bluuebunny/crossref_metadata_2025_split huggingface dataset:
Design of Fibre-Optics Based System for Monitoring of Structural Safety in Drilling Rigs
Authors: Thakur A. K. S. 
Published: December 2007

Abstract
Structural safety of drilling rigs is a matter of major concern for operators. In spite of best industry practices a number of mishaps occur, sometimes taking heavy toll on investments and human lives. At times marine environment is also endangered due to accidents on offshore rigs. The paper presents a system design for altogether a new class of online monitoring system based on optical fibre technology for total rig structure providing ample opportunity to take pre-emptive action for averting mishaps arising due to metal fatigue and excessive overloading. The system will be very useful in the inspection and testing of new rigs. The system finds application in periodic preventive and corrective maintenance and would reduce the inspection time and expenditure. Such a system gains more importance on account of emerging trends in "re-qualification" of offshore drilling rigs.
A New Electronic Firing Head for Slickline Explosive Services
Authors: Taylor Nick , Guevara Juan , Sabine Cedric 
Published: December 2007

Abstract
Using traditional slickline methods, it has not been possible to initiate chemical cutters, detonate perforating guns or any other explosive device, without using a preset pressure or temperature tool. These devices require a survey run and rely on well conditions remaining the same during the live perforating run. Once inside the preset operating window, the firing process is automatic. With these devices, the operation cannot be aborted unless the tool is removed from the operating window or the operating parameters are changed.
A new firing head has been developed that eliminates the parameter-gathering run and gives the operator total control, similar to that in electric-line perforating. This results in a safer operation that allows arming, firing and aborting the operation. The firing head uses field-proven technology and a slickline movement sensor. Safety is also improved by eliminating primary high explosives.
This paper covers the development of the firing head, from initial idea to field introduction, and includes discussion on operation and safety features. The case studies describe the first commercial operations in a southern North Sea field.
Coalbed Methane in the Illinois Basin: Development Challenges in a Frontier Area
Authors: Lombardi Tracy E. , Lambert Stephen W. 
Published: December 2007

Abstract
Coalbed Methane (coal gas) is in its second wave of development in the United States. Twenty years ago, it was an unconventional gas play most operators stayed away from. It grew however to be one of the hottest plays of the early 1990’s. The development of successful coal gas fields has come as a result of favorable economic conditions, but also due to strong cooperative efforts among industry and research and development organizations in sharing technical information and experience, and designing research projects specifically geared toward technical issues. During this first wave of development numerous areas containing substantial coal gas resources were left undeveloped. These frontier areas in the lower United States have been estimated to contain over 677 Tcf of coal gas.
The Illinois Basin is still considered a frontier area. The basin was formally evaluated for its coal gas potential in 1979, at which time the amount of Pennsylvanian-age coal was estimated at ~365 billion short tons, having a potential in-place coal gas resource of up to 21 Tcf. However even with such a large potential coal gas resource, only small areas within the basin have seen exploration programs during the past 20 years. Methane gas has been produced from wells drilled into abandoned coalmines in the past providing an energy resource for local uses, but less than 35 actual coalbed gas wells have been drilled in the basin through December 2000.
The Illinois Basin encompasses approximately 53,000 mi2, and is in close proximity to numerous large gas storage fields and gas markets. Having a long history of hydrocarbon activity, the basin contains a well-developed interstate pipeline infrastructure. What are the main factors hindering coal gas exploration in the Illinois Basin? What are the technical challenges that operators have yet to overcome? Will a coordinated basin-wide industry / research effort required to develop more confident estimations of this resource?
This paper focuses on these questions by addressing, the current perceptions of the coal gas resource, the historic and current exploration activity, and the mechanisms effecting coal gas development. As a result, the current technical challenges facing operators are identified. Opportunities to participate in the collection and evaluation of comprehensive reservoir characterization data sets in the basin are presented.
Identifying Best Practices in Hydraulic Fracturing Using Virtual Intelligence Techniques
Authors: Mohaghegh S. D. , Gaskari R. , Popa A. , Ameri S. , Wolhart S. , Siegfried R. , Hill D. 
Published: December 2007

Abstract
Hydraulic fracturing is an economic way of increasing gas well productivity. Hydraulic fracturing is routinely performed on many gas wells in fields that contain hundreds of wells. Companies have developed databases that include information such as methods and materials used during the fracturing process of their wells. These databases usually include general information such as date of the job, name of the service company performing the job, fluid type and fluid amount, proppant type and proppant amount, and pumped rate. Sometimes more detail information may be available such as breakers, amount of nitrogen, and ISIP, to name a few.
These data usually is of little use if some of the complex 3-D hydraulic fracture simulators are used to analyze them. But valuable information can be deduced from such data using virtual intelligence tools. The process covered in this paper takes the available data and couples it with general information from each well (things like latitude, longitude and elevation), any information available from log analysis and production data and uses a data mining and knowledge discovery process to identify a set of best practices for the particular field. The technique is capable of patching the data in places that certain information is missing. Complex virtual intelligence routines are used to insure that the information content of the database is not compromised during the data patching process. The conclusion of analysis is a set of best practices that has been implemented in a particular field on a well or on a group of wells basis. Since the entire process is mostly data driven we let the data "speak for itself" and "tell us" what has "worked" and what "has not worked" in that particular field and how the process can be enhanced on a single well basis. In this paper the results of applying this process to Medina formation in New York State will be presented. This data set was furnished by Belden & Blake during a GRI / NYSERDA sponsored projects.
This process provides an important step toward achieving a comprehensive set of tools and processes for data mining, knowledge discovery, and data-knowledge fusion from data sets in oil and gas industry.
Continuing Education Needs in Exploration and Production
Authors: Domínguez-Vargas G. , Camacho-Velázquez R. 
Published: December 2007

Abstract
This paper describes the findings of a technological diagnosis in a national oil company, aimed at detecting professional development needs, the set of actions taken to solve these, and the evaluation of these measures by another needs-identification procedure.
With these results, future actions are proposed to consolidate the advances and to drive the company to the next level of professional development.
A Method for Analyzing Multiple Factor Experiments - Its Application to a Study of Gun Perforating Methods
Authors: Vogel L.C. 
Published: December 2007

Abstract
Frequently in engineering research, problems involving a large number of variables (factors) are encountered. A traditional method of interpretation is for the project engineer to present his results in the form of families of curves obtained by varying factors one at a time. When several values (called levels) are required to characterize each variable properly the number of test points necessary may become prohibitive. It is possible under certain conditions to test only a portion of all of the combinations of the factors and still draw reliable conclusions.
This paper describes and demonstrates the use of a powerful statistical method for handling problems of this type. The accurate and fairly inexpensive solution to the laborious calculations was made possible by the use of an electronic data processing machine. The first part of the paper deals with the method of analysis in sufficient detail so that its application in general engineering research problems can be seen. The second part describes the actual application to a study of gun perforating methods.

Introduction
One of the most perplexing problems faced by engineers is that of properly interpreting the results of experiments involving large numbers of supposedly independent variables. Reservoir engineers are constantly attempting to evaluate the effect that the various phases of well completion have upon oil production. Research engineers design laboratory experiments to evaluate various factors in as economic a manner as possible. The classical method of studying the effect of controllable factors is to vary a single factor at a time. This "single-factor-at-a-time" method is extremely inefficient when compared to the technique called factorial design. For a simple experiment involving two factors, each at two values (levels), the use of factorial design results in an increase in precision of 50 per cent over that in the equivalent single-factor-at-a-time experiment and, as the example becomes more complicated, the difference in efficiency between the two methods increases markedly. This advantage of factorial experiments, sometimes called "hidden replication," is based on the fact that all of the observations contribute to the determination of the effect of each factor. In the single-factor method, on the other hand, only a small proportion of the total number of observations is used.
When factors do not operate independently the are said to interact. An example of interaction between factors can be seen in PVT studies where the effect of varying the temperature is dependent upon the pressure of the system.
An Evaluation Method for Screen-Only and Gravel-Pack Completions
Authors: Hodge Richard M. , Burton Robert C. , Constien Vernon , Skidmore Valerie 
Published: December 2007

Abstract
Screen-only and screen with gravel-pack completions have become more commonplace in long horizontal wellbores in poorly consolidated reservoirs. Several of the formations currently being completed pose challenges in selecting effective sand-control screens due to their non-uniform particle size distributions and the large amount of very small particulates.
Early screen and gravel-pack studies, from which common scaling factors were derived, did not always contain the smaller particle sizes that are encountered in poor quality reservoirs. Later studies have shown that both the fines content and the uniformity of the sand impact the performance of the completion7-13.
This paper presents an evaluation method for screen-only and gravel-packed completions utilizing formation sand samples. The method determines the amount of solids produced through the screen and the change in flow capacity of the screen and formation sand pack with increasing stress. The flow capacity data is useful in estimating production changes as wellbores collapse around the screen and the formation porosity around the screen decreases.
The amount of formation particles that pass through the screen or the gravel-pack and screen is useful in estimating the solids production. Data is presented which illustrates the amount of small particles, which can penetrate wire-wrapped and premium screens, along with gravel-packs and gravel-packed screens.
Data will be compared for gravel-packs based on conventional scaling factors of 5-6 times the median diameter and other scaling factors.
Environmental Protection in Work-Over Completion Operation Using Pitless and Zero Cost.
Authors: Sauman M. , Law B. , Hamdani A. , Foster J. 
Published: December 2007

Abstract
Pertamina / Vico Indonesia made the decision to minimize the environment impact from its Work-over completion operation in East Kalimantan. In the past, Work-over completion operations typically used a large location with a brine or salt water as work-over fluid in work-over completion operation. All waste from the operation was dumped into a large pit. The drilling and work-over department is now applying new technology to continuously improve and achieve ‘pit-less work-over completion’ or ‘zero waste discharge’ and therefore minimize the environmental impact. The intention was to achieve these environmental goals with an overall cost saving, as the increased costs would be offset by cost reductions. The project is being implemented in several stages.
The first stage of the environmental protection project is to use additional water clarification equipment and centrifuge to treat location drainage and rainfall. This process allows the clean water discharge from the process to be recycled for the rig operation or disposed to the environment. The solid waste from the centrifuge is tested to ensure the solid discharge is acceptable and landfill in the catch pit. Locations are designed and built to channel the rainwater. The catch pit is build to collect the liquid waste and oil pollution. Oil or condensate is skimmed and burnt at the flare pit
The second stage of the project used a water clarification, filtration unit to recover salt water or brine from the old well to be recycled for work-over completion operation. The system and waste disposal is proven and pit-less work-over completion has been implemented in VICO operation.
During the project, special effort has been given to confirm the water clarification and remediation results. In order to meet Indonesia regulations and other applicable regulations and standards, water and solid waste are tested to ensure discharges are acceptable. The work-over completion area was planted with a variety of native plants.
Using the above technology Pertamina / Vico Indonesia are working to minimize the environmental impact in work-over completion operation. There is "Zero" environmental cost as the cost of the service is offset by reduced costs for land, construction, reclamation, and re-greening.
This paper describes the minimization of environmental impact in work-over completion operation with zero cost.
The Importance of a Health Management Program in China
Authors: Raj Reuben D. , Jackson Mark 
Published: December 2007

Abstract
More and more international companies regard people as the main asset of the business. In many cases, medical evacuation and emergency response often get more emphasis when a foreign company starts its operations in the oil and gas industry of the People's Republic of China. However, this view can be perceived as reactive. To prevent losses, a proactive Health Management System is essential to treat health-related problems early.
China, with her great diversity, offers a new market with endless business opportunities. The acceptance of China into the World Trade Organisation will no doubt attract more foreign investment into this new business frontier. Health, among other issues, is an important element for any foreign company to consider before commencing operations.
Mechanical Equipment Surveillance
Authors: Broyles George W. 
Published: December 2007

Abstract
Surveillance of gas facility mechanical equipment is a vital part of Exxon's current operation. Proper utilization of this equipment presents a significant opportunity in cost control, presents a significant opportunity in cost control, optimizing revenue and minimizing investment requirements. If reciprocating compressors and centrifugal compressors are not operated properly and adequately maintained, oil production, gas production and gas plant liquids will be curtailed production and gas plant liquids will be curtailed accordingly. Availability of horsepower when needed is an obvious requirement for maximizing revenue from production of oil, gas and gas plant products.

Introduction
This paper describes a mechanical equipment surveillance program that has been developed in the East Texas Division of Exxon Co., U.S.A. Production Department. The statistics that are Production Department. The statistics that are quoted refer only to this division, and although similar programs are in effect in other divisions within Exxon's Production Department, only the specific program as developed by the East Texas Division is described.
The existing machinery maintenance program was begun in 1968 with the establishment of an engineering surveillance group at the division level. By 1978, surveillance personnel had also been added to the engineering groups in the four district offices. There is a total of 463,000 BHP in 390 units in gas compression and generator service spread over one 75,000 square mile area of this division.
The machinery maintenance system can be divided into four basic functions:Predictive/Preventive MaintenancePerformance monitoringTechnical inputDevelopment of on-site maintenance capability
These four facets of the system are discussed below, followed by a summary of the benefits that have been accrued from the system to date.

I. PREDICTIVE/PREVENTIVE MAINTENANCE PREDICTIVE MAINTENANCE PREDICTIVE MAINTENANCE

Reciprocating Compressors
Exxon has utilized predictive maintenance techniques since 1968 when the first Beta Engine/ Compressor Analyzer (E/CA) was purchased. The Beta analyzer was developed by the Southwest Research Institute of San Antonio, Texas to analyze reciprocating engines and compressors in operation. The analyzer became a reality in January, 1965 when Beta Corp. of Dallas, Texas began marketing it.
The Beta E/CA is comprised of three main units which are:The motion transducerThe indicator unitThe auxiliary unit
Other basic components used with the Beta E/CA are the synchronizing light, pressure transducers, oscilloscope camera and ignition and vibration pickups. pickups.
An Investigation of Asphaltene Instability Under Nitrogen Injection
Authors: Jamaluddin A. K. M. , Joshi N. , Iwere F. , Gurpinar O. 
Published: December 2007

Abstract
As a part of an integrated improved oil recovery project, it was required to evaluate asphaltene formation arising from contacting nitrogen gas with the reservoir fluid. This paper discusses the experimental work associated with the asphaltene evaluation.
The subject reservoir was known to have operational problems due to asphaltene precipitation during primary production. Hence, laboratory experiments using the transmittance of an optimized laser light in the near infrared (NIR) wavelength (~1600 nm) were used to first define the pressure-temperature regions of asphaltene instability of the reservoir fluid. Subsequently, several light transmittance experiments were conducted to evaluate the asphaltene instability regions by contacting various molar concentrations (5, 10, & 20%) of nitrogen gas with the reservoir fluid. Also, measurements were conducted to quantify the bulk precipitation of asphaltene with various molar concentrations of nitrogen.
Results indicated that nitrogen gas aggravated the asphaltene instability, and also, increased the bulk precipitation amount with increasing concentrations of nitrogen gas in the reservoir fluid. The aggravated asphaltene instability could potentially nullify any expected benefits of improved oil recovery with nitrogen injection as pressure maintenance.
The Hybrid Drilling System: Incorporating Composite Coiled Tubing and Hydraulic Workover Technologies into One Integrated Drilling System
Authors: Coats E. Alan , Farabee Mark 
Published: December 2007

AbstractHistorically well drilling operations have been based exclusively on steel pipe. Recently a drilling system that combines composite coiled tubing technology and hydraulic workover technology has been introduced. This paper examines the operating experience for the system and its implications for the future.By using composite pipe with embedded conductors, the system achieved uninterrupted real-time two-way communication with the downhole tools. This allowed a step-change improvement in the knowledge of dynamic wellbore conditions and in the control over downhole systems. New procedures were developed to assimilate and use this increased functionality. These procedures include both geosteering and real-time system diagnostics from remote locations.Incorporating a hydraulic workover (HWO) jacking system as an integral part of the drilling unit also expanded the operating envelope and functionality of the entire drilling system. This revolutionary full-system development encountered numerous challenges, many of which are related to the unique properties of composite pipe in difficult hole conditions. The technological solutions to these challenges are examined in depth.
A Realistic Approach For Capital Expenditures Analysis
Authors: Choudhary Bijoy K. , Kellstrom William A. 
Published: December 2007

Abstract
This paper briefly reviews the various financial analysis techniques to judge capital expenditure projects. Most of these methods in their basic forms, however, fail to determine the real returns to a company from such capital investments. A procedure is outlined to incorporate the concept of real returns for a realistic appraisal of a capital expenditure project.

Introduction
The capital expenditures in the petroleum industry are analyzed with the help petroleum industry are analyzed with the help of several techniques, such as discounted cash flow rate of return, net present value, payback and operating rate of return. Among the lesser known and practiced methods are E.A.A. (equivalent annual amount) rate of return and some ratio of present value of profits to present value of investments. Beyond the apparent present value of investments. Beyond the apparent advantages and disadvantages, these methods in their basic forms fail to account for the real loss of returns due to inflation and other factors which may be unique to a company.
This paper describes the existing financial analysis techniques and then discusses a method which incorporates the concept of real returns which are also adjusted for the company's historical performance. When combined with some form of computerized simulation techniques, this suggested approach can perform a very effective and useful role in proper selection and ranking of the capital expenditure projects. This may also be able to achieve optimum returns under any given set of assumptions. A comprehensive example shows the various profitability measures and their usefulness and profitability measures and their usefulness and limitations. It is then expanded to show the real rate of return which ought to be the true measure of capital expenditure projects. projects.

DISCUSSION OF PROFITABILITY MEASURES
The various methods to determine the profitability of a project are summarized profitability of a project are summarized below.

DCF RATE OF RETURN
The discounted cash flow (DCF) rate of return, also known as internal rate of return, is the discount rate which will make the present value of all cash outflows equal to the present value of all cash inflows.