bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Installed Coiled Tubing Gas Lift Completions
Authors: Tran T.B. , Miller J. , Woodell M.E. , Johnson H.R. 
Published: December 2007

Abstract
Gas lift has long been used as a petroleum industry vehicle for secondary artificial lift. Typically run in a conventional jointed tubing completion string or, more recently, in manufacturer installed spoolable systems utilizing continuous pipe; new applications utilizing modifications of existing equipment and processes have enabled "on-location" make up of coiled tubing conveyed gas lift strings and subsequent installation and/or extraction of same. This application was designed as an alternative to conventional gas lift systems as well as other means of artificial lift in order to effectively address mechanical problems due to wellbore conditions and expensive and frequent workover operations all dictated by marginal well economics from tail-end field reserves. Results from this completion method have been mechanically and economically successful for this application and field installed coiled tubing gas lift has been expanded to exploit other formation types.
Development and Use of an Analytical Model to Predict Coiled Tubing Diameter Growth
Authors: Brown Paul A. , Dickerson Jessica L. 
Published: December 2007

Abstract
When coiled tubing (CT) is plastically deformed by bending over a reel or guide arch, several important changes are known to occur. The tubing suffers irreversible and cumulative fatigue damage, and the diameter may increase in the presence of internal pressure. Fatigue has been the subject of extensive study, and several analytical and empirical models have been successfully developed. Diameter growth has received less attention, but recent industry trends are causing it to become more of a concern. These trends include:–Use of tubing for a greater fraction of its fatigue life–Repeated local cycling at higher pressures (e.g. drilling)–Greater use of large diameter CT–Operations at very high pressure &gt;5000 psi)
It is worth noting that all of the above trends have been made possible in part by improved modeling, the effectiveness of which is undermined if an important parameter affecting the working life of the string is neglected, such as tubing diameter.
This paper presents an analysis of a new analytical model for predicting diameter growth, and compares the estimated working life of a tubing string when both fatigue and diameter growth are considered. Model predictions are compared with observed data from full-scale tests and fatigue test machines. Use of the model in real-time tubing monitoring software as a means to identify potential problem areas is discussed.
Update on Advance Composite Spoolable Pipe Developments
Authors: Fowler Hampton 
Published: December 2007

Abstract
Much of the credit for the recent rapid growth in the Coiled Tubing Industry can be attributed to the development of larger diameter and higher strength spoolable steel tubular products allowing for an expansion of the operating limits and the applications that can be performed such as drilling, completions and horizontal well servicing. The development of an advanced composite, high performance spoolable tubular product will help fuel this market expansion even further by creating additional enabling capabilities for the Coiled Tubing well servicing industry.
Conoco, Inc. initiated the development project for high-performance, composite spoolable tubular products in 1988. The initial focus was on corrosion resistant water injection lines and later evolved to a 1.5" OD composite coiled tubing. The development effort lead to a composite tube design formed by taking a thermoplastic liner and surrounding it by a carbon fiber and epoxy matrix structure. The matrix includes an external KevlarR fiber layer to provide wear and impact resistance. The advantage of a composite spoolable pipe over steel pipe is that it can be "engineered" for particular applications to take advantage of the composite's enabling attributes. These attributes include corrosion resistance, high strength to weight ratios, high working pressure capability and low material density. In fact, the current composite tubing designs weigh in at 1/3–1/4 the weight of a like OD steel tube in air and are 1/7th the weight of steel in water. This obvious advantage allows longer and larger strings of composite tubing to be handled by lower pull capacity coiled tubing units or lifted onto offshore platforms with smaller crane capacities.
This paper will review the development efforts and operational issues addressed to qualify the advanced composite spoolable tubing for several enabling applications. The first full scale field trials are scheduled to be performed in the 2nd quarter of 1997.
High Pressure Coiled Tubing Job Prepares Gulf Coast Well
Authors: Morrison Dan , Reid Kevin , Kenney Tom 
Published: December 2007

Abstract
This case history paper presents the details of the role played by coiled tubing in returning a high-profile, Gulf of Mexico oil/gas well to production after the well had to be shut in due to excessive sand production. The paper presents the following events/conditions:The well could not be injected into in several attempts up to 9,300 psi. Since the well had produced sand, operators suspected that a sand plug existed.The well was completed with 4 1/2", 15.1# production tubing.Coiled tubing performed offline while the rig was performing completion operations. A hydraulic workover unit would have required the rig to be moved to aid in snubbing operations.The well was 18,750 ft deep, with a wellhead pressure of 7,000 psi. The well was producing from two comingled gravel packs with a ceramic flapper installed in the upper gravel pack packer for fluid loss. The state of the flapper was unknown.A coiled tubing string of 1.25" OD and 19860 ft long was designed for the job. Wall thickness tapered from 0.156 in. at the top to 0.134 in. at the bottom to support the tensile load of the string and provide maximum cycling capabilities at the location of the ceramic flapper.
The initial goal was to use coiled tubing to wash to the bottom of the lowest gravel pack and break through the ceramic flapper with an impact tool. Due to low annular velocities inside the production tubing a special xantham based polymer/CaCl2 mixture was required to wash sand to the surface. The use of coiled tubing to wash through the production tubing in this extreme pressure/depth application allowed the well to eventually be killed by bullheading kill fluid.
The paper also presents useful information on the following coiled tubing-related issues:Tubing fatigue monitored by software that tracked tubing life and helped ensure that the tubing was not used beyond stress ratings.Coiled tubing technology has extended the working envelope for high pressure applications.
Worldwide Occurrence of Abnormal Formation Pressures, Part I
Authors: Fertl Walter H. 
Published: December 2007

Abstract
In the last decades, exploration for new and additional oil and gas reserves has greatly expanded laterally, both on- and off-shore, and at the same time has also greatly progressed downward to investigate the hydrocarbon potential of deep and superdeep targets. In these activities, abnormal formation pressures; i.e., pressures other than hydrostatic have been encountered on all but one continent. The present discussion attempts to compile information on the worldwide occurrence of abnormal formation pressures, which are equally important in the pressures, which are equally important in the search for and drilling and production of oil and gas.

Introduction
In the worldwide search for oil and gas, formation pressures other than hydrostatic have been encountered on all but one continent (Figure 1). Such abnormal pressures, defined by departure from hydrostatic at any given depth, may be excessively high or low, the possible modes and causes of origin being numerous.
The present discussion, unfortunately, is limited by (1) data available to the author or (2) their proprietary nature (North Sea, South China Sea, Arctic Islands). Since each country had to be treated rather briefly, selected references will assist in pursuing the subject further. All pressure pursuing the subject further. All pressure data shown in graphical rather than tabular form. Each graph includes three trend lines representing the overburden gradient of 1.0 psi/ft, which corresponds to the weight of the overlying rock series (i.e., weight of both the rock matrix and fluids) with an average density of 2.30 gm/cc, (2) the hydrostatic pressure gradient of 0.465 psi/ ft, which corresponds to the average hydrostatic gradient as found in the U.S. Gulf Coast area, and (3) the hydrostatic gradient of 0.433 psi/ft, representative of the domestic Mid-continent area.
A Method of Determining Permeability by Means of a Pulsed NMR and an Application of the Method to the Study of a Gulf Coast Supernormally Pressured Well
Authors: Seevers D. O. 
Published: December 2007

Abstract
A method is presented for determining porosity, specific surface area and permeability of shales by means of pulsed Nuclear Magnetic Resonance pulsed Nuclear Magnetic Resonance (NMR). The method is applied to drilling chips collected from a Gulf Coast well. Combining well data on pressure and temperature with the NM pressure and temperature with the NM determination of permeability, a calculation of vertical flux is made. An analysis of the behavior of the flux with depth suggests that clay diagenesis is responsible for the supernormal pressure. All other observed properties can be explained on this basis.

Introduction
There are many hypotheses for the cause and present day characteristics of supernormally pressured sediments. In general we do not have enough information to validate a given hypothesis. The purpose of this report is to present a method for determining the permeability to fluid flow of the shales in the supernormally pressured section. These permeabilities can be combined with permeabilities can be combined with pressure data on adjacent sands and pressure data on adjacent sands and yield the present day flux of water through the shales. A knowledge of the variation of water flux with depth will aid in understanding the cause.
A Systematic Study of Fracture Modeling and Mechanics Based on Data from the GRI/DOE M-Site Project
Authors: Wright T. B. , Green T. W. 
Published: December 2007

Abstract
The GRI/DOE M-Site Project involved a series of seventeen test injections pumped into three separate wet, non-economic sandstone reservoirs. Various advanced diagnostic techniques were used to characterize the resultant fracture systems. These diagnostics included microseismic-event mapping, the use of closely-located downhole tiltmeters, and numerous observations resultant from cores taken through the expected fracture azimuth. Using numerous procedures and tests, these reservoirs were more completely characterized than would be the case for a typical commercial reservoir, however the accuracy of some important parameters (specifically, some which are used as fracture simulator inputs) is still questionable due to the layered nature of the reservoirs. All seventeen of the injections were analyzed using a lumped-parameter 3D fracture simulator, both in real-time and postinjection. Using measured injection data as inputs, the simulator-predicted pressure was compared and matched to the measured data. Whenever the model-predicted fracture dimensions differed substantially from the diagnostically-determined dimensions, certain model and/or reservoir parameters were changed so that the simulator and diagnostic dimensions predictions were in agreement (with simulated and measured pressure also still in agreement). Details of the simulator analyses are presented and compared to the diagnostic interpretations. Other direct observations made from the various data are also presented.
Import LNG
Authors: Purvin Robert L. 
Published: December 2007

Abstract
Import LNG should represent an important addition to the gas supply of the United States but there are many political and economic factors which must be considered. It is increasingly apparent that because of rising hydrocarbon values and increasing capital costs, LNG will not be a cheap supply but it should be competitive with other substitute natural gas sources. Of particular importance is the fact that LNG can be stored and should represent the most economical source of short and intermediate seasonal and peak supply. Security of supply and foreign exchange requirements are two subjects that must be studied in major LNG importation programs but the fact that gas is our cleanest form of fuel will be a strong attraction for importing relatively large supplies if they are available at a reasonable price.

Introduction
On March 9th of this year the Federal Power Commission approved for the first time a long-term LNG import program. While this must be viewed as a landmark decision, the Distrigas project is of such a limited and specialized nature that it certainly will not set the precedent for all future LNG projects. There is no doubt that the case served to educate industry, government and the public in this new and innovative field of liquified natural gas and will therefore have served a useful purpose in setting guidelines for larger and more ambitious LNG projects. The distrigas decision culminates almost four years of activities which led to the Distrigas projects and represents a personal landmark after almost twenty years of work in the LNG field. The development of this project is in itself an interesting story but today I want to give you a broad view of import LNG, describing this new industry as a whole, pointing out its strengths and weaknesses, and even attempting to forecast its ultimate position in our future gas supply.
Casing Design for Extended Reach Wells
Authors: Jaffe Linton , Maidla Eric , Irrgang Rosemary , Janisch Werner 
Published: December 2007

Abstract
A method for calculating casing loads for extended reach wells is presented that helps outline field strategies to run casing in or pull casing out of the well (if necessary). It is based on defining the critical inclination for which drag exceeds the tangent weight component and considers multiple fluids (air, water, mud, heavy mud) inside the combination casing string while running it into the well to optimize hook loads (minimize or maximize depending on the desired situation).
The results show that optimization is possible but is dependent on the friction factor used for the design procedure.
Reforming Liquid Hydrocarbons
Authors: Marten Jerome H. 
Published: December 2007

Abstract
The paper deals with a review of the various existing processes for the production of Synthetic Pipeline Quality Gas production of Synthetic Pipeline Quality Gas from liquid hydrocarbons ranging from methanol through whole crude oil.
Commercialized processes covered include both catalytic gasification, thermal cracking and non-catalytic hydrogenation.
A brief discussion of the economics of the catalytic gasification process together with other potential applications for said process is also given. process is also given. In the United States today we are in the beginning of an overall energy shortage. While the causes and magnitude of this energy shortage are being debated at all levels of industry and government, the one fact generally accepted is that of all the energy sources, natural gas will feel the pinch first and most severely. This pinch first and most severely. This impending shortage of natural gas is the motivating force behind the renewed interest in production of gaseous fuels.
The development of processes for the commercial manufacture of fuel gas goes back at least two hundred years. One of the first processes was used in Philadelphia in 1796 to produce fuel gas for street lights. This process was based on coal gasification as were the majority of the early gasification processes. The gasification processes generally produced a product with a higher heating value of product with a higher heating value of below 500 BTU/SCF, which was referred to as "Town Gas". Originally the "Town Gas" was used for lighting and domestic heating only; but, as demand for electricity and industrial uses grew "Town Gas" production increased greatly. The development of the synthetic ammonia and methanol processes lead to the development of coal and coke gasification processes designed to produce the specific synthesis gases required.
"Town Gas" production was usually associated with the coal and steel industries. This was especially true in the United Kingdom and Europe. In the United States, an ever increasing amount of the energy requirements were supplied by petroleum products and "Town Gas" production came to a halt for all practical purposes in 1947, mainly because of practical purposes in 1947, mainly because of accelerated discoveries of natural gas reserves and development of an extensive nationwide pipeline distribution system. Europe too, after World War II, shifted to petroleum to meet the rapidly expanding energy demand. Domestic needs, however, were still supplied via "Town Gas".
In the early 1960's, with the development of the ICI high temperature naphtha-steam reforming process, which produced a 300 BTU/SCF gas, the United Kingdom's "Town Gas" industry shifted to a naphtha feed basis very rapidly. Initially LPG was used as the enriching gas; but, in the mid 1960's the British Gas Council developed a catalytic low temperature steam-naphtha gasification process, the CRG Process, which produced a high BTU gas suitable for use as the enriching gas in "Town Gas" production.
Systematic Methodology for Effective Perforation and Fracturing Strategies
Authors: Manrique J. F. , Bjornen K. , Ehlig-Economides C. 
Published: December 2007

Abstract
This paper discusses an improved completions methodology and criteria for perforating/fracturing based on systematic and enhanced geomechanical reservoir characterization.
Understanding of the near wellbore stress distribution is critical to implement a sound perforating strategy. Reservoir quality variations, mixed lithologies with plastic behavior and loading/unloading cycles (drilling and production operations) will alter the near wellbore stress distribution reducing the compressive stress of the rock. Thus, constant stress gradients (i.e., 0.1 psi/ft.) are misleading and rock mechanical properties measurements may prove to be of extreme importance.
The case-specific examples presented in our work, demonstrate the advantages of using a detailed geomechanical reservoir description and illustrate when the "standard" assumptions and the "one-approach-fits-all" perforating approaches are not applicable. Perforation strategies are suggested to address different and complex issues; multiple fractures, phasing, shot density, vertical coverage, natural fractures, far field stresses alignment, tortuosity and erosion effects. Reservoir performance, net pressure matches and geomechanical data indicate that effective stimulation treatments can be implemented where others have failed or unacceptable production changes occurred.
The perforating for fracturing methodology discussed in this paper places the set of perforations where they are needed the
most, accounting for stress contrasts and optimization of shot density and phasing. Easy to implement recommendations for strategic placement of perforations and the mechanics for fracture initiation from vertical, deviated and horizontal wellbores are briefly discussed.
This approach attempts to achieve effective vertical coverage and proper placement of a hydraulic fracture. As demonstrated by production results, the improved efficiency of the perforating/fracturing strategies minimizes treatment failures and has significant impact on treatment implementation and production enhancement strategies.
Application of Model Studies to the optimization of Pressures in Underground Gas Storage Reservoirs
Authors: Hardy Reginald H. , Khair Abdul W. , Kimble Edward J. 
Published: December 2007

Abstract
Research presently underway at the Pennsylvania State U. is concerned with the Pennsylvania State U. is concerned with the study of the mechanical stability of underground gas storage reservoirs. This research involves a number of phases including a laboratory model study which will be outlined in the present paper. paper. In these studies small scale models containing reservoir cavities of simple geometry were first loaded under typical in-situ stresses then pressurized internally until failure occurred. Microseismic techniques were utilized to detect reservoir failure.
A description of the experimental facilities and the model fabrication techniques are included along with a review of results obtained from tests on a number of differently shaped reservoir cavities. A discussion, relative to the effect of reservoir geometry and depth below surface, on the optimum storage pressure is included. In general, the results of the model study indicate that optimum storage pressures may be considerably higher than those based on the discovery pressure or the average hydrostatic gradient.

Introduction
The natural gas industry today is faced with the problem of locating and developing sufficient underground storage reservoir capacity to meet peak seasonal demands. Since it is economically desirable to store the gas at the mammon possible pressure, an accurate value for the optimum pressure, namely the maximum pressure to which a reservoir could be pressure to which a reservoir could be pressurized and still remain mechanically stable, is pressurized and still remain mechanically stable, is of great importance.
Natural gas is stored underground in former gas and oil reservoirs, aquifers and man-made cavities. As the demand for natural gas increases the necessity for storing larger and larger volumes of gas underground during periods of low demand has increased markedly. In 19701 a total of 325 storage reservoirs were reported in the U. S. The majority of underground storage was located in former gas and oil reservoirs with a lesser number in aquifers and relatively few in man-made cavities.