bluuebunny/crossref_metadata_2025_split huggingface dataset:
Grieve Unit - High Recovery Muddy Sand
Authors: Hurd J.D. 
Published: December 2007

Abstract
The Grieve Unit is in Natrona County, Wyoming, 35 miles west of Casper in the southeastern portion of the Wind River Basin of Central Wyoming. The producing oil reservoir is a stratigraphic trap in the Muddy sandstone which occurs on a monoclinal structure at a depth of 6,900 ft.
This Wyoming "Giant" has produced nearly 28 million barrels of oil since discovery in August of 1954 and presently ranks 20th in the State on a cumulative oil recovery basis. Over 50 percent of the oil-in-place has been recovered. by the various mechanisms including an original gas cap, gas injection, gravity segregation and a strong water drive.
Three submersible pumps are installed in downdip, high water cut wells in order to achieve the higher recovery from gravity segregation. A liquid hydrocarbon plant strips the liquids from the cycling gas production and the products are blended with 36 degrees API crude oil for increased gravity.
Forest Oil Corporation drilled the discovery well in this Muddy sand field and is the Unit Operator with nearly 95 percent working interest. It is estimated that there will be ten more years of crude oil production before gas cap gas blowdown time.
This paper reviews operations and the reservoir properties that have been estimated and calculated.
Introduction
Presentation of this paper is the result of renewed exploration activities of recent in the Wind River Basin in general, and in the Muddy sand of northeastern Wyoming in the past several years. However, the value of the paper, besides nostalgia for some, should be paper, besides nostalgia for some, should be limited to any permeable, steeply dipping sandstone of the Northern Rockies.
The qualifications of the author are that he was an under-graduate engineer 1,000 miles away during discovery and early life of the Grieve Unit and most of his reservoir work with Forest Oil has been on other reservoirs. Nevertheless, previous reports and records have been reviewed again and Forest personnel that were knowledgeable of the history of the Grieve were interviewed.
Network Model For The Study Of Multiphase Flow Behavior In Porous Media
Authors: Singhal A.K. , Somerton W.H. 
Published: December 2007

Abstract
In designing a displacement recovery process, it is desirable to have a method of predicting how the relative permeability, capillary pressure, residual oil saturation and hence the displacement efficiency will be governed by the controllable variables, i.e., viscosity ratios, interfacial tensions, contact angles and flooding rates. This paper describes a simulation procedure in which a network model for the reservoir rock is generated by the Monte-Carlo technique, using pore size distribution and structural parameters appropriate to the particular reservoir. Applying existing hydrodynamic and thermodynamic knowledge about two-phase flow in pore spaces the displacement mechanism in the porous medium is simulated. pore spaces the displacement mechanism in the porous medium is simulated. Progress of the flood is followed pore-space by pore-space over the entire Progress of the flood is followed pore-space by pore-space over the entire network model and data on the effluents from the model boundary provide information on the performance. The model has been used to study displacement behavior in unconsolidated sand packs. The model results simulate the relative permeability behavior of porous media quite satisfactorily but rather permeability behavior of porous media quite satisfactorily but rather semi-quantitatively.
Core-log Data Integration for Improved Formation Evaluation in the Dulang Field, Offshore Peninsular Malaysia
Authors: Bin Tajul Amar Zarool Hassan , Egbogah Emmanuel O. , Bin Nurdin Abdul Rahim 
Published: December 2007

ABSTRACT
One of the most challenging tasks of a log analyst is to understand log responses. In order to achieve this it is essential to establish an accurate Bulk Volume Model for the reservoir. This includes mineralogy, porosity and saturations. Unfortunately, in the case of Dulang field, log data alone cannot be used to derive accurately the Bulk Volume Model due to insufficient log data and the presence of special minerals. These minerals which affect log responses significantly are Potassium-Feldspar, Siderite and Fe-Dolomite. Dulang field is a complex shaly-sand reservoir situated 130 kilometres offshore Peninsula Malaysia.
This paper illustrates how results of core analysis have helped us understand log responses in the Dulang field. A special core recovery program was carried Out in three wells, namely, Dulang-A17, B20 and B21, which penetrated all the major reservoirs that contributed the bulk volume of STOIIP in the Dulang field. A low toxicity oil-based mud was used in well Dulang-B21 to establish accurately the connate water saturation for quantitative calibration of log derived parameters. A bland water-based mud was used in the other two wells to preserve the rock wettability. The results of the core analysis enabled us to better refine our petrophysical model of the reservoir which led to a more accurate computation of reserves.
Components of core analysis used in this study are Fourier Transform Infra-Red spectroscopy, Core Layering and conventional core measured petrophysical parameters (porosity, permeability, grain density and saturations).
Inflow Performance Relationship For Perforated Wells Producing From Solution Gas Drive Reservoir
Authors: Sukarno Pudjo , Tobing Edward L. 
Published: December 2007

Abstract
The IPR curve equations, which are available today, are developed for an open hole wells. In the application of Nodal System Analysis in perforatedwells, an accurate calculation of pressure loss in the perforation is very important. Nowadays, the equation which is widely used is Blount, Jones and Glaze equation, to estimate pressure loss across perforation. This equation is derived for single phase flow, either oil or gas, therefore it is not suitable for two-phase production wells. In this paper, an IPR curve equation for perforated wells, producing from solution gas drive reservoir, is introduced. The equation has been developed using two phase single well simulator combine to two phase flow in perforation equation, derived by Perez & KeIkar. A wide ranges of reservoir rock and fluid properties and perforation geometry are used to developed the equation statistically.

Introduction
In the application of Nodal System Analysis, perforation is an important component in a well production system. Different perforation technique, different perforation length and diameter yield different well productivity and at the end of the analysis yield different cost and revenue. Therefore, optimization is needed to choose the "right" perforation technique and geometry. In Nodal System Analysis, a good equation of flow performance inperforation, is needed. An equation that suitable to the well conditions. Blount, Jones and Glaze had derived an equation to predict flow performance inperforation for single phase flow (gas or oil). Therefore, the equations are not applicable for wells producing gas and oil (two-phase wells), such like a well producing from solution gas drive reservoir. Perez & Kelkar had derived an equation to predict two-phase pressure drop across perforations. In the application, this equation need information of oil relative permeability atcrushed zone, as well as number of perforations, perforation size and length, viscosity and formation volume factor of oil, pressure at crushed zone and pressure at perforation. Therefore, for practical purposes, Perez & Kelkar equation should be combined with other method which gives the value of oil relative permeability, and the pressure at crushed zone and perforation. In this paper, a two-phase single well simulator is used to prepare the oil relative permeability data, at certain production conditions. The well productivity performance usually is represented by Inflow Performance Relationship (IPR) equation. All of those equations, which are available today, do not consider the effect of perforation. In this paper an IPR equation, which is consider the effect of perforation technique and perforation geometry, is proposed.
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Ecuador Strategic Alliance Project: A Case History
Authors: Peery M. D. , Thomson C. L. 
Published: December 2007

ABSTRACT
The alliance contract is a new project management approach that can obtain improved contractor performance on large drilling, completion and production projects. Under the arrangement known as the Ecuador Strategic Alliance, Oryx Ecuador Energy Company entered into a single contract with Baker Hughes INTEQ, an integrated service company, which assumed many duties previously handled by the operator. Services covered 15 wells in Block 7, located in the Oriente region, Ecuador. (See Figure 1) Included in the contract as alliance partners were several other service companies. This management approach is believed to be unique in the industry in that the alliance of competitive companies agrees by contract to manage and execute the entire program, making decisions that will benefit the program without regard to the source of products and services. No dedicated operator representative is resident at the site. In this approach partners in the alliance must manage to achieve best results in order to receive incentives upon successful completion of contractual milestones. The paper reviews salient points of the alliance working arrangement, covering responsibilities of the various service companies and management methods used in the successful achievement of program objectives. Operational and economic results of the arrangement are described over a period of operation in which the first 13 wells were completed.
Organisation, Integrity, Learning—The Keys to Success in Well Construction
Authors: Thorogood J. L. 
Published: December 2007

Abstract
New contracting styleshave placed increased demands on service companies, contractors and operators alike. As the service sector professes a willingness to "take on more responsibility", so operators are faced with the challenge of taking up this offer. With responsibility goes risk, but the burden of risk must be rewarded.
Do service companies really want more responsibility, and thus, accountability or merely to be "involved" in a diffuse, multi-disciplinary way? If, indeed they want to take responsibility then, before it can be transferred, and the discussions on risk and reward begun, the question to be asked is, "If I give my contractor responsibility, will he let me down? Am I running an unjustifiable risk? What will happen to my reputation if something goes wrong?" In a traditional oilfield, responsibility could be transferred quite informally by relying on the fruits of personal relationships and trust. But in the contemporary oilfield, with large organisations and impersonal quality systems, a risk-free transfer is less easily achieved.
Cost reduction is the main driver behind these changes. Cost reduction without technical integrity will create serious risks. Responsibility is transferred by getting the operator and contractor to work together in a logical and structured way. The end result is a relationship where the operator can confidently delegate work to a contractor that has demonstrated his capabilities. A model is presented that provides a check-list for five aspects of a contractor's work: his organisation, logistics and his capability to design, execute and continuously improve his performance. This new role will require structural changes inside the service companies, development of a culture of Technical Integrity and development of the habits of Performance Measurement and Continuous Improvement.
Steps Towards a Comprehensive Reeled Tube Drilling System
Authors: Faure A. M. , Oosterling Peter , Lord D. J. , Vuuinghs Pieter , Brinkhorst Jan 
Published: December 2007

ABSTRACT
The oil industry is facing the challenges of reduced margins with respect to optimization of mature field and development of marginal discoveries. In this context conventional approaches are reaching their limits and a step change is required.
The first oilwells were drilled using the cable tool method. The Rotary drilling revolution was introduced in 1901 and became firmly established in 1920. Since then the industry has been dominated by the reign of the 30 ft. joint. Replacing jointed pipes by continuous reeled tubes could indeed become the next step change. A visionary Reeled System (RS), including drilling umbilicals, casing, tubing and pipelines could improve the economics of hydrocarbon development projects. RS could reduce costs, enhance quality, broaden technical abilities and improve well productivity.
An all around RS does not exist and the intention is not to build one from scratch. However, Coiled Tubing (CT) is presently the nearest thing to the reeled tube vision. Recent experience prove CT can be used for drilling, completions and flowlines and its envelope of application is rapidly expanding.
It is proposed to build a global alternative to jointed pipes by gradually improving the technical abilities of the existing CT system. Pieces of the giant jigsaw puzzle are already in place. Others are still at the conceptual stage while some are still barely visible. Reeled System Technology (RST) will evolve at its own pace driven by market forces, technology innovation and most importantly attitude change. Rather than a mere technical improvement this technology authorizes new strategies for hydrocarbon exploitation.
Drilling Performance Predictions: Case Studies Illustrating the Use of Risk Analysis
Authors: Peterson S. K. , Murtha J. A. , Roberts R. W. 
Published: December 2007

ABSTRACT
This paper presents two predictive drilling performance models, using two dissimilar case studies to illustrate some of the appropriate techniques for developing such models. Both case study models utilize risk analysis and incorporate Monte Carlo simulation and statistical analysis of historical drilling data to generate more representative, risked, AFE estimates. The first model was developed for a development well in a mature area. The second case study, for a rank wildcat, incorporates limited "nearby" well data and historical data pertaining to analogous exploration wells, and demonstrates the usefulness of a large database from which we can draw representative distributions.
Results Oriented Strategies in Well Engineering Operations
Authors: Jackson J. R. , Avocato N. S. 
Published: December 2007

ABSTRACT
Chevron UK Limited (CUK) implemented a performance driven strategy commencing in 1991 based upon core alliance agreements enabled by metrics, benchmarking, and operational scanning to optimize well engineering and operations (WEO), all organized around a set of core processes. This strategy was initiated in response to new field developments, continued operations in mature fields, and the maturing of the North Sea as a producing area with emphasis on performance and cost management. It was implemented over a period of four years for the core competencies of WEO including well construction (WC) (drilling) and well management (WM) (workovers). The results of this strategy will be reviewed.
Deep, Directional Platform Drilling: Problems and Solutions
Authors: Wallen G. L. , Striedel C. M. 
Published: December 2007

ABSTRACT
Attention to detail and the utilization of operational techniques that have been around since the 1960's and 1970's have resulted in the drilling of directional platform wells over 18,000 feet deep, with 40-45 degrees of angle, in just 23 days from spud. Although this paper discusses deep, platform drilling, the techniques are basic and they have a broader utility to a range of drilling applications in other areas, on land and offshore. This paper demonstrates the importance of staying operationally and mechanically simple when executing sophisticated, deep, directional well plans.
Enhancing the Safety and Reliability of Subsea Drilling Operations by the Use of ‘Routine’ Case Operating Envelopes
Authors: Burton K. , Ferguson G. , King G. W. 
Published: December 2007

ABSTRACT
A major UK JIP has recently been completed, its purpose being to identify appropriate limits within which subsea drilling operations can be performed. One of the main deliverables from the JIP has been acceptable Operating Envelopes for ‘routine’ case subsea drilling operations. This paper presents a definition of what constitutes a ‘routine’ case drilling system; typical operating envelopes are also presented. Application of this information wil I greatly reduce the requirement for case-specific analysis of subsea drilling operations; indeed, the intention is that for ‘routine’ case operations, the need for analysis will be completely eliminated. The data contained in this paper forms the basis of a forthcoming UK Institute of Petroleum Guideline publication.
Drilling Performance Improvements Using Downhole Thrusters
Authors: Reich Matthias , Hoving P. G. , Makohl Friedhelm 
Published: December 2007

Abstract
Thrusters generate weight-on-bit by using drilling fluid hydraulics. The pump-open behaviour of thrusters de-couples the lower part of the bottom hole assembly from the remainder of the drillstring, and in so doing provides a constant, controllable weight-on-bit (WOB) that dampens out axial vibrations and shocks.
In more than one hundred and twenty jobs, thrusters have proven their ability significantly to improve drilling performance in holes with vibration- or shock-related problems. The technique has been used to increase overall penetration rates and bit lives, improve steerability and reduce downhole failures in hole sizes from 12 1/4" to 3 7/8" diameter, in both horizontal and vertical wells, and at depths to ~5400 m (1650 ft.). The system has been used mainly on fixed rigs, but also on floating rigs, substantially reducing cost per foot.
As the thruster interacts with other hydraulic components of the drillstring (bit, mud motor, restrictor subs, MWD pulser), the proper tuning of the drilling system is required to obtain optimum performance. This paper shows the function and principle of thrusters, it explains possibilities and limits for their use, and details criteria for the optimum thruster in certain applications. Detailed field data from 4 wells in 4 geological areas are presented.
Environmental Studies For A Proposed Arctic Marine Terminal
Authors: Ranft Fracis E. , McCollom Robert L. 
Published: December 2007

Abstract
Investigations are presently underway to determine the suitability of several areas along the Arctic coastline as potential sites for petroleum storage and marine terminal facilities. The broad, shallow shelf along the Alaskan Arctic coast presents considerable engineering design problems for the construction of a marine terminal which would accommodate deep draft tankers; however, several suitable sites appear to be present along the Canadian Arctic coast.
In the Spring of 1969, a field investigation was conducted at Herschel Island, Canada near the Mackenzie Delta to determine if subsurface conditions and other environmental factors are favorable for possible development of marine terminal facilities.
Deep water access to the island is provided by a submarine canyon which comes provided by a submarine canyon which comes to within a few miles of the shoreline. A natural deep water basin, probably formed by glacier-ice thrusting, exists immediately adjacent to the protected harbor at Thetis Bay on the south side of the island. A submarine ridge consisting predominantly of clays and clayey silts separates the submarine canyon from the deep water basin.
Herschel Island with its protected harbor and natural deep water basin offers some distinct advantages over other potential sites. The only major drawback appears to be the necessity of dredging a channel to connect the deep water basin with the submarine canyon. To a large extent economic considerations will determine the feasibility of utilizing Herschel Island as an Arctic marine terminal in the future.
Introduction
Technical and economic feasibility studies are being conducted to determine methods by which the recently discovered crude oil and gas reserves of Prudhoe Bay and the Mackenzie Delta can be transported to the major market areas of the eastern and mid-western united States. Some of the plans being considered include:
A Trans Alaska pipeline from Prudhoe Bay to Valdez, Alaska which would connect by conventional tanker with a Trans United States pipeline extending from terminal facilities pipeline extending from terminal facilities in Puget Sound across the Cascades and Rocky Mountains to the eastern markets;
Ground-Water Flow Systems and Underground Nuclear Testing
Authors: Fiero G.W. , Maxey G.B. 
Published: December 2007

Abstract
Ground water is the only possible transport vehicle of radioactive contaminants released by an underground explosion. Consequently, safety considerations require an accurate determination of the ground-water flow directions and velocities in the vicinity of the nuclear detonation.
Recent advances in knowledge regarding ground-water flow systems have created new theoretical models to describe the nature of ground-water movement. Many of the physical parameters which are involved in parameters which are involved in ground-water movement also control the movement of other subsurface fluids. Consequently, oil and gas stimulation experiments may be better predicted by an understanding of predicted by an understanding of current ground-water concepts.
Ground-water flow in the vicinity of an underground nuclear explosion may be divided into the preshot (natural) and postshot (induced) systems. Several examples of these systems and their relationship to radionuclide dissemination are given. A thorough knowledge of the system is necessary for each unique location of an underground nuclear explosion.
Introduction
The only possible transport vehicle of radionuclides generated by an underground nuclear explosion is ground water. In order to determine the concentrations of the radioactive material in space and time, the velocity and direction of ground-water movement must be known.
Learning to Learn
Authors: Keon Billy V. 
Published: December 2007

Abstract
It is estimated that an engineering student will be technically obsolete from 5–10 years after he graduates if he does not continue to learn after graduation. A new teaching strategy, Self-Paced Instruction, has recently been applied to engineering courses. This technique has the advantage that it teaches a student to learn for himself as well as giving him the technical content of the course. On the basis of our experience to date, this method is a great success as judged by student learning, motivation, and enjoyment.
Introduction
Due to the probable technical obsolescence of a student who fails to continue studying after graduation, one of the primary responsibilities of modern engineering education is to design the classroom environment to encourage the student to enjoy learning. If this is successfully achieved, psychology indicates that the student will naturally gravitate toward a continuation of his education after his formal studies are completed. Modern learning theory has developed a teaching strategy called PSI (personalized or proctorial system of instruction) in which a positive attitude toward learning as well as specific "learning skills" are developed without sacrificing coverage of course material. PSI was applied at The University of Texas in a senior engineering course.