bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gravity Drainage Performance of Depletion-Type Reservoirs
Authors: Matthews C.S. , Lefkovits H.C. 
Published: December 2007

Abstract
The performance of depletion-type reservoirs at the stage in which the gas is at such low pressure that gravity is essentially the sole driving force has been investigated both theoretically and by use of scaled models. A simple theory is developed which completely explains the scaled model experiments. It also agrees with some field data.

Introduction
This investigation was undertaken to determine a method for prediction of performance of reservoirs where gravity is the sole driving agent. Depletion-type reservoirs fall into this category after the pressure has fallen to some low value. Some examples of this type are found at Healdton, Okla; Oklahoma City; Midway-Sunset, Calif.; and East Coalinga, Calif. In the past, predictions of behavior of such reservoirs have been based on empirical extrapolation of the rate of production to the economic limit. Difficulties arise when new wells are drilled in the field or when production is artificially curtailed, since in such cases the decline rate of individual wells or leases changes and no clear trend can be detected. It was hoped that the present study would lead to improved methods for evaluation of such reservoirs.
The study was initiated by building a scaled model for a particular field and by running a number of experiments on this model, Later a simple theory was developed which explained the laboratory results completely.
Numerical Modeling of Aquifer Disposal of CO2
Authors: Pruess Karsten , Xu Tianfu , Apps John , Garcia Julio 
Published: December 2007

Abstract
Disposal of CO2 from stationary sources (fossil-fired power plants) into brackish (saline) aquifers has been suggested as a possible means for reducing emissions of greenhouse gases into the atmosphere. Injection of CO2 into such aquifers would be carried out at supercritical conditions, and would give rise to the evolution of a two-phase fluid system, in which most of the injected CO2 will reside in a dense supercritical gas phase, while also dissolving partially into the aqueous phase, and reacting with native minerals. This paper presents scoping studies of the amounts of CO2 that can be trapped into the various phases (gas, aqueous, and solid) for a range of conditions that may be encountered in typical disposal aquifers. Our analyses employ a realistic fluid property (PVT) description of brine-CO2 mixtures for super-critical conditions, which takes into account real gas density and viscosity effects for CO2, and includes pressure, temperature, and salinity dependence of CO2 dissolution into the aqueous phase. The fluid property description has been incorporated into a multi-purpose reservoir simulator, and has been used to evaluate dynamic effects of CO2 injection into aquifers. A survey of minerals commonly encountered in crustal rocks was made to identify possibilities for chemical sequestration of CO2 through the formation of carbonates of low solubility. We also performed batch reaction modeling of the geochemical evolution of representative aquifer mineralogies. Results indicate that under favorable conditions the amount of CO2 that may be sequestered by precipitation of secondary carbonates is comparable to the amount of CO2 dissolved in pore waters. The accumulation of carbonates in the rock matrix and induced rock mineral alteration due to the presence of dissolved CO2 lead to a considerable decrease in porosity.
Downhole Dehydration vs. Reduction of Oil Droplet Break-Up
Authors: van den Broek W. M. G. T. , van der Zande M. J. , Janssen P. H. 
Published: December 2007

Abstract
In downhole dehydration the produced fluids – oil and water, with a low oil/water ratio – are separated at the bottom of the well by means of a hydrocyclone. In many cases this separation can be carried out successfully, because the size of the oil droplets is generally in such a range, that the hydrocyclone can remove the oil from the produced water. Potential problems are connected with the possible occurrence of very small oil droplets, because this may lead to the presence of some oil remaining in the produced water, which is unfavorable from an economical point of view and, moreover, which can lead to difficulties with subsurface injection of this water. Notably production from reservoirs with a relatively low permeability may lead to the presence of small oil droplets.
For conventional high water-cut oil production, the presence of very small oil droplets is predominantly caused by droplet break-up in the choke valve. Further downstream these small droplets determine the complexity of the separation units. It is shown that the geometry of the choke valve influences the break-up process. Consequently, by modification of the geometry of this valve it must be possible to reduce the break-up. It is expected that in this way a substantial droplet size increase can be realized.
Environmental Issues Affecting Deepwater Gulf of Mexico Development
Authors: Clodfelter C. L. , Ratliff M. D. 
Published: December 2007

Abstract
Deepwater exploration and development activities in the Gulf of Mexico have been increasing significantly over the past 5 years and the trend is expected to continue in the future. Early in 2000, the Minerals Management Service released the Gulf of Mexico Deepwater Operations and Activities Environmental Assessment Report (Deepwater EA). The Deepwater EA indentified numerous environmental issues related to deepwater operations. The Deepwater EA discussed the potential environmental concerns related to all aspects of deepwater exploration and production including seismic operations, drilling, production and transportation issues. This paper examines how environmental issues identified in the Deepwater EA will affect operations.
Hygro-Mole: A Logging Tool for Determining Moisture Content in Environmentally Sensitive Subsurface Zones
Authors: Weimer Mindy , Constant W. David 
Published: December 2007

Abstract
The Hygro-Mole's success has been proven both in the laboratory and in the Waste-management Education & Research Consortium (WERC) competition. This logging tool is designed to determine the value of low moisture content present in subsurface regions, at very low cost. The Hygro-Mole yields immediate results, and can be calibrated to specifically monitor multiple types of sub-surface material. This logging tool is a simple, non-invasive technique with virtually no waste stream, and very minimal health and safety hazards.
Professional Responsibility And The Employed Engineer*
Authors: Harwell Thomas A. 
Published: December 2007

Introduction
This paper will consider some of the legal problems arising out of the professional responsibility the employed petroleum engineer. Those problems peculiar to the independent engineer, who holds himself out as problems peculiar to the independent engineer, who holds himself out as a consultant or works under contract will not be directly considered, although some reference will have to be made to the independent engineers position since the basic principles which regulate the performance of an position since the basic principles which regulate the performance of an engineers duties are generally the same whether he is acting as an employee or independently. There appears to have been little effort in the past to hold petroleum engineers legally responsible for their activities. There are almost no reported cases involving the liability of an engineer or particularly defining the nature of his responsibility, although the dearth of reported cases does not necessarily mean the profession has been totally free of such problems. The writer is personally familiar with at least three Instances where serious claims were made against engineers by persons who relied upon their reserve estimates. On the whole, petroleum engineers appear to have been exposed to much less in the way of direct claims than have of other professions. At the same time, the relative infrequency of claims should not be taken as an indication that the situation will not change and there are, in fact, good reasons for believing one must expect more frequent attempts will be made to charge engineers and the companies who employ them with responsibility for losses suffered or thought to have been suffered as a result of their actions.
Professional Liability Insurance
Authors: Waddell James P. 
Published: December 2007

Introduction
As a layman to the petroleum engineering field I do not profess to have a complete understanding of the hazards inherent in your work. Likewise, as a layman to the legal profession, I will not attempt to predict trends in the area of Professional Liability litigation. As an insurance Professional Liability litigation. As an insurance broker, however, I can discuss what is RISK, as it is related to Professional Liability; why you, as engineers, can be held accountable for loss sustained by others; and how you can protect yourself and your personal assets through various forms of indemnification and insurance.

DUTY = RISK
The case law in the United States which defines professional liability is rooted in English common law. an properly understand the origins of this legal concept, it must be well understood that the theory of Negligence is the basis of such liability and has been an accepted legal theory since the Eighteenth Century.
A first-year law student learns in his second semester, thanks to his Torts II professor, that a cause of action for Negligence is professor, that a cause of action for Negligence is based on the following elements:A duty, which is an obligation recognized by the law;A failure to conform to a required standard, commonly known as a breach of duty;A reasonably close causal connection between the conduct of the one who owes the duty and the resulting injury; andActual loss or damage resulting to the interests of another.
The early English Negligence cases which are the basis of Professional Liability have as defendants people who held themselves out to the public as having special skills in particular fields. The plaintiffs, or injured parties, particular fields. The plaintiffs, or injured parties, in these cases usually were people having direct dealings with the defendants and suffered an alleged damage (usually monetary) because of the negligent act, error or omission of the defendant arising out of their dealings. In every case there existed a direct relationship between the plaintiff and the defendant, a contractural relationship, privity. It is this privity that was the basis for establishing the element of duty in a Negligence cause of action.
The American case law on Professional Liability continued this concept of privity up into the Twentieth Century. What this meant was that a professional was immune from suit unless there existed some sort of contractural relationship between the complaining party and himself; and therefore damages were limited to the value of the contract plus limited extra expense. With out this privity a duty could not be established. In other words, an injured third party had no cause of action in Negligence; only those party to the agreement could bring suit.
Unfortunately, this is not the legal climate today. Privity is no longer necessary to establish the element of duty in a successful suit couched in the language of Negligence.
In 1922 an important case was decided by the Court of Appeals in New York and the opinion written for that Court by Justice Cardozo.
Heat Seeking Laser Sheds Light on Tern
Authors: Woodrow C. K. , Drummond E. 
Published: December 2007

Abstract
This paper describes the deployment of an optical fibre distributed temperature system, in a well on the Tern Alpha platform, which provides a measure of temperature in the wellbore. The temperature is measured using pulsed laser optical time domain reflectometry technology. As with virtually all such ventures into the unknown utilising new technology, several surprising results have been encountered, spawning local interest in accelerating the use of this potentially useful reservoir management tool.
This paper also describes what distributed temperature profiling using optical time domain reflectometry is, what it's for, and why it adds value. The paper highlights the early data acquired from the recent deployment activities on a well drilled from the Tern Alpha platform located in the Northern North Sea.
The vision is to be able to measure the ‘health’ of the well using it's temperature as an indicator, rather than waiting for a problem to develop and have to ‘diagnose’ using ‘post mortem’ production logging activities.
Slim Hole Saga
Authors: Dupuis Dominique 
Published: December 2007

Abstract
In the early 90' s, mid 90' s, one route to minimise drilling costs was to drill Slim Hole wells.
Were assessed the geological data acquisition means in diameter ranging from 4 ¾" to 3 ⅜". Also was assessed the production limits with wells having over all 4 ¾". Those hypothesis were validated.
Drilling contractors and operators worked together, designed and built dedicated equipment, drilling rigs fit for purpose.
The industrial drilling programs took place, economic results were encouraging, it demonstrated global drilling cost decrease ranging from 30% to 50%.
After few years, Slim Hole drilling has been forgotten.
The paper will outline what has been achieved and will analyse the reasons of the complete lack of interest: economical, technical, psychological barriers.
Visualization: Game Changer, Facilitator or Gimmick?
Authors: Wright W. , Holt J. , Rezmer-Cooper I. , Minton R. , Ramshorn C. 
Published: December 2007

Abstract
Visualization: What value does it bring today, and what can it potentially bring to well construction?
Many in the industry today regard it as a gimmick that looks nice and may be good in the Geoscience domain but has no real place in the well construction arena. However, that perspective is rapidly changing.
In varying environments outside the petroleum industry three-dimensional visualization has demonstrated many diverse benefits. This paper discusses the gains realised so far and future potentially rich areas to exploit, in the framework of well construction. Visualization allows complicated geometric and computational models to be simply represented; wells can more easily be linked to the larger picture of the field. No longer is there a need to use terms that confuse all but the individual discipline experts, a picture is now available. This speeds and facilitates the communication and mutual understanding of problems and potential solutions. Discipline experts can look for creative solutions to be suggested from their extra-discipline peers, small and subtle changes are much more easily dealt with, and the exercise becomes a shared-learning experience. Teams start to appreciate what is involved in the collaborators disciplines, thereby facilitating future work in the team. Visualization enables a common language to be established for future communication amongst a multi disciplinary team. Mutual understanding and appreciation of problems can greatly enhance team performance.
Once a model of a field is created, that includes offset well data from the drilling of the wells, we have, an intuitive repository of knowledge for future well construction projects that can be used by rig-site engineers for real-time decision-making, directional drillers for assessing anti-collision risks, and a simple and effective tool for current or future peer reviews to interrogate and more easily understand historical information in the form of knowledge.
Perhaps the most powerful benefit of all for the technique is the draw that it provides to bring people together.
New Mud Pulse Telemetry Techniques for Deepwater Applications and Improved Real-Time Data Capabilities
Authors: Hutin R. , Tennent R. W. , Kashikar S. V. 
Published: December 2007

Abstract
Increasing water depth, total well depth, synthetic mud systems and increasing measurement complexity pose unique challenges for real-time data transmission via mud pulse telemetry. In deepwater environments, where the use of synthetic oil-based mud is prevalent, low water temperature significantly increases mud viscosity which reduces the signal strength at surface and makes detection of the signal more difficult. Noise within the mud channel further hinders transmission of downhole data. With rig rates approaching $350k per day and total well depths beginning to exceed 10700 m (35,000 ft), operators cannot afford to drill ahead without good quality real-time downhole data. On recent wells in deep water conditions in the Gulf of Mexico as many as seven different measurement while drilling/logging while drilling (MWD/LWD) tools have been run concurrently. Some of these tools may include the capability to produce real-time images. There is thus an increasing demand for higher data rates coupled with more reliable telemetry to transmit all this data to the surface in real-time. Recent advances in MWD tool design, signal strength prediction, and signal recovery on the surface, using advanced digital signal processing techniques, have made it possible to double telemetry data rates while also reducing error rates in the data received at the surface.
A New Method of Preventing Wear in Drilling and Combination Risers
Authors: Haberer Joseph F. 
Published: December 2007

Abstract
Multiple incidents of riser wear resulting in the loss of riser integrity have occurred worldwide in recent years. The increasing failure rate and the move to deeper water depths and longer riser systems has sparked an interest in the deepwater community to discover means of reducing wear in the riser or eventually eliminating wear completely. In response to this problem, new internally applied, welded and thermal spray coatings have been developed and tested. These new materials, when applied to the internal bore of the riser, dramatically reduced the amount of wear the riser sample experienced during the wear test in relation to uncoated riser coupons. The article outlines the goals of the tests, test parameters, and relates the findings, wear-reducing capabilities, and operational feasibility of the materials tested.
Planning and Execution of Big Bore Wells - Offshore NW Australia
Authors: Dolan S. P. , Williams G. J. , Crabtree R. J. 
Published: December 2007

Abstract
Two wells were spudded in August 1999, on the Woodside North Rankin A (NRA) gas / condensate production platform with the intention of completing them as Big Bore producers. These wells were drilled into the Perseus reservoir, which can be accessed from the NRA platform at a horizontal step out of approximately 3500m. The NRA platform is located 135km offshore from the North-Western coast of Australia.
The Big Bore well design incorporates 9.5/8" production tubing to maximise production and subsequently halve the Unit Technical Cost (UTC) of Well Construction per unit of gas production ($/MMscf/d). Larger tubing is used as production from the highly permeable reservoirs is tubing constrained with the current 7.5/8" tubing. The additional cost of a Big Bore well is 10% when compared to the cost of a comparable conventional well.
This paper will describe the Well Construction related Front-End Engineering, Detailed Planning and Execution phases. The paper does not describe work done by other disciplines such as Production Technology and Process Engineering.
In particular, detailed engineering such as casing wear, integrity issues, major tasks hazard management, extensive communication requirements and equipment issues will be highlighted.
Results and lessons learnt from the planning and execution phase are analysed with a view to future improvements in the continued development of the Big Bore well designs.
Coiled Tubing Drilling: Continued Performance Improvement in Alaska
Authors: McCarty Thomas M. , Stanley Mark J. , Gantt Lamar L. 
Published: December 2007

Abstract
Coiled tubing drilling (CTD) has thrived in recent years on the North Slope of Alaska. To date, CTD has sidetracked over 250 wells, in a continuous program of activity since 1995. In that time Alaska has become a proving ground for coiled tubing drilling tools and techniques. CTD has matured into a highly efficient and economical means of sidetracking wells on the North Slope. Key reasons for the success of the program include: continuous utilization allowing rapid learning; a culture of technical innovation; effective performance-based service contracts; the right people with the right expertise; and the vision & support of senior management. This paper will summarize the performance improvements realized in North Slope CTD operations, detailing how the tools and techniques have changed.
Applying new technologies and improving existing tools are major levers of CTD progress. Major performance improvement areas include, window milling, BHA reliability and dealing with lost circulation. Reliability improvements in equipment and persistent innovation will continue to fuel coil tubing drilling's underlying economic performance in Alaska.
Included in the paper is a discussion of the remaining problems associated with through-tubing, slim-hole drilling using CTD technology. Examples of what new CTD technologies are being used, or are about to be implemented in Alaska, will also be presented.
Operational Efficiency on Eight-Well Sidetrack Program Saves $7.3 Million Vs Historical Offsets in MP 299/144 GOM
Authors: Williams Chad , Mason John S. , Spaar John 
Published: December 2007

Abstract
This paper will describe how the operator planned and drilled an eight-well sidetrack program, including one horizontal application, in Main Pass 299/144 field, Gulf of Mexico (GOM), in record time. This achievement was accomplished by improving operational efficiency (incident free) and reaching bottom hole objectives quickly, thus reducing open-hole exposure and costly "flat" time. The authors will discuss changes in the BHA, including mud motors, AKO settings, steerable ream while drilling tools and roller cone bits in addition to synthetic mud systems, that allowed each sidetrack operation to successfully drill oversize (eccentric technology) hole and hit the directional targets in record time.
The authors will discuss why different technologies were chosen and outline successful operations. A case study will be where a 7–5/8" steerable ream while drilling system with a 4–3/4" steel tooth pilot bit was able to build from 0° to 90° in one run, a record for the area.
Finally, the authors will document, with historical offset data, how improving operational efficiency and new bit technology reduced costs by approximately US$7.3 million on the eight-well program. Analysis will include a mechanical risk index that takes into account a variety of well variables to objectively compare costs on wells drilled in GOM.