bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gas-Liquid Two-Phase Flow in Pipelines
Authors: El-Oun Z. 
Published: December 2007

ABSTRACT
A combined theoretical and experimental investigation to study the behaviour and characteristics of gas-liquid two-phase flow in horizontal pipelines is described in this paper.
A simple theoretical model was developed to provide predictions of liquid hold-up in equilibrium stratified two-phase flow regimes and transition boundaries into slug flow. In order to calculate the liquid hold-up, the pressure drop equations were considered. The pressure drops in the two phases together with the shear stresses at the walls and interface were solved numerically. The criterion employed for predicting the onset of slug formation is wave instabiltiy which occurs when the wave velocity is imaginary.
The experimental study was conducted over a wide range of flow conditions to investigate pressure loss, liquid hold-up, flow pattern transitions and slug/bubble characteristics. The results presented in the paper are only flow pattern transitions and slug/bubble characteristics. The experiments were conducted on 0.2 and 0.4m, diameter, 400m long loops at BHRA for a range of superficial air and water velocitie's up to VSG = 24m/s and VSL = 2n/s.
The agreement between the experimental observations and the predictions of the transition into slug flow is considered excellent. Based on the average experimental data generated from these loops and from a separate study conducted on different fluids and pipelines, various empirical correlations for calculating the slug/bubble characteristics have been developed. Comparisons were also made between the measurements and current design methods, thus stating their range/limitations of applicability.
Phase Distribution During Gas/Liquid Flow Through Horizontal Dividing T Junctions
Authors: Hart J. , Hamersma P. J. , Fortuin J. M. H. 
Published: December 2007

Abstract
A model has been developed to the predict route preference of condensate at T junctions in gas transportation pipelines. This so-called 'Double Stream Model' has been derived from the steady-state macroscopic mechanical energy balance (Bernoulli equation), applied to the 'inlet-to-run' stream and the 'inlet-to-branch' stream of both the gas phase and the liquid phase.
The theory is applicable to the stratified-wavy and annular flow regimes, provided the liquid holdup 𝛜L&lt; 0.06. The model has been verified with experimental results carried out in our Chemical Engineering Department, using air-water flow in a horizontal tube with a horizontal tee (D1 = D2=D3= 0.051 m), and with experimental results from Institutes in the USA and Canada.
Results predicted with the Double Stream Model are in good agreement with experimental results, obtained with regular (D1=D2=D3) and reduced (D3&lt;D1) T junctions.
Enhanced NGL Recovery in the Arun Field Expander Plant Using a Low-Pressure Absorber for Maximizing Propane Recovery
Authors: Berini D. L. , Widjojo T. 
Published: December 2007

ABSTRACT
This study compares the propane recovery efficiency of an expander plant using a low- pressure absorber with that of a conventional expander plant. By optimizing the reflux rate to the low-pressure absorber, propane recoveries close to 90% are achievable. Actual operating data matches very closely with computer simulation predictions.
This paper relates specifically to the Arun Field NGL extraction facilities which are designed to process 1,000 MMscf/D [28,317 103m3/d] of feed gas.
Design, Development, and Field Test of a True Vapor Pressure Analyzer
Authors: Reed D. B. , Monday W. L. , Chou K. , Ogren W. E. 
Published: December 2007

ABSTRACT
This paper describes the development and testing phase of an on-line device to measure the True Vapor Pressure (TVP) of any liquid, but with particular application to hydrocarbons including both crude oil and refined products. The method is based on classical thermodynamic principles, and measures the TVP of the fluid in a time frame of minutes. The advantages of measuring TVP rather than Reid Vapor Pressure will be discussed, and supporting data presented. The paper describes the principle of operation, the development of the system into a field deployable device, presents results of laboratory and field tests, and describes some potential applications.
Artificial Neural Networks for Identification of Beam Pump Dynamometer Load Cards
Authors: Rogers J. D. , Guffey C. G. , Oldham W. J. B. 
Published: December 2007

1 ABSTRACT
The oiL industry, spurred by the need for cost efficiency and the loss of experts in technical areas, has begun to apply Artificial Intelligence or Expert systems. This paper details the use of a pattern recognition scheme using Fourier Descriptors and a Neural Network model to develop an Artificial Intelligence system to analyze and classify beam pumping unit dynamometer diagrams.
Hydrocyclone Produced Water Treatment for Offshore Developments
Authors: Choi M. S. 
Published: December 2007

ABSTRACT
Ever increasing water production and more stringent environmental standards have driven up the cost of produced water disposal. What was once a small consider-ation in the design of production facili-ties has become a high profile and costly component of offshore production projects.The large space and weight requirement for conventional produced water treatment (PWT) systems (skim tanks,CPI's and flotation cells) could have a large nega-tive impact on the overall economics of a deep water development.
Recent advances in static hydrocyclone technology for PWT has added an attractive alternative to conventional systems.In 1985,Conoco installed a small hydrocyclone PWT system on the Murchison platform in the North Sea. The success of that first pilot system has lead to the expanded use of the technology in other locations in the North Sea and the Arabian Gulf. With the experience gained from the design, testing and ex-tended operation of these systems, Conoco has developed a high level of confidence in defining the capabilities and limits of hydrocyclone PWT systems, and the economic benefits possible when applied to offshore projects.
Analysis of Operational Practices and Performance of Selected Gulf of Mexico Operators
Authors: Bolin W. D. , Brienen J. W. , Morgan R. L. , Pyles S. R. 
Published: December 2007

ABSTRACT
In 1989, Oryx Energy Company conducted personal interview surveys with 13 Gulf of Mexico operators to quantify various operating practices, philosophies, and techniques. Production statis-tics and economic indicators were also compiled. The companies surveyed included Amoco Production Company, Arco Oil and Gas Company, Conoco Inc., Forest Oil Corporation, Kerr McGee Corporation, Marathon Oil Company, Oryx Energy Company, Pennzoil Exploration & Production Company, Samedan Oil Corporation, Unocal, and others.
As a result of analyzing the information, Oryx undertook a major restructuring of its Gulf of Mexico operation. In addition, other survey participants have started organizational and/or operational changes of their own.
Operation and Utilization of Hydraulic-Actuated Service Tools for Reeled Tubing
Authors: Fowler S. H. , Pleasants C. W. 
Published: December 2007

ABSTRACT
The advent of highly deviated and horizontal well completions has created the need for a new line of service tools that do not rely upon gravity for the setting and retrieving of downhole tools. When using reeled tubing in downhole applications, in particular highly deviated or horizontal wells, frictional drag can limit the available forces required to set and pull flow controls, shift sleeves, shear pins, etc1 As such, tools are needed that take advantage of the pressure and flow capabilities of the reeled tubing to create an efficient system for servicing highly deviated and horizontal wells in addition to conventional vertical wellbores.
Inflow Performance Relationships for Solution-Gas-Drive Slanted/Horizontal Wells
Authors: Cheng A. M. 
Published: December 2007

Abstract
Since 1968, the Vogel equation has been used extensively and successfully for analyzing the inflow performance relationship (IPR) of flowing oil wells under solution-gas drive. Oil well productivity can be rapidly estimated by using the Vogel IPR curve and well outflow performance. However, the Vogel curve was originally developed for conventional vertical wells and may not be valid for slanted and horizontal wells. The development of IPR’s for slanted and horizontal wells by using a vertical/horizontal/slanted well reservoir simulator is presented. Several important results were observed. First, the IPR’s for slanted and horizontal wells are similar to the parabolic behavior of the Vogel IPR curve. Second, IPR data generated for slanted wells by using the Vogel curve can differ as much as 22% from that of the new IPR data and 27% for horizontal wells. Third, the right curvature shift of the Vogel curve for slanted and horizontal wells indicates that these wells are more efficient producers than vertical wells from a subsurface fluid flow viewpoint. Fourth, a minimum slant angle of 45 degrees is required to increase oil productivity by 50% over that of a vertical well. A slant angle of 60 degrees or greater can increase oil productivity more than two times that of a vertical well. The newly developed IPR data are compared with existing empirical and field data. Several application examples are presented to illustrate the use of these IPR’s to predict slanted/horizontal well productivity.
Influence of Matrix Shrinkage and Compressibility on Gas Production From Coalbed Methane Reservoirs
Authors: Harpalani S. , Schraufnagel R. A. 
Published: December 2007

Abstract
The effect of methane desorption on gas flow through coal was investigated. Adsorption/desorption isotherms were established for coal samples. Permeability of cylindrical samples to different gases was measured at simulated in-situ conditions in a triaxial stress field. Gas pressure-permeability-desorption relationship was established for helium, methane and carbon dioxide. Related experiments measured coal compressibility, and volumetric changes of coal matrix with methane adsorption and desorption.
The hypothesis that desorption of methane shrinks coal matrix, and results in increased permeability was confirmed. The increase in matrix permeability with reduction in pressure from 1000 psi to atmospheric was highest for carbon dioxide (the most adsorptive gas), on the order of a factor of five for methane, and non-existent for helium. The corresponding volumetric shrinkage of coal matrix on desorption of methane was 0.6%. When measured values of compressibility and shrinkage were used as input parameters into a reservoir simulation model, 60% more gas was produced over a five year period.
Material Balance Techniques for Coal Seam and Devonian Shale Gas Reservoirs
Authors: King G. R. 
Published: December 2007

Abstract
This paper presents the development of two material balance methods for unconventional gas reservoirs. One method is appropriate for estimating gas-in-place while the second is appropriate for making future reservoir predictions. These techniques differ from the material balance methods for conventional gas reservoirs, in that, the effects of adsorbed gas are included. Both methods are developed using the assumptions traditionally associated with the material balance approach. For estimating original gas-in-place, the additional assumption of equilibrium between the free and adsorbed gas phases is required (ie., gas desorption is assumed to be strictly pressure dependent). Simplified forms of this generalized equation corresponding to special cases (volumetric reservoirs, etc.) are also presented. No additional simplifying assumptions are required for making future reservoir predictions.
The results of both methods are compared to those of a rigorous finite-difference simulator developed specifically for unconventional gas reservoirs. These comparisons are made to determine the effects of all assumptions and the magnitude of these effects.
Due to the assumption of equilibrium, the first approach is appropriate for shut-in wells or flowing wells in reservoirs undergoing rapid desorption. The assumption of rapid desorption corresponds to reservoirs with a high natural fracture density (small primary-porosity matrix blocks) or with a high diffusion coefficient.
It is believed that the techniques presented in this paper provide basic tools currently unavailable to engineers working with unconventional gas reservoirs.
Enhanced Coalbed Methane Recovery
Authors: Puri R. , Yee D. 
Published: December 2007

Abstract
At present, coalbed methane is being recovered by means of reservoir pressure depletion. While this method is simple and effective, it is not efficient. Reduction in reservoir pressure deprives the fluids of the energy necessary to flow to the wellbore. Furthermore, there is a practical and economic limit on the extent to which reservoir pressure can be reduced. It is estimated that reservoir pressure depletion strategy of coalbed methane production will permit the recovery of 50% or less of the gas-in-place.
This paper discusses an alternate method of coalbed methane recovery which consists of nitrogen flooding a coal seam. Lab research has shown that essentially all methane sorbed on coal can be stripped by nitrogen without necessarily reducing the total system pressure. That is, methane desorption from coal is achieved by reducing the partial pressure of methane rather than merely the total pressure. Lab and modeling results are presented to demonstrate how nitrogen injection in coal can accelerate methane production rates and enhance reserves. Scoping process economics of enhanced coalbed methane production also appear to be attractive.
Future Prospects of Deep Delaware Basin Exploration
Authors: Zimmerman James B. , Long Laddie F. 
Published: December 2007

American Institute of Mining, Metallurgical and Petroleum Engineers Inc.

Abstract
The discussions and postulations in this paper are confined to formations of Wolfcamp paper are confined to formations of Wolfcamp age and older. The exploration of the Delaware basin has not followed the normal pattern of basin development. Expensive pattern of basin development. Expensive drilling costs, carbon-dioxide gas distribution, the uncertainty of future gas prices, lack of deep subsurface data, and difficulty with seismic interpretations have caused an erratic development. In addition, the Delaware basin has had to share the exploration dollar with the Val Verde basin. The first significant deep gas reserves were proven in the Val Verde basin and it was nearly 10 years before any promising reserves were found in the Delaware basin. The authors have combined data on the Delaware and Val Verde basins in order to obtain a better development history. Based on reserve prediction methods as developed by Hendricks and Moore, it is estimated that approximately 100 trillion cu ft of gas in place ultimately will be discovered in the place ultimately will be discovered in the Delaware-Val Verde basins.
In all probability, future exploration in the Delaware basin will continue to be spasmodic. Most of the new drilling in the immediate future apparently will be concentrated in the Val Verde basin once again. Although the southern part of the Delaware basin undoubtedly will continue to receive its share of exploration interest for a number of years, the northern portion offers the larger area with deep gas potential still relatively untested. It is logical to expect this area to receive its share of attention in future years.

Introduction
The future exploration prospects of any geological basin are difficult, at best, to evaluate, and pertinent geological knowledge of the area is essential. A review of the methods used by recognized authorities reveals that the best predictions are based on either a long history of reserves discovered or cumulative production. A production history of the production. A production history of the Delaware basin is almost nonexistent since most of the giant gas discoveries still are awaiting pipeline connections. By industry standards, a pipeline connections. By industry standards, a giant discovery contains over 1 trillion cu ft of gas. A comparison of discovered reserves by year of discovery does not make a satisfactory historical plot because the giant discoveries fall in a recent five-year period.
To obtain a better history, the authors have combined the Val Verde and Delaware basins, since both basins have the same geological characteristics and should be considered joint in any study of this nature.
This study is confined to reserves in formations of Wolfcamp age and older.
Study of Hydrate Dissociation by Methanol and Glycol Injection
Authors: Sira J. H. , Patil S. L. , Kamath V. A. 
Published: December 2007

Abstract
Formation of gas hydrates have been known to cause severe problems of blockages in natural gas pipelines, wellbores and natural gas processing units. Methanol and glycols are commonly used as hydrate inhibitors to control or prevent formation of gas hydrates, due to their ability to lower hydrate formation (or dissociation) temperatures considerably. For the same reason, they are very effective hydrate dissociation stimulants for enhancing gas production from hydrate reservoirs as demonstrated by a field study in the Messoyakha gas hydrate reservoir of the Soviet Union (Makogon, 1981). Effect of these hydrate inhibitors on the thermodynamic phase behavior of gas hydrates has been well established, however, no experimental data exist on effect of inhibitors on the rate of hydrate formation or dissociation. Hence, the current methods of prevention of hydrate formation by inhibitors have relied upon the thermodynamic data rather than kinetic data.
In this study, the characteristics of hydrate dissociation process during methanol and ethylene glycol injection were investigated. After formation of methane hydrates in the synthetic cores, hydrates were dissociated by injection of inhibitor solution of known initial concentration, at a constant rate. The pressure was held constant during dissociation and gas production, inhibitor solution temperature and dissociating hydrate front position were monitored continuously. Experimental results show that the instantaneous rate of hydrate dissociation is function of inhibitor concentration, inhibitor injection rate, pressure, temperature of inhibitor solution and hydrate-inhibitor interfacial (contact) area. Based upon the unsteady state dissociation data, empirical correlations for the rate of hydrate dissociation in presence of inhibitors are developed. The correlations can be used to compute the degree of enhancement in the rate of hydrate dissociation by inhibitors in applications such as hydrate prevention or production of natural gas from hydrates.
Reduction of Residual Oil Content in Produced Water at Offshore Gas Production Platform P/6A
Authors: op ten Noort F. J. , Etten J. P. , Donders R. S. 
Published: December 2007

ABSTRACT
The produced water on the P/6-A gas producing contains a residual amount of oil after primary separation treatment. This oil consists of finely dispersed aliphatic hydrocarbons with extremely small particle sizes and aromatic hydrocarbons dissolved in the water. Due to the relatively high ratio of aromatics to aliphatics, the aliphatic hydrocarbon droplets tend to remain in suspension. This renders it difficult to separate out the dispersed hydrocarbons by means of gravity and coalescence. To comply with the prevailing regulation of 40 mg/liter of oil-in-water, secondary means of oil· in-water reduction have been explored. Several technologies have been tested such as a centrifuge, a hydrocyclone, membranes and a corrosion inhibitor. Observations and conclusions from the tests are presented.
System Analysis of Oilfield Development Problems in Environmentally Sensitive Areas
Authors: Surthuthev L. , Basnieva I. 
Published: December 2007

ABSTRACT
The development of major oil fields requires considerable primary resources consumptions. Vast use of land, water and energy, negative technogenic impact influence considerably on natural environment in local and regional aspects. Implementation of improved oil recovery (IOR) methods demands additional use of energy, expensive oil displacement agents, skilled personnel, specialised equipment etc.
Multicriteria analysis of oil recovery processes by use of primary resources allows to estimate the complex efficiency and rate of natural environmental impact. To achive the solution of multipurpose problem of. rational resources consumption in course of oil fields development procedure of optimization and compromise programming is carried out. The significance of used natural resources in different geographical regions is determined by environment protection expert analysis.
Natural environment systems in such regions as the North of the West Suberia and the Kaspean lowland are very sensitive to the processes of oil and gas fields development. The permafrost conditions and easy spoiled land fertile cover, the danger of earth subsidence and possible technogenic seismicity demand thorouth analysis of oil recovery projects applicability and their environmental safety.
Complex efficiency assessment and multicriterion optimization of primary resources consumption have been done for the design versions of development of large oil fields Russkoe and Tengiz. Analysis of verious IOR methods on the basis of primary and energy resources consumption allows a better choice of natural environment saving technology and shows the direction and necessity of their further improvement. Study of possible technogenic effects caused by oil field development is of prime importence for timely prevention from negative consequences for nature in the region.
Improved Reservoir Management by Integrated Study: Cormorant Field, Block 1
Authors: Grant I. , Marshall J. D. , Dietvorst P. , Hordijk J. 
Published: December 2007

ABSTRACT
The Cormorant field, in the East Shetland Basin of the Northern North Sea, consists of four oil accumulations in the productive Brent Group. Block I, the central structure, is a 15 km long, north-south trending and westerly tilted fault block with crestal erosion.
To evaluate future development options and to provide a realistic forecasting and monitoring tool, a multi-disciplinary Petroleum Engineering study was carried out. A complete geological and petrophysical review was undertaken as an integral part of the study. This included a reservoir geological description of the main reservoir units, an analysis of the sealing capacity of the internal faults, and permeability prediction using multi-linear regression. The results of the review formed the basis for the detailed Block I 3D reservoir simulation model.
History matching identified the key reservoir parameters responsible for the observed pressure and water cut trends. These were the sealing capacities of the faults, the transmissibility between reservoir units, and the differing sedimentary fades (channel, barrier, interchannel, mouthbar, lagoonal beach) in the Etive and Lower Ness reservoir units. The facies variations were found to exercise considerable control on permeability trends and fluid displacement efficiency. Their proper description proved fundamental.
The model has been used to evaluate alternative development options. These have led to the formulation of a new development plan that should increase ultimate recovery in the order of 10% (20 MMstb) [3.2 × 106 m3].