING EDUCATION PROGRAMS FOR THEIR TECHNICAL, SCIENTIFIC AND ADMINISTRATIVE PROGRAMS FOR THEIR TECHNICAL, SCIENTIFIC AND ADMINISTRATIVE PERSONNEL, THESE PROGRAMS ORIGINATE FROM THE MUTUAL DESIRES PERSONNEL, THESE PROGRAMS ORIGINATE FROM THE MUTUAL DESIRES OF THE EMPLOYER TO UPGRADE THE PROFESSIONAL COMPETENCE OF THE EMPLOYEE AND THE EMPLOYEES CONCURRENT DESIRES TO KEEP ABREAST OF NEW DEVELOPMENTS TO REVIEW THE STATE OF THE ART OF SPECIALIZED SUBJECTS, AND TO BETTER QUALIFY HIMSELF TO COMPETE IN AN EVERY CHANGING TECHNOLOGY. IN-HOUSE TRAINING AND CONTINUING EDUCATION PROGRAMS TO PROVIDE SUCH REVIEW AND EDUCATION FOR THE EMPLOYEE ARE BECOMING A RECOGNIZED FUNCTION OF COMPANIES COMPRISING THIS INDUSTRY. THESE COMPANY-SPONSORED SEMINARS, WORK-SHOPS, AND TRAINING SESSIONS ARE AUGMENTED BY THE PERMITTED ATTENDANCE OF EMPLOYEES AT COMMERCIALLY AND UNIVERSITY-PRESENTED WORKSHOPS, AGAIN UNDER THE RECOGNITION OF THE DERIVED BENEFITS ACCRUING TO EMPLOYEE AND EMPLOYER AND A HIGHER LEVEL OF PERFORMANCE RESULTING.
Effective Relative Permeability in Scale-Up and Simulation
Authors: Saad Naji , Cullick A. S. , Honarpour M. M. 
Published: December 2007

ABSTRACT
In modern reservoir characterization, detailed heterogeneous models of reservoir properties are routinely scaled-up for flow simulation. In addition to single-phase flow properties, two-phase flow properties, relative permeability and capillary pressure functions must also be scaled up. Here techniques for determination and assignment of effective relative permeability and capillary pressure on different scales of heterogeneities are presented and discussed. Many authors have considered scales of heterogeneities, their influence on fluid flow, and calculation of effective properties at a particular scale. In this paper, however, we present a unified approach to this problem; we consider effective relative permeability and capillary pressure on multiple scales of heterogeneities, and discuss a procedure for considering these heterogeneities at each level so that the overall influence is represented in the flow simulation model, results of which are used for economic decisions.
A simulation technique and an analytical method for calculation of effective relative permeability and capillary pressure are presented. Scale-up of relative permeabilities results in a set of effective relative permeability curves and an effective capillary pressure curve for each larger-scale simulation grid block.
We show how these relative permeabilities, and the corresponding effective capillary pressure curves, can be grouped together to yield a manageable number of effective relative permeability and capillary pressure curves for flow simulation. The application of these techniques is demonstrated through 2D and 3D scale-up and flow simulation examples.
Pulsed Neutron Capture Log Evaluation - Louisiana Gulf Coast
Authors: Stieber S.J. 
Published: December 2007

Abstract
Saturations initially computed from Pulsed Neutron Capture log response usually vary significantly from final or "refined" values. In many instances, considerable juggling of "fixed" parameters is necessary before reasonable saturations are derived. Slight variations in water salinity, shaliness, hydrocarbon or rock matrix capture cross sections can result in significant saturation uncertainties. This study primarily concerns a statistical study of log response opposite zones of known saturation conditions and formation water salinity. A technique to compensate for shaliness based on relative natural gamma ray deflection is developed. The average relationships presented represent a standard error for computed water saturations of ±15 saturation percent. Normalizing techniques utilizing one or more intervals in which saturation conditions are known can substantially reduce this error.
Introduction
Since the introduction of Pulsed Neutron Capture logging, over 130 Neutron Lifetime Logs (Dresser Atlas)1 and 30 Thermal Decay Time logs (Schlumberger)2 have been run in Shell's South Pass Block 24 and South Pass Block 27 Fields. In many cases, quantitative interpretation of the log is difficult primarily because of wide variations in computed matrix capture cross sections (Sma) lack of porosity control, uncertainty in hydrocarbon capture cross sections, and the inability to compensate for shaliness.
All of the major producing horizons in the two fields are broken sand-shale sequences, normally compacted, with sand quality primarily varying with the degree of silt and clay content. Since "trend" analyses and normalizing techniques have proven effective in handling uncertain petrophysical parameters for similar sedimentary sections, the techniques were applied to PNC log interpretation.
Before any shaliness correction based on relative gamma ray deflection can be developed, one of the following assumptions must be made:
Shale is interbedded or laminated with clean sand. Shale or clay is evently distributed within the sand matrix. A combination of the above.