bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Steel Tooth Cutting Structure Breaks Multiple Records in Australasia
Authors: Bunton Steve , Sim Natalie , Grimes Bobby 
Published: September 2008

Abstract
Approximately 90% of the large diameter holes in Australasia (Indonesia, Australia, PNG and New Zealand) are drilled with steel tooth roller cone bits. A new steel tooth bit design has proven to significantly improve the drilling economics in these applications. This paper describes the drilling challenges posed by these applications, details the new bit design features, and presents case studies showing the performance improvements these new bits provide when compared with conventional steel tooth bits.
The new design bits feature a novel cutting structure with pyramid-shaped teeth, additional rows of teeth, wide grooves between rows, anti-tracking row(s) with tight pitches, thick hardfacing deposits, and a bar trimmer type gauge design. The result is a steel tooth bit that delivers significantly higher ROP and longer life than current designs, with high reliability, and predictable steering behavior for directional applications. Hole sections can often be completed with fewer bits, which further improves drilling economics. These bits achieve ROPs faster than even that of large diameter PDC bits in the Australasian applications, thus the reason that steel tooth bits are primarily used.
An operator in Balikpapan, Indonesia drilled a long S-shaped hole with a new 17 1/2-in. steel tooth bit at 40% higher ROP than the best of nine direct offsets that were drilled with conventional steel tooth bits. Another operator offshore Western Australia conducted a head-to-head comparison of a new 16-in. steel tooth bit against a conventional steel tooth bit in identical hole sections. The new bit drilled over 70% faster and over 25% farther than the regular bit. A third operator in the Northwest Shelf area off Western Australia employed a new 17 ½-in. steel tooth bit to complete a section normally drilled with 12 ¼-in. PDC bits. The new steel tooth bit drilled over 25% faster than the fastest PDC offset run. Additional case studies will be presented further documenting these positive field results.
Avoid Downhole Explosions, Buckled Pipe and Parted Tubing During Snubbing Operations
Authors: Duncan Grant J. 
Published: September 2008

Abstract
Snubbing involves the running of tubing and related completion equipment into a well while pressure is present at the wellhead. This operation requires the use of specialized equipment that provides control of well pressure and associated fluids at all times, and enables the movement of tubulars and equipment into and out of the well.
Petro-Canada chose to create their own snubbing guidelines, and share them with industry, because of situations being encountered that were not adequately described in published recommendations and regulations. The Petro-Canada Snubbing Guidelines are intended to compliment, rather than replace, Industry Recommended Practices on snubbing.
Petro-Canada's Snubbing Guidelines contain the following information: Written guidelines, providing information on snubbing and well control equipment, safety requirements, snubbing procedures, and contingent operations.A procedure for preventing downhole explosions when pulling plugs.Pipe buckling calculations, as related to wellbore pressure.Allowable tensile loads, as a function of internal and external pressures.A snubbing operations checklist.
This paper addresses i) avoiding downhole explosions, ii) preventing pipe buckling in pipe-light situations, and iii) allowable tensile loads as a function of internal and external pressures.
Oil-Based Foam and Proper Underbalanced-Drilling Practices Improve Drilling Efficiency in a Deep Gulf Coast Well
Authors: Sepulveda J. J. , Falana O. M. , Kakadjian S. , Morales J. D. , Zamora F. , Dibiasio M. A. , Marshall E. , Shirley G. , Benoit D. J. , Tkach S. A. 
Published: September 2008

Abstract
A recyclable oil-based foam drilling fluid (OBFDF) system has been developed to expand the benefits of controlled pressure drilling with foam onto water sensitive formations. This paper describes chemical development and presents drilling results for a Gulf Coast well drilled with the oil-based foam system. Not only did results confirm the ability of the foam system to control fluid loss and preserve formation permeability, but also, show the advantages of drilling with foam. Furthermore, a bit trip was saved drilling the reservoir in a single bit run, with a high rate of penetration and reduced gas inflow while drilling. The OBFDF is versatile, stable at high temperature (up to 450°F), compatible with H2S scavengers and reusable. Foam properties were successfully adjusted in presence of gas and condensate inflow. Still, the flexibility of foaming, defoaming and refoaming allowed surface separation and fluids reuse. Therefore, recycling liquid make up hydrocarbon reduced fluids and chemical usage with the associated cost reduction. Onsite modeling showed the controlled pressure contractor modeling software used for water-based foams can be adjusted to properly predict drilling parameters with oil-based foams.
Overcoming Challenges during the Development and Installation of Intelligent Completion Systems in SRI Wells
Authors: Joseph Paul , Going Walter , Eriksen Frank , Hughes Baker , Vinje Lars , Berland Helge 
Published: September 2008

Abstract
In this age of multi-zone and multilateral wells, existing technologies are always challenged to achieve desired results. In the case of Statoil Skinfaks/Rimfaks (SRI) wells, capabilities of intelligent completion systems were stretched to the limit. Some of the challenges included depth, system optimization, feedback monitoring, subsea logic, placement of downhole hydraulic logic switches, hydraulic timing, cross flow design due to limited control lines, development of an auxiliary logic switch, etc. Operational requirements also pushed downhole tools like the flow control valves and logic switches in a novel and previously untried configuration. System operation logic mandated the design of a very complex hydraulic circuit.
Cross flow design with limited control lines proved to be a significant challenge. Each of the wells had three zones to be controlled. The existing subsea trees allowed only three hydraulic control lines. Three balanced piston flow control valves normally require at least four control lines to be operated. A new system was to be developed to be able to control all three balanced piston valves with only three hydraulic control lines.
This paper will present how a combination of analytical modeling, simulation and laboratory testing was used to overcome these and other design challenges during the system development phase. This novel methodology will aid the optimization and reduction in design cycle time of future intelligent completion systems. Four wells in the Statoil Skinfaks/Rimfaks Improved Oil Recovery Project were completed with intelligent systems in 2007. Thorough planning and execution yielded higher operational efficiency which resulted in job completion ahead of schedule. The installation phase will be discussed in the paper with special emphasis on pre-job planning, operational procedures, post-job results and lessons learned.
Polymer Flood Modeling Using Streamlines—Part 1
Authors: Thiele M. R. , Batycky R. P. , Pöllitzer S. , Clemens T. 
Published: September 2008

Abstract
The successful design of a polymer flood relies on the ability to properly model the distribution of polymer concentration in the reservoir while accounting for effects on fluid properties such as water viscosity increases as a function of in-situ polymer concentration and loss of polymer due to adsorption. Despite advances in numerical techniques and computer hardware, the numerical modeling of polymer floods using Eulerian-based approaches such as finite differences remains a challenge: coarse grids tend to excessively smear concentration fronts masking the true benefit of polymers, yet introducing finer grids inevitably leads to excessive run times that make using modern reservoir engineering workflows unrealistic. This problem was already outlined in 1978 by Lake et al.. We revisit the same problem 30 years later in the context of modern streamline simulation techniques.
In this work, we present the extension of modern streamline simulation to field-scale polymer flooding, which represents a step-change from the hybrid, 2D steady-state models used in the 1970's. We apply the well-established numerical modeling of polymer flooding to captured the displacement efficiency in 1D, and couple it with a three-dimensional (3D) streamline simulator to efficiently capture the inter-pattern sweep efficiency caused by well rate imbalances, reservoir architecture, and reservoir heterogeneity. Because modern 3D streamline simulators account for changing well rates, non-uniform initial conditions, and gravity, adding polymer functionality means that real-field polymer floods can be modeled with sufficient confidence to be useful and with the necessary speed to be used for modern reservoir engineering workflows that center on assessing uncertainty and risk associated with design parameters.
In this paper we proceed to outline the basic architecture of a streamline simulator with a polymer option. We discuss streamline-specific issues, such as the data that must be exchanged between the Lagrangian streamline grid and the underlying Eulerian grid to allow streamlines to be updated as production/injection conditions change. We discuss advantages and disadvantages of the formulation and present numerical experiments in 1D, 2D, and 3D to illustrate our results.
Erosion Study for a 400 MMcf/D Completion: Cannonball Field, Offshore Trinidad
Authors: Healy J. C. , Martin John , McLaury Brenton , Jagroop Raynald 
Published: September 2008

Abstract
The Cannonball Field is a one Tcf gas condensate development offshore Trinidad producing at a sustained rate in excess of 800 MMcf/D from three wells. The completion design selected was 7⅝ inch production tubing with an open-hole gravel pack. The initial well (CAN01) has produced at 333 MMcf/D. These rates are higher than typically experienced which has raised concerns concerns about the resultant potential for metal erosion. As a result, a rigorous erosion study was initiated. The objective was to quantitatively evaluate erosion at various rates over the life cycle of the well to appropriately design the completion and select the appropriate materials.
The erosion nodes within the completion - changes in flow direction (e.g. a tee such as in the wellhead) and/or flow constrictions - were identified as: the tree; a landing nipple profile near the surface; and a formation isolation device (FID) positioned in the gravel pack assembly. The key parameters were defined as particles of sharp sand, with a diameter of 50 microns, at a concentration of 0.1 lbs/MMcf. Erosion rates were calculated using the erosion model - Sand Production Pipe Saver (SPPS) - developed by the Erosion/Corrosion Research Center, University of Tulsa, USA. Erosion rates were calculated over the life cycle starting at initial rates of 280 and 400 MMcf/D. Erosion rates were also calculated with and without a liquid film (a protective layer on the pipe wall that can reduce the erosion rate). Erosion results (without a liquid film) at all nodes exceeded BP's erosion limit; however, the erosion results with a thin liquid film were mostly below the company's erosion limit. Determination of the presence and thickness of the liquid film was critical. A multi-phase pipeline simulation calculated that a sufficient liquid film would exist at all critical areas. Erosion of the tree was further assessed by computation fluid dynamics (CFD) models, which identified several hot spots; thus, additional cladding of all flow-wetted surfaces and rounding of the outlet corner was required. The Cannonball completion design, including the tree, was determined to be capable of sustained rates up to a maximum 400 MMcf/D. The three (3) well development, where initial rates have been as high as 333 MMcf/D, has been on production for several years without any erosion issues.
Prediction Onset and Dynamic Behaviour of Liquid Loading Gas Wells
Authors: Belfroid S. P. C. , Schiferli W. , Alberts G. J. N. , Veeken C. A. M. , Biezen E. 
Published: September 2008

Abstract
As reservoir pressures decrease in maturing gas wells, liquid drop-out forms an increasing restriction on gas production. Even though virtually all of the world's gas wells are either at risk of or suffering from liquid loading, the modeling of liquid loading behavior is still quite immature and the prediction of the minimum stable gas rate not very reliable. Many wells start liquid loading at gas rates well above the values predicted by classic steady state prediction models such as Turner. The loading point is strongly dependent on inclination angle, flow regime transitions and the interaction between tubing outflow behavior and the reservoir IPR. In the paper, the behavior of different natural gas wells and of an air-water test setup are analyzed. Simulations were performed using both commercially available software and dedicated dynamic models. The onset of liquid loading and the dynamic behavior of a flooded well during a restart were predicted. These were then compared to actual production data. The influence of the reservoir parameters and of the tube inclination were of special interest.
The influence of dynamic disturbances on the stability are not taken into account by the classic prediction models. Systems with high permeable reservoirs are less able to cope with disturbances. This leads to higher critical rates for those systems. This corresponds to data from field observations. A maximum in the critical velocity is observed around an inclination of 50° with a critical rate 40% higher than for a vertical well. To solve this, relations found from flooding experiments are used to modify the current prediction models. Based on the current work an adaptation to the Turner equation, which takes the inclination effects into account, is proposed. For the observed natural gas wells and for the air-water experiments the modified Turner equation predicts the observed loading points within 20% accuracy.
A Compliance-based Approach to Well Integrity Management
Authors: Wallace Gary , Kiddie Neil , Kearns John , Robinson Peter 
Published: September 2008

Abstract
This paper describes a process for actively managing well integrity throughout the development life cycle with a particular focus on the production operations / well maintenance phase. Although developed in relation to ConocoPhillips UK North Sea development wells, most of the features of the process have application to all development well operations (both onshore & offshore) under any regulatory regime.
The original well integrity management process was developed in order to demonstrate compliance with the UK Offshore Installations & Wells (Design & Construction, etc) Regulations 1996 (DCR). Since that time the original process has continued to be modified to improve effectiveness & efficiency. As well as describing the current process, this paper also describes its development and how we see that the process might evolve in the future.
DCR regulations form a part of the UK ‘safety case’ regime. The ‘safety case’ regime places a strong focus on the development of site-specific performance standards; it also utilises the principles of independent examination & verification in order to demonstrate compliance. The process described in this paper represents a significant new contribution to the management of major accident hazards in well operations since it focuses on the use of performance standards and independent examination in order to ensure well integrity.
Application of Membrane Filtration Technologies to Drilling Wastes
Authors: Oluwaseun Olatubi , Burnett David , Roy Hann , Haut Rich 
Published: September 2008

Abstract
The Environmentally Friendly Drilling (EFD) program is taking a renewed look at dealing with the issue of waste management and re-use particularly with regards to produced water and water based drilling wastes, developing solutions that would possibly reduce the size of reserve pits needed in drilling operations and achieve significant waste volume reduction through the extraction of water from drilling wastes encouraging reuse of the extracted water in drilling operations and the concentration of suspended solids.
The EFD is investigating the use of membrane-filtration technologies in the aforementioned aim of waste volume reduction and water extraction from drilling wastes. The investigation involves processing actual drilling wastes using various membrane types and configurations in developing solutions to challenges facing membranes particularly fouling. We are investigating the ability of these membranes to effectively remove the suspended solids from waste streams and refine the waste to levels where they could be used in drilling operations or sent for further treatment such as desalination. Our aim is to develop a mobile treatment unit made of a suitable membrane system that could be deployed to drilling sites to be used as an onsite option aimed at recycle or re-use of water resources.
We are currently investigating in our laboratories various membrane-filtration technologies with water based oilfield wastes and coupling this with our prior development of field deployed technologies in developing a cost efficient membrane filtration system for field application. We show in this report how membranes have been used in the filtration of actual solids laden field supplied water based muds and a solids simulated laboratory water based mud, highlighting the compatibility of membrane systems with water based muds.
In light of the evolving stringent regulatory standards and in demonstrating good stewardship of the environment, the Oil and Gas industry is expected to be active in reducing the footprint of its various activities on the environment and in showing optimal use of resources. This approach to dealing with drilling wastes confers the two-fold advantage of optimal use of water resources through re-cycle and the reduction of the footprint of drilling operations well within reasonable economic costs by saving significant waste treatment, hauling and freshwater costs.
Case History Review of the Application of Pressure Transient Testing and Production Logging in Monitoring the Performance of the Mars Deepwater Gulf of Mexico Field
Authors: Weiland Jeffrey , Azari Mehdi , Fox Phil , Dorffer Daniel 
Published: September 2008

Abstract
Proper characterization of a producing well has significant impact on asset management. Production schedules from different wells and further infill drilling in a field depend on the effectiveness and the pattern of the production drive mechanism. Whether the reservoir displays partial aquifer influx or is waterflooded, the flow profile of produced/injected water as well as the reservoir pressure, permeability, fluid saturations, and formation compaction are useful to properly evaluate the overall sweep efficiency. This information is more crucial in a field with multi-layered reservoirs having different permeability, pressures, and structure. Data acquisition should be scheduled and compared to baseline data such as a baseline pulsed neutron capture, production, or compaction logs. There should also be plans to monitor specific wells over the life of the project to observe and optimize the reservoir performance, characterize the reservoir response, and in the case of waterflooded reservoirs monitor the performance of the waterflood. Multi-rate multi-zone production logging and pressure transient testing are two excellent methods to achieve these goals.
IMESAFR: A New Tool for Wellsite Explosives Safety Assessment
Authors: Leidel D. J. 
Published: September 2008

Abstract
Many industries have begun to utilize the tool of probabilistic risk assessment to quantify the risks of personnel fatality and injury from possible equipment failures, human error, or personal exposure to hazardous material. The U.S. Department of Defense Explosives Safety Board, (DDESB), recognized the need for a software package, (termed SAFER), that could quantify the risk to related and unrelated personnel as a result of operations involving ammunition items. Recently, the Institute of Makers of Explosives, (IME), completed a project to develop a new version of risk assessment software for the commercial explosives industry. This software package termed IMESAFR can be applied to perforating gun loading shops, wellsites and storage facilities to assess quantitatively, the risk to operating personnel and the public as a result of these types of operations.
Heretofore, the only tool available for siting commercial explosives operations was the American Table of Distances, (ATD), which is limited to establishing the distance of a specific explosive storage magazine or manufacturing building with respect to a limited number of inhabited buildings, public highways, passenger carrying railways and other explosive storage magazines. One underlying assumption in the ATD is that the tables are intended to be applied to "exposures in rural areas", rendering the distances that the ATD prescribe unsuitable for multiple exposed sites occupied by a large number of people. IMESAFR permits a more in-depth evaluation of the risk to include such factors as multiple exposed sites to the explosives operation, the amount of time persons are exposed to the explosive operation, the type of explosive, and the nature of explosive operation in process, which significantly affects the probability of fatality or injury as a result of an unplanned explosives event.
This paper describes the IMESAFR Software, and its development, in particular, describing examples where it can be applied to the upstream oil and gas industry.
Probabilistic risk assessment is a very powerful tool to assist planners in siting operations involving oilfield explosives and to inform the operator of expected risk levels in situations where separation distances may be limited.
Modeling of Inversion Point for Heavy Oil-Water Emulsion Systems
Authors: Ersoy G. , Yu M. , Sarica C. 
Published: September 2008

Abstract
As the world's demand for oil increases, more heavy oil reservoirs are being discovered, drilled and produced. However, heavy oil production brings new challenges. One of the challenges is the formation of emulsions. Emulsions can cause high pressure losses, resulting in transportation and pumping problems and separation. The inversion point, at which continuous and dispersed phases in an emulsion changes, needs to be studied to improve knowledge of heavy oil-water emulsions.
A new mathematical model was developed in this study using fundamental thermodynamics and conservation of mass laws to predict the inversion point of an emulsion system. Simulation results indicate that the properties of surfactant, emulsion droplet size and standard chemical potentials of the liquid phases play very important role in controlling the inversion point of an emulsion system. The model proposed in this paper can help predict inversion point of an emulsion system. Estimation of inversion point of emulsions helps improve the existing emulsion viscosity correlations and develop new models when necessary. The improved heavy oil-water emulsion viscosity models can be used in design and operation phases of heavy oil fields.