bluuebunny/crossref_metadata_2025_split huggingface dataset:
Layered Waterflood Surveillance in a Mature Field: The Long Beach Unit
Authors: Woodling G. S. , Taylor P. J. , Sun H. H. , Nguyen Q. N. , Brix T. R. 
Published: December 2007

Abstract
Techniques for allocating historical production (oil and water) by layer for individual producers and waterflood patterns are presented. Production splits were approximated from offset injection histories (i.e. spinner profiles, hydrocarbon pore volumes injected, proximity to injection, and injection timing). The techniques presented include the following by layer:Production Gross & Oil Bubble MapsWater Cut MapsInjection Streamline MapsPattern Performance Graphs
The tools are extremely useful and rapid when well counts and production histories are extensive such as in the Long Beach Unit with 1200 wells and 27 years of waterflooding. Reservoir material balance and pressures are not used in the split logic for a well but checked later for each pattern. Predicted splits and water cuts compared favorably with fullfield reservoir simulation results and field production logs.
The allocation logic works in stratified formations where reservoir cross flow is minimal. Shales or other barriers between zones are required. The logic also requires that injection profiles, pressures, and injection-withdrawal ratios remain relatively constant. However, the logic can be applied over incremental time steps to handle dynamic changes in these parameters.
Coning Phenomena in Naturally Fractured Reservoirs
Authors: Al-Afaleg N. I. , Ershaghi Iraj 
Published: December 2007

Abstract
Development of water coning in naturally fractured reservoirs and the issues of critical rates and cone breakthrough times are examined in terms of appropriate reservoir properties. A correlation is proposed to account for fracture acceleration effects in the computation of critical rates and the breakthrough times for uniformly distributed fractures. For a fractured systems with non-uniform fracture distribution, cone development is asymmetrical and the concept of partial completion to prevent coning becomes inapplicable. As such, for heterogeneously fractured reservoirs, estimation of critical rate and breakthrough time requires modeling with an understanding of fracture pattern around the producing wells.
The Effects of Injectant-Enrichment Level on Oil Recovery in Horizontal, Gravity-Tongue-Dominated Enriched-Gas Drives
Authors: Chang H. L. , Lo Tak Sing , Ring W. W. , Weisbrod K. R. 
Published: December 2007

Abstract
Experiments and simulations showed that the oil recovery behavior of horizontal, gravity-dominated, enriched-gas corefloods is distinctly different from that of one-dimensional slim tubes or corefloods. Additional oil was recovered when the injectant was enriched beyond the one-dimensional minimum miscibility enrichment (1-D MME) level. Mechanisms controlling oil recovery at different injectant compositions are discussed.
Vertical Sweep Efficiency and Oil Recovery From Gas Injection in Heterogeneous Horizontal Reservoirs
Authors: Belgrave J. D. M. , Win Than 
Published: December 2007

ABSTRACT
Many field tests have demonstrated that without the benefit of gravity stabilization gasflooding operations usually result in low vertical sweep efficiency due to gravity override. For this reason horizontal or low relief reservoirs, which constitute a large fraction of hydrocarbon bearing formations, are generally not considered to be good candidates for recovery schemes involving gas injection.
A cross-sectional reservoir simulation study was undertaken to investigate the effect of vertical heterogeneity, viscous/gravity force ratio, and perforation thickness on oil recovery from gas injection in horizontal reservoirs. Three types of reservoir systems were considered: (a) homogeneous, (b) deltaic channel sands, represented by vertically decreasing layer permeabilities, and (c) deltaic bar sands, represented by vertically increasing layer permeabilities. The degree of reservoir heterogeneity was systematically varied and characterized by the Dykstra-Parsons coefficient.
For the homogeneous reservoir, vertical sweep efficiency and oil recovery at breakthrough were found to increase with increasing gas injection rates. On the other hand, over most of the ranges of viscous/gravity force ratio and degree of heterogeneity investigated, channel sand reservoirs tended to give increasing breakthrough oil recoveries for decreasing rates of gas injection. Deltaic bar reservoirs exhibited more complex behaviour.
At low heterogeneity levels these reservoirs gave higher oil recoveries at higher injection rates, and reversed this trend as the degree of heterogeneity increased.
Included in the paper are gas saturation breakthrough patterns, which show the influence of geological and operating conditions on the location of uncontacted oil.
Planning a Coiled-Tubing-Conveyed Production Logging Job in a Horizontal Well
Authors: Copoulos A. E. , Costall Douglas , Nice S. B. 
Published: December 2007

Abstract
Planning is an important part of a successful coiled-tubing-conveyed horizontal well production logging job. Close coordination between a multidisciplinary team, including the operating company’s production engineer, reservoir engineer, field supervisor, and the logging and coiled-tubing company representatives is required. Without a proper balance of input from these individuals, conflicts can arise, costly downtime can occur, and data can be lost. To avoid these potential problems, prejob planning should be considered a necessary and cost-effective part of the coiled-tubing-conveyed horizontal well production logging job.
The multidisciplinary team should jointly address reservoir, operational, and production issues. Reservoir issues include reservoir performance, gas-, oil-, and water-contact identification, fault and fracture identification, variations in rock quality, and productivity. The production issues include instrument selection, wellbore trajectory, rig-up technique, and costs, while operational issues include centralization, drag buckling, equipment compatibility, and a variety of miscellaneous on- and off-site equipment checks. By jointly addressing these and other issues with a multidisciplinary team prior to the job, costly downtime will be minimized, and logging objectives will be more clearly defined and easily achieved.
3D Boundary-Element Model for Predicting Performance of Horizontal Wells
Authors: Koh L. S. , Tiab Diebbar 
Published: December 2007

Abstract
Potential benefits in increased productivity and recovery efficiency coupled with advances in drilling and completion technology have roused considerable interest in horizontal well applications. Since horizontal well systems are characteristically less symmetric (compared to vertical ones), and horizontal wells typically penetrate the reservoir more and in paths that are more tortuous, the flow field and pressure distribution created by such wells can be expected to be three-dimensional in nature and thus be more susceptible to irregularities in geometry and other system properties in three dimensions. There is thus a need for developing predictive tools that adequately describe three-dimensional fluid flow through porous media in realistically complex situations. This need represents the main motivation of this work.
Through the years, both analytical and numerical methods have been used to solve partial differential equations governing engineering problems. Analytical solutions are the most desirable since they are exact and continuous. Unfortunately, they can be obtained only for relatively simple and idealized cases. This has led to the development of various numerical methods which are able to solve more complex and realistic problems. The finite-difference and finite-element methods (FDM and FEM) have been the most widely used numerical techniques in general; in petroleum engineering, however, the use of the former is almost exclusive. The boundary-element method (BEM) is an emerging technique that has gained considerable research attention and popularity in recent years. It offers several potential advantages over the FDM and/or FEM, including Lesser modeling effort, due to the reduction of the dimensionality of multi-dimensional problems by one;Greater numerical accuracy, due to its "semi-analytic" nature and the elimination of grid orientation effects and numerical dispersion; andBetter problem representation, due to its ability to conform better to complex geometries and boundary conditions.
The technique has been successfully applied to many diverse fields. It has only been used to a limited extent in petroleum engineering, however.
Non-Darcy Gas Flow: From Laboratory Data to Field Prediction
Authors: Milton-Tayler David 
Published: December 2007

ABSTRACT
The beta factor, or Non-Darcy flow coefficient is the critical parameter in determining the performance of propped hydraulic fractures in gas wells. In addition, non-Darcy effects enter into the analysis of laboratory-derived gas permeametry data, of reservoir core, and its extrapolation to the field.
In this paper, both the beta factor and the Klinkenberg slip constant are investigated. Flow tests under carefully controlled conditions have been completed in consolidated and unconsolidated media. Anomalies in the beta factor can be readily dealt with as far as proppant packs are concerned, but their implications for gas permeametry in consolidated core may be more serious.
Developments for Reducing Natural Gas Treating and Processing Costs
Authors: Leppin Dennis , Gamez J. P. , Meyer H. S. 
Published: December 2007

ABSTRACT
The Gas Research Institute (GRI) has an R&D Program directed towards natural gas processing issues. Of particular interest is research on problems connected with small-scale subquality natural gas processing. Both fundamental, knowledge-building and applied research are carried out.
Processes and hardware developments in gas processing from this program which are at or near commercial introduction are reviewed. Included are the MVC Multivariable Process Control Optimization, R-BTEX process, and lithium bromide (LiBr) absorption chiller applications in gas conditioning. Obtaining significant technical information on performance of new gas processing technology is also an important activity of GRI and selected applications in this are discussed as well. Included in this category are results oftesting of commercial cellulose acetate membranes for CO2 removal from natural gas and field evaluation of Liquid Redox Sulfur Recovery processes.
Protect the Forest With LNG
Authors: Poulallion P. L. , de Abreu Moreira L. A. , Dominguez J. L. R. 
Published: December 2007

ABSTRACT
The temptation to build a gas pipeline in the Amazonic Forest or an electric transmission system is very strong when you have not knowhow or enthusiasm to develop a new technology. Nevertheless, after a long story, the most sympathetic project was achieved to transport Natural Gas from Urucu to Manaus and Porto Velho.
Beyond a sympathetic point of view, it is also possible to get a good benefit in creation of activity for people (labor) and in efficiency of money (rentability).
The project deals with environment conditions and resolves all problems to transport natural gas on ways given by nature (rivers) and takes opportunities to develop a process to match technical specifications and economics.
Protect the rain forest with LNG is to show how human "profitability can be enhanced in tomorrow's environment".
Main points will be discussed: modular Unit for liquefaction versus scale factor; electric driven compressor versus turbines; air cooler versus refrigerated water; light self container barge versus integrated barges for transportation; fractioning with energy recuperation versus simple vaporization.
A Horizontal Well in Gas Storage: A Case Study
Authors: Bergin S. R. , Shikari Y. A. 
Published: December 2007

ABSTRACT
Enhancement of deliverability has always been a top priority for storage field operators. Historically, all available enhancement techniques have been tried, with varying and occasionally negative results. The recent and rapid development of horizontal drilling technologies has given storage operators another method for consideration.
There are several geological and reservoir engineering aspects in evaluating a potential horizontal storage well project. If favorable conditions exist, a multidisciplinary approach is needed for the design and implementation of a successful project. This paper discusses the methodology and results of a successful horizontal storage well project conducted jointly by Oklahoma Natural Gas Company ("ONG") and the Gas Research Institute ("GRI").
Mitigating Horizontal Well Formation Damage in a Low-Permeability Conglomerate Gas Reservoir
Authors: Cimolai M. P. , Gies R. M. , Bennion D. B. , Myers D. L. 
Published: December 2007

Abstract
In the application of horizontal well development to the Cadomin formation in the Deep Basin gas field of west central Alberta, control of formation damage to a low permeability, thin pay reservoir is of critical importance. Under the current fiscal regime the economics of the limited single well reserve potential does not allow for remedial operations after rig release. The horizontal well is, of necessity, the required stimulation to the reservoir and the drilling of the formation is the completion process.
The two primary formation damage mechanisms which must be controlled are aqueous fluid entrainment and drilling fines invasion which are significantly greater concerns in horizontal wells due to the intrinsically deeper reservoir penetration and longer exposure times. From laboratory studies, the Cadomin is undersaturated with respect to the capacity of the formation to retain water. Invasion of the zone by an aqueous phase doubles the irreducible water saturation within the reservoir severely reducing the relative permeability of the matrix to gas. Coupled with the entrainment of drilling fines, permeability can be impaired by an order of magnitude. In engineering for these conditions in the Cadomin, a viscosified clear diesel drilling fluid was designed incorporating sodium chloride as a bridging agent to permit near balanced drilling.
Reviewed in this paper is a case study describing a history of operations to characterize the formation and the field results of two Cadomin horizontal wells drilled with contrasting aqueous and diesel based fluid systems.
The New Keys to Deliverability: Storage, Imports, and Resource Development
Authors: Kaplan S. M. 
Published: December 2007

Abstract
Gas storage and Canadian imports have become key sources of winter natural gas supply for the U.S. The use of storage and imports to meet winter peaks has reduced the importance of domestic deliverability; by extension, this means that a lower level of resource exploration and development will support current and future demand. However, the growing use of storage may lead to price instability and may increase the risk of spot shortages and curtailments during the summer.
Streamlining Gas Production at Low Gas Prices: Activity-Based Costing for the Gas Production Process
Authors: Lechner H. E. 
Published: December 2007

ABSTRACT
This article describes an economic model which allows calculation of the contribution of a single gas well or a single gas field to the overall operating result of a company. Moreover, this system makes it possible to assess various measures taken at an individual gas well or gas field and the respective effects on the company's operating result. It permits fixing of the ‘stars’ and the ‘dogs’ at any market condition and to find not just one but the optimal solution for our producing properties. A cost accounting system for 3 different levels of decision making (production, well, field) was developed based on contributed margins. By applying previous cost information and future cost estimates, this system provides the required data for making sound business decisions. An example describes how this cost accounting system which is based on contributed margins, was applied. Additional options for the application of this system are outlined.
Use of Vogel's Inflow Performance Relation for Coal Wells
Authors: Seidle J. P. , Erickson D. J. 
Published: December 2007

Abstract
Deliverability of coal wells, like conventional gas wells, depends on bottomhole flowing pressure. Because coal wells often produce both gas and water, lowering bottomhole flowing pressure to increase gas rate also increases water rate. Thus, optimization of coal well profitability entails balancing gas revenues and water disposal costs. The present study was undertaken to determine if the relation between coal well bottomhole flowing pressure and gas and water production rates could be described by Vogel's Inflow Performance Relation (IPR). First, simulation studies were done to test the applicability of Vogel's IPR to coal wells. Secondly, productivity of actual coal wells was compared with Vogel's IPR curves.
Productivity of an oil well draining a solution-gas drive reservoir was investigated by Vogel1 using numerical simulation. A total of 21 simulations covering a wide range of oil, PVT properties, and relative permeabilities were made. By using dimensionless pressures and rates, Vogel found well productivity could be described by
(1) q q max = 1 − 0.2 p w f p a v g − 0.8 ( p w f p a v g ) ) 2
where q is oil production rate in bpd, qmix is maximum oil production rate in bpd, pwf is bottomhole flowing pressure in psia, and pavg is average reservoir pressure in psia. Eq. (1), called Vogel's Inflow Performance Relation (IPR), was found to describe simulated well productivity with a typical accuracy of 10%. Errors as high as 20% were noted for simulations of viscous crudes and/or damaged wells with skin factors great than +5. Over the last quarter century, Vogel's IPR curve has been extensively used to predict oil well performance. Because of this success, the question arose as to whether Vogel's IPR could also describe gas and water production from a coal well.
Fracturing Process Control and Automation: Phase 2
Authors: Stephenson S. V. , Woodall E. L. , Donaghe C. D. , Dant R. E. 
Published: December 2007

Abstract
Since the publication of Fracturing Process Control and Automation Phase 1 (SPE 17315), the entire automated and remote controlled fracture stimulation system has been placed into production globally with hundreds of jobs successfully accomplished and documented.
Phase 1 presented the organizational approach to creating the system. Mechanical equipment, computing equipment and software, operating procedures, and documentation requirements were also discussed in the first paper.
Phase 2 of the project involved: (1) a new design concept for a slurry processor, (2) creating software for the central computer in the control and engineering center, and (3) improving the proppant handling equipment. In addition, fluid monitoring systems were developed.
This paper will present the unified automatic fracturing process control system. Comparison of the advantages and disadvantages of automated, semiautomated, and manual systems will be made. The management task for technology transfer from dedicated design team to design and manufacturing staff and from prototype to full production equipment will be examined.
Graphical User Interface for Existing Field Automation Systems
Authors: Glynn C. J. , Crockett J. R. , Smith C. O. 
Published: December 2007

Abstract
Field automation systems provide an enormous amount of information. In older existing systems, this information is presented to the field staff as text. Significant improvements in the staffs effectiveness and efficiency can be achieved by utilizing a Graphical User Interface. However, quantifying these improvements is a difficult task.
Improved Material Balance Calculations by Coupling With a Statistics-Based History-Matching Program
Authors: Hwan R. R. 
Published: December 2007

ABSTRACT
This paper describes a new material balance calculation by coupling a statistics based history matching program with a material balance program. The procedure is to match the historical reservoir pressure data with the calculated pressures obtained from the material balance program – the so-called pressure match method – with the help of the history matching program.
The combination of the history matching and material balance programs proves to be a very simple and powerful tool for material balance calculations. A user who does not know different material balance methods under various reservoir conditions is able to calculate the material balance with great accuracy. This is because the new procedure is based on the pressure match method which is known to be applicable to all types of reservoirs, i.e., oil or gas reservoir with or without gascap and/or aquifer, with accurate results.
In this paper, the calculation of pressure in the material balance method is briefly reviewed and the mechanism of pressure history match is cursorily discussed. Three case studies, comprising an abnormally pressured gas reservoir, a gascap drive reservoir and an aquifer water drive reservoir, are presented to illustrate the use of the new method. The calculation results of these cases are comparable to or better than those of using the material balance program alone. Moreover, the matches were obtained in only a few number of runs.
A Computer System That Determines Optimal Capacity and Recovery for Gas Reservoirs
Authors: Dougherty E. L. , Chang Jincai 
Published: December 2007

ABSTRACT
This paper describes a C-language software system dubbed FIDOS (Field Development Optimization System) that optimizes development and production from one or more gas reservoirs producing through one or more compressor stations. The optimal schedule delivers the economic portion of a requested profile of offtake rate plus spare capacity vs time over a specified planning horizon. In order to base selection of wells or HP increments upon incremental NPV and PVR, a reservoir simulator and an economic evaluator are imbedded in FIDOS. To reduce computing time for the many simulations, the nodal analysis equations that determine deliverability are solved with a specially tailored technique. With more than one compressor station a generalized network flow model is used it-eratively to determine optimal capacity and production at each station. To preserve machine independence Postscript is used to generate mixed graphical/numerical presentations of inputs and results. An example illustrates FIDOS' utility.