bluuebunny/crossref_metadata_2025_split huggingface dataset:
Skid Mounting an 1100 Horsepower Turbine Compressor Station
Authors: Koskimaki C.M. 
Published: December 2007

Abstract
Skid mounting compressor stations for portability will result in a minimum amount portability will result in a minimum amount of wasted material and additional costs should the relocation of this station become necessary. Mountain Fuel Supply Company has recently skid mounted a remote control, completely automated 1100 horsepower turbine compressor station and installed it at a remote location south of Vernal, Utah.
The turbine compressor unit, piping, automatic valves, regulators and the unit controller are mounted inside of a building as one integral unit on a single skid; while the plant generators, boiler and station controller are mounted inside of another building on a second skid; and the microwave system and building are mounted on a third skid.
The yard piping and metering are the only part of this station which are not Portable. Each of the three skids can be Portable. Each of the three skids can be wenched onto a flatbed truck and moved to a new location with relative ease with only a minor amount of interconnecting piping and wiring necessary to complete the relocation.
Introduction
Skid mounting equipment for portability has become increasingly popular with industry in recent years. The obvious advantage for making anything portable is in the cost savings when and if the particular piece of equipment should ever be moved. An additional advantage is in being able to do most of the fabrication under ideal conditions in a machine shop rather than at some distant location.
With these factors in mind, Mountain Fuel Supply Company has skid mounted a completely automated, remote control, 1100 horsepower turbine compressor station along with all of the necessary auxiliary equipment and have installed it at a remote location south of Vernal, Utah and east of Bonanza, Utah.
FUNCTION AND CONTROL
This compressor station was installed for the purpose of maintaining a 500 Psig contract pressure at Bonanza, Utah, the beginning of our southern pipeline going into Orem, Utah.
The Friction Measuring Tool: Real-Time Estimates of Sandface Pressure During Fracture Treatments
Authors: Graham R. L. , Hill D. G. , Amick P. C. , Shaw J. S. 
Published: December 2007

ABSTRACT
This paper describes a Friction Measuring Tool (FMT) and how it is used to estimate pressure loss from friction in the wellbore while a foam fracture treatment is being pumped. Combined with standard surface equipment, such as densitometers, flowmeters, and pressure transducers, this tool (located on the surface) offers real-time estimates of bottomhole treating pressures during the fracture treatment. Field examples are presented comparing calculated bottomhole treating pressures, based on the FMT, to actual pressures measured with downhole electronic pressure gauges (installed in the casing just below the treated zone) during stimulation treatments.
In addition to the provided field examples which verify application of the FMT, the theory and mathematical background underlying the use of the FMT are described. Construction of the tool, actual use in the field, and trouble-shooting are also presented. This tool is also applicable to foam for coiled tubing operations or stable foam drilling.
Development of the FMT is one product of a cooperative research program sponsored by the Gas Research Institute (GRI) where one of the broad research objectives is improved stimulation techniques.
Two New Design Tools Maximize Safety and Efficiency for Coiled Tubing Pumping Treatments
Authors: Gary S. C. , Walton I. C. , Gu H. 
Published: December 2007

ABSTRACT
This paper describes the use of two new computer tools to assist the engineer in the design and evaluation of coiled tubing (CT) pumping treatments. Sand fill cleanouts and nitrogen kickoffs continue to comprise the majority of the operations performed by CT; however, the ability to design and evaluate jobs of this type has been limited for many years to simple steady-state calculations and general rules of thumb, both strictly applicable to vertical wells. Using these tools and an engineering design methodology, these treatments can be performed in the most efficient manner possible. The tools optimize the fluids, rates and penetration schedules by considering the effect of deviation on particle transport, reservoir influx or leakoff or both, mixing of gases in the wellbore, and other aspects of the operation. Additionally, by optimizing the required movement of the CT, pipe fatigue can be held to a minimum, providing safer and more cost-effective treatments. Examples that use these tools to design CT treatments are presented.
Optimal Design of Perforating Completion for Gas Well
Authors: Tang Yula , Pan Yingde , Wang Yongqing 
Published: December 2007

AbstractThe productivity characteristics of perforated gas well is investigated for the first time under real conditions considering drilling damage, perforation compacted zone and anisotropy in this paper. A nonlinear finite element model for non-Darcy flow in perforated gas reservoir is built to consider the effects of twelve factors on productivity ratio (PR) of perforated gas well. The nomographs for two cases are presented in this paper.Compared with previous works, the following results are found: (I) The effects of drilling damage and perforation diameter on PR of gas well are more remarkable than that in oil well. (II) Any perforation phase may be the best or the worst as to perforating gas well, which depends on anisotropy, drawdown and that whether or not perforations are beyond drilling damage zone. (III) The increase in perforation length hardly improve PR of gas well when perforations have been beyond drilling damage zone.The new method is suggested to predict or determine the turbulent flow co-efficient D’, total skin S, pseudo skin St’, and individual skin factors (Sp, Sd, Sdp) in perforated gas well.The minimum underbalance required to obtain a zero perforating skin is discussed as well. Some drawbacks of the equation proposed by Tariq (SPE 20636) are analyzed and a new Reynold's number criterion is established. The critical Reynold's number for clean perforation is dependent on formation permeability.Based on this research, the principle and the program for optional design of perforating completion in gas well are highlighted. These new concepts, results and conclusions would be of importance to both gas well perforating and gas reservoir engineering.
The Depletion Behaviour Of The F23 Gas Field (East Malaysia) - Integrated Studies On History-Matching Dynamic Data
Authors: Leong Stephanie M.S. , Ling Liew Shiew , Wong Kenneth U.S. , Heijna H.B. 
Published: December 2007

Stephanie M.S. Leong,* Liew Shiew Ling, Kenneth U. S. Wong and H.B. Heijna

Abstract
The F23 carbonate gas field has some 10 years of production history. Annual TDT surveys are conducted to monitor compaction and gas-water contact movements in the central part of the field. These observed gas-water contact movements were not compatible to those predicted by material balance studies. There was also a fear of preferential flank water influx which might lead to early flooding at the wells. Since these have important consequences to gas deliverability, multidiscipline studies were initiated. This paper describes the material balance, simulation and seismic work undertaken to arrive at a rigorous interpretation.

Background
The F23 gas field is located in the Central Luconia Province, some 200 km offshore Sarawak in a water depth of about 280 ft (Fig. 1). The accumulation consists of a Late Miocene layered platform type carbonate build-up with an areal extent of 22 km2 and a maximum gas thickness of over 1000 ft.
F23 is divided into five zones (Fig. 2), the peripheral flank Zone 5 surrounds the four horizontal zones (Zone 1 to Zone 4). An extensive aquifer lies at the bottom faces of Zones 4 and 5. The geology and reservoir properties in Zone 5 is one of the largest uncertainties in this study as no wells have yet penetrated this flank zone.
P. 485
Applications and Field Experience of an Advanced Delta Flow Kick Detection System
Authors: Haeusler Detlef , Makohl Friedhelm , Harris T. W. R. 
Published: December 2007

ABSTRACT
A Kick Detection System has been developed especially for Slim-Hole applications recognising extreme low flow differences between flow in and flow out, and considering dynamic effects of the fluid system during different operating processes, i.e., tripping pipe, reaming or drilling.
The system provides audible and visual alarms to the drill floor, as well as fluid volume information.
In more than 25 applications onshore and offshore the system has proven its functionality and reliability by detecting differential flows of less than 15 1/min and kicks at influx volumes of less than 120 litres.
Validation of Kick Control Method and Pressure Loss Predictions on a Slim Hole Well
Authors: Dupuis Dominique , Augis Didier , Sagot Andre , Delahaye Thierry , Cartalos Ulysse , Burban Bruno 
Published: December 2007

ABSTRACT
In order to validate a kick control method and a pressure loss model for Slim Hole, experiments on a pilot well were performed.
For the validation of the pressure loss model, flow parameters were varied so as to investigate all possible flow regimes.
For the kick control method, different drilling situations have been simulated. The paper underlines recommendations and operating instructions for the field.
New Field Methods Of Estimating Minimum Flow Rate Required For Continuous Removal Of Condensate From Gas Wells
Authors: Shirkovsky A.I. 
Published: December 2007

Abstract
Special field experiments have been made in the Cambay gas condensate field in western India to determine the minimum flow rate (MFR) required for continuous removal of liquid from condensate wells. Two new field methods have been developed for estimating MFR. The first is based on a calculation of the height of the condensate column at the bottom of the well and the minimum flow rate required to eliminate this column. The method requires data on pressures and temperatures at the wellhead and at bottom hole plus specific gravity of the gas and condensate. The second method utilizes data from a separator that operates at a constant temperature which is held fixed by flowing the gas condensate mixture through a sufficient length of buried pipe. From plots of the condensate-gas ratios in the separator versus pressure at fixed flow rates, it is possible to determine the MFR that will eliminate condensate from the well. Recent theoretical methods proposed by others do not give satisfactory results when applied to the proposed by others do not give satisfactory results when applied to the data of the Cambay field.
Introduction
Two-phase flow performance of gas-condensate wells under both steady and non-steady state conditions has received considerable attention in recent years. The theoretical aspects of such flow has been studied by several authors. In order to test these theories, one should have reliable data with sufficient accuracy but very often such data are not available.
Low Salinity Polyglycol Water-Based Drilling Fluids as Alternatives to Oil-Based Muds
Authors: Bland R. G. , Smith G. L. , Eagark Pasook 
Published: December 2007

ABSTRACT
Both laboratory and well site data are presented on the use of high performance water-based drilling fluids containing chameleonic or TAME polyglycols. The laboratory results support a new mechanism for shale stabilization by these polyglycols and provide design criteria for optimizing their application. The well site data demonstrates an effective and efficient application of the design criteria for land-based drilling with a freshwater system. The field results show that chameleonic or TAME polyglycols can cost effectively replace invert emulsion and high electrolyte systems without the use of electrolytes to eliminate disposal costs and liability.
The Petroleum Industry and Environmental Concern
Authors: Hilpman Paul L. 
Published: December 2007

Abstract
Unchecked growth of the world's population, coupled with per capita population, coupled with per capita increases in resource consumption and waste production has given rise to anxieties about the future of mankind. The past decade has produced intensified concern for the integrity of earth's ecosystems. Although the petroleum industry has contributed much petroleum industry has contributed much toward the physical comfort and industrial might of modern society, it has also unwittingly contributed to excessive waste and environmental deterioration through its somewhat limited perspective. By action and influence, the industry can do much to ameliorate these conditions through programs of remedial engineering and programs of remedial engineering and hydrocarbon conservation.
Efforts in remedial engineering should be comprehensive enough to not only eliminate pollution of our coastal waters and estuaries by leaking wells, pipelines and tankers, but also to arrest contamination of surface water and ground water systems. Hydrocarbon conservation programs should ensure that fossil fuels (petroleum, natural gas, and coal) are conserved for uses that cannot be met by other resources. Furthermore, extraction processes employed in the future must be chosen on the basis of reserve-recovery ratios rather than the rapidity of investment returns.
Introduction
Since the dawn of civilization mankind has felt a kinship with the earth upon which he builds his homes, factories, roadways, and from which he obtains resources and energy to satisfy his ever growing needs. Rich have been the rewards for application of knowledge, but we have paid a high price for ignorant abuse of the price for ignorant abuse of the environment. On a short term basis, mankind can ignore natural laws, but nature, at a time of her own choosing, will present her bill to future generations for such liberties.
The decade of the sixties has witnessed the emergence of a broad ecological conscience within society suggesting that man is becoming more concerned about the day when he must pay his debt to nature. pay his debt to nature.
Do Shales Swell? A Critical Review of Available Evidence
Authors: Santarelli F. J. , Carminati Stefano 
Published: December 2007

Abstract
A vast majority of drilling problems occur in shales. The traditional explanation is that Shales swell when contacted with water. As the use of oil based muds becomes more difficult, recent years have seen a large numberof publications dedicated to the study of water/shale interaction.Unfortunately, this large body of evidence contains too many contradictions to be trusted as a sound basis for engineering. A two years long critical review of this material was therefore undertaken revealing that most experimental observations performed in the laboratory were not representative of downhole conditions as air or water vapor had been introduced in the samples, leading to capillary phenomena which have been mistaken for swelling. Further observations revealed that true swelling is unlikely to be an issue downhole. Upon contact with drilling fluids, the occurrence of mineralogical transformations affecting the shale was identified and it was further shown that such transformations will affect the mechanical response of the rock.
Preliminary Report on Effectiveness of Different Lubricants on Wear and Friction Coefficients Using Shale Medium
Authors: Hale A. H. , Albrecht M. S. , Roy Sanjit , Dzialowski Andrew , Mody F. K. 
Published: December 2007

ABSTRACT*
Earlier experimentation demonstrated that the friction coefficient and wear of shale were highly dependent upon the chemistry of the drilling fluid. Since 70% of the formations drilled are shale, it was important to determine what additives might reduce wear of shale by a tool joint and/or lower the friction coefficient between a drillstring and shale. An examination has been undertaken to determine the effectiveness of various additives to alter the coefficient of friction and reduce wear on shale. This is an exceptionally important question when considering that most of the footage drilled is that of shale. Lower friction coefficients while drilling shale should improve the capability for longer-reach wells and reduced trouble costs. Reduced wear lowers the potential for key seating and thus limits costs. Because there is no relationship between wear and the coefficient of friction, it is important to identify reagents that can both lower the friction coefficient and reduce wear. The results indicate unique classes of chemicals are capable of lowering the friction coefficient and reducing wear. These chemicals can be incorporated into functional drilling fluids which are environmentally acceptable depending upon the concentration.
In addition results are shown which demonstrate the unique capabilities of applying an electric potential across a shale matrix. Experiments are described that demonstrate that the presence of an electric potential lowers the friction coefficient and reduces the wear in a variety of drilling fluids both water-based and oil-based. This reduction is sufficient to lower the friction coefficient on shale in a water-based mud to a friction coefficient similar to that of an oil-based mud.
Fracture Treatment Modifications and Bottomhole Treating Pressure Analysis in the Pictured Cliffs Formation, Rio Arriba County, New Mexico
Authors: Johnson Raymond L. 
Published: December 2007

Abstract
This paper describes the fracturing behavior of the Pictured Cliffs (PC) formation and evaluates the containment properties of the bounding intervals of the PC: the Fruitland formation and the Lewis Shale. Evidence will be presented on modifications to PC treatments that allowed proppant to be placed more effectively in the upper, most productive intervals of the Main PC. Bottomhole treating pressure (BHTP) analysis of modified and unmodified PC treatments will be presented in the form of history-matches using in a three-dimensional (3D) fracture model.
Continuous-Flow Gas-Lift Installation Design Utilizing Production-Pressure-Operated Valve Performance
Authors: Winkler H. W. 
Published: December 2007

ABSTRACT
The variable-gradient design-line method is a widely accepted procedure for spacing gas-lift valves (GLV's) in a continuous-flow gas-lift (GL) installation. Injection-pressure-operated (IPO) and production-pressure-operated (PRO) GLV's can be used in a variable gradient designed installation. The primary purpose of GLV's is to unload a well to the desired depth of gas injection. If the installation design is based on a constant surface injection-gas pressure (pio), the GLV's must be opened by an increase in the flowing-production pressure at valve depth (ppfD) rather than an increase in injection-gas pressure at valve depth (pioD)· PPO, also called fluid-operated, valves are opened and closed by changes in ppfD.
This paper outlines in detail the calculations for a variable-gradient continuous-flow installation design procedure based on a constant pio for spacing the unloading PPO valves. The valve spacing and port size selection includes performance characteristics of PPO GLV's. A simplified method for calculating the injection daily volumetric gas rate (qgSC) throughput of an unbalanced bellows type of PPO valve on the basis of a change in and the valve bellows-assembly load rate (BIr) is given in the Appendix.
Optimum Plunger Lift Operation
Authors: Baruzzi J. O. A. , Alhanati F. J. S. 
Published: December 2007

ABSTRACT
Operational conditions for a plunger lift installation are analyzed based on qualitative observations on a reduced experimental facility and simulations with a simple hydrodynamic model.
Despite many simplifications, model predictions for daily production and pressure behavior at the wellhead agreed well when compared with measurements in a real well.
A method is described to predict when it is possible to have liquid accumulation only in the tubing during the buildup period. It is shown that there is a minimum GLR to reach this desirable condition.
Sensitivity analysis for a typical well shows that for a given pressure there is an optimum afterflow time, and for a given afterflow time the smaller the pressure the greater the production.
Practical recommendations are given on how to obtain optimum conditions for a typical installation.
An Evaluation of Large Diameter Coiled Tubing for Subsurface Production Tubulars
Authors: Adams L. S. , Smith L. W. 
Published: December 2007

ABSTRACT
This paper provides an economic and technological perspective for use of large diameter coiled tubing1 relative to threaded tubulars for subsurface production tubing. This new advancement in coiled tubing technology can significantly reduce the expense for purchasing and installing production tubing while increasing hydrocarbon reserve recovery and providing a safer, more desirable ecosystem interrelation.
Case Histories and Laboratory Studies of Cement Sheath Deposition Inside Casing Strings
Authors: Griffith J. E. , Osisanya S. 
Published: December 2007

Abstract
This paper describes recently observed problems of cement sheath deposition on the inside circumference of a casing string. Actual job parameters and several proposed causes of the cement sheath are reviewed. The probable hypothesis for the cement sheath deposition is a combination of temperature, cement retardation, large cement volumes, and the surfactant contained in the slurry. This hypothesis was explored through the use of large-scale, physical models to duplicate the actual well problem in the laboratory.
Based on test results, the principal cause of cement sheath development is surfactant in the cement slurry. Once the surfactant is removed or retarding agent is added to the slurry, the cement slurry can be successfully placed. This paper also includes a laboratory procedure that provides for timely screening of potential cement slurries to determine sheathing tendencies.
Detecting Production Tubing Leak by Time Resolved Geochemical Analysis of Oils
Authors: Hwang R. J. , Elsinger R. J. 
Published: December 2007

Abstract
Many multiple completion wells in the Gulf Coast often develop tubing string communication through leaks that may not be detected by changes in the production log of a well. Routine geochemical analyses of reservoir fluids, however, can provide an early indication of such problems and allow timely corrective action. This paper describes detection of production tubing leak by several time re-solved geochemical analyses of oils. It demonstrates that the geochemical technique is an effective and inexpensive tool for monitoring well performance.
The technique is also capable to quantitatively determine mixes of commingled production caused by the plumbing problem.
Case Studies Suggest a Better Approach to Analyzing Collapse of Inclined Boreholes
Authors: Guo B. , Hareland G. , Boonyapaluk P. 
Published: December 2007

ABSTRACT
This paper addresses the comparison and selection of failure criteria for in-situ rocks in borehole stability analysis. Five commonly used criteria are compared with field cases for mud weight design. The result of case studies indicates that the Mohr-Coulomb criterion, Inner Drucker-Prager criterion and Middle Drucker-Prager criterion are overly conservative, and that the Outer Drucker-Prager criterion is underestimating for designing wellbore pressure to control borehole collapse. It is concluded that the von Mises criterion is more reliable than other failure criteria and should be used for borehole collapse analysis and mud weight design. Based on triaxial test data, this paper also provides failure diagrams for some reservoir rocks. These diagrams can be used as references for borehole stability analysis when similar rocks are encountered in petroleum drilling.