bluuebunny/crossref_metadata_2025_split huggingface dataset:
Marginal Oil Fields, Profitable Oil at Low Reserves : How?
Authors: Agiza M. N. , Shaheen S. E. , Barawi S. A. 
Published: December 2007

Abstract
Fields with recoverable reserves of about five million barrels of oil are considered in Egypt as marginal fields. Economics of Egyptian marginal oil fields depend on non-traditional approaches followed in developing and operating such fields.
The actual exploration, development and operating expenses and state fiscal terms were used to evaluate the sensitivity of the economic parameters of such marginal fields. The operator net present value (NPV) and internal rate of return (IRR) beside the government take are presented for different parameters used.
The purpose is to make acceptable profits out of the marginal oil fields, for the mutual benefits of both the country and the investors.
Evaluating Shareholder Value of Investment Prospects - Usefulness of Per Unit Costs and Netbacks
Authors: Radke G. A. 
Published: December 2007

Abstract
Projected finding & development costs and netbacks, when used as investment decision criteria in conjunction with the capital productivity index, are useful for selecting an optimal corporate investment portfolio. The capital productivity index is an excellent measure for ranking investments and for optimizing the use of capital resources. Projected finding & development costs and netbacks measure the potential competitive advantage created by an investment, and the message that will be communicated to investors regarding an oil & natural gas corporation ‘ s competitiveness.
These criteria should be used with caution when used to compare investment prospects across different fiscal regimes. Governments collect their take through a variety of royalty, production sharing, and general corporate tax provisions, often in differing amounts and proportions. As a result, the implications of some of the terms inherent in the definitions could be different.
A useful graphical strategic planning tool can be developed by plotting calculated capital productivity indices against varying projected finding & development costs and operating costs. The tool is useful for comparing different fiscal regimes in which a company is considering operating and for screening alternative investment prospects.
Emulsion Rheology and Flow Through Unconsolidated Synthetic Porous Media
Authors: Uzoigwe A.C. , Marsden S.S. 
Published: December 2007

Abstract
The flow behavior of emulsions through tubes as well as unconsolidated synthetic porous media is described analytically and verified experimentally.
A correlation technique was developed for the unconsolidated porous medium by coupling the rheological properties of the emulsions, determined from classical viscometric experiments, with the results from porous medium experiments, utilizing the "hydraulic-radius concept" and the Blake-Kozeny-Carman equation. Rheological characterization was carried out with a set of six capillary rheometers and particle size and particle size distribution were determined using a particle size distribution were determined using a Model B Industrial Coulter Counter.
Emulsion qualities (volume per cent of Soltrol in the emulsion) up to and including the 50 per cent quality were found to be Newtonian for the entire range of shear rate and shear stress investigated, (10 sec(-1) to 15,000 sec(-1) and 10 dynes/cm2 to 2500 dynes/cm2, respectively). The 60 and 70 per cent qualities were characterized by Newtonian behavior at low shear values and non-Newtonian pseudoplastic behavior after some critical shear rates and shear stresses, both of which depend on emulsion quality. Fluid slippage at the capillary walls was non-existent, and the rheological characteristics were found to be independent of capillary dimensions.
The theoretical model for the unconsolidated porous medium was tested by comparing the porous medium was tested by comparing the experimental and predicted friction factor-Reynolds number relationship. With forty experimental points, errors in friction factors were found to be 14.6 per cent and 17.4 per cent for the 60 and 70 per cent emulsion qualities, respectively.
The Treatment of Capital in Estimating Fair Market Value of Oil and Gas Properties
Authors: Hartsock James H. , Gruy H. J. 
Published: December 2007

Abstract
Fair market value has its origin in law and is defined as that price that a willing buyer will pay and a willing seller will sell at some point in time, with neither the buyer nor the seller under any compulsion to buy or sell, and both having equal and reasonable bwwledge of the facts. In reality, a perfect sale probably never occurs in which a willing buyer and a willing seller are under no compulsion to buy or sell and both are equally familiar with all the facts. Nonetheless, it is necessary to prepare fair market value estimates for oil and gas properties for the purpose of gift taxes, estate taxes, condemnation cases, mergers and divorce settlements.
Fair Market Value Discount Rates: Analysis of Market Sales Data
Authors: Miller Richard J. 
Published: December 2007

Abstract
The appraisal of oil and gas properties for sale or acquisition; financing; and for estate and ad valorem taxes is dependent on the knowledgeable and appropriate use of Fair Market Value (FMV) discount rates. Information from over 200 FMV property acquisitions in California from 1983 through 1994 has been obtained and evaluated to derive the effective FMV discount rate for each transaction. The analysis of the sales is based on acquisition appraisal data provided by the buyers of the properties.
Rational Is Practical: Better Evaluations through the Logic of Shareholder Value
Authors: Schuyler J. R. 
Published: December 2007

Abstract
An approach is presented for evaluating corporate project decisions in the context of shareholder value. Properly calculated, project expected monetary value (EMV) represents pre-tax EMV for the investor. Calculating after-tax shareholder value requires, principally, adjusting for tax on distributed project earnings.
Change in the certain equivalent (CE) of an investor's portfolio measures true project value to the investor. The difference between CE and EMV is shown to be minor, especially for marginal projects and when most of the risk is unique to the project. Companies wishing to maximize shareholder value can therefore apply the EMV decision rule, with confidence, as a nearly-optimal decision policy.
Optimising Perforation Performance for the Armada Gas Condensate Development
Authors: Bird K. , Dunmore S. 
Published: December 2007

ABSTRACT
The Armada field development will bring onto production three gas condensate discoveries in Quadrants 16 and 22 of the Central Area of the United Kingdom (UK), North Sea. The largest field, Fleming, will be developed concurrently with the other two deeper reservoirs, Drake and Hawkins. Over one trillion cubic feet of recoverable gas are present. Peak platform production rates of 450 MMscf/d will initially be obtained from eight wells.
The degree of underbalance has a significant impact on well performance and perforation geometry. This paper presents an experimental study to evaluate the effect of underbalance on perforation performance in the Fleming gas-condensate reservoir.
Fleming analogue rock cores were perforated with single shaped charge perforators, and flow tested under simulated downhole conditions. Nitrogen gas was used as the pore fluid for all tests. A brief description of the test facility is included. Cores were taken from outcrop rock chosen to match, as closely as reasonably possible, selected properties of the Fleming reservoir sandstone; in particular, unconfined compressive strength, porosity, permeability, grain size distribution, sorting and shape.
The perforated cores were examined in detail using flow performance comparison, rock mechanical tests, probe permeameter tests, microscopic examination and x-ray scans.
The testing and analysis has enabled:
– A comparison of the effectiveness of underbalances ranging from 200 psi to 2,000 psi based on flow performance using nitrogen gas as the pore fluid. – A comparison of the effectiveness of underbalances ranging from 200 psi to 2,000 psi based on measured perforation geometry. Therefore, a realistic measure of the in-situ perforation geometry. – An analysis of the structure and permeability of the crushed zone around the perforations created when perforating at different underbalances with nitrogen gas in the target rock pores.
Limitations of the Skin Concept and Its Impact on Success Criteria Used in Sand Control
Authors: Unneland Trond , Larsen Leif 
Published: December 2007

ABSTRACT
This paper addresses limitations of the skin concept as a parameter to diagnose and compare well performance and its impact on current success criteria used in sand control. Based on simple models for radial, hemispherical and linear flow, and supported by field examples from high rate gravel packed North Sea oil wells, this paper concludes that the skin concept is in many cases inappropriate in comparisons of inter-well performance. Since well interventions can introduce pressure drops controlled by intrinsic properties of the intervention, independent of formation permeability, it follows that added skin effects can reflect properties of the formation and not of the intervention alone. It is therefore possible that phenomena observed and documented in the petroleum literature concerning well behavior can reflect problems with the methodology instead of problems with the wells.
Limitations of the productivity index (PI) as a parameter to judge well performance are also addressed. Finally, alternative methods are discussed to analyze gravel pack performance and compare completion success.
Scale Inhibitor Adsorption/Desorption vs. Precipitation: The Potential for Extending Squeeze Life While Minimising Formation Damage
Authors: Jordan M. M. , Sorbie K. S. , Griffin P. , Hennessey S. , Hourston K. E. , Waterhouse P. 
Published: December 2007

Abstract
In this paper, results are presented from a series of scale inhibitor core flood experiments using oil reconditioned reservoir cores from four North Sea fields. Phosphonate, poly phosphino carboxylic acid, poly acrylic acid and sulphonated acrylic acid scale inhibitors were used in order to evaluate their performance prior to field squeeze application. Different methods of application were considered including both (i) adsorption/desorption and (ii) precipitation/ redissolution type squeeze treatments. The return profiles for the different types of applications and the different chemistries are compared as are the observed formation damage effects. The advantages and disadvantages are outline for these two mechanism in terms of the extending squeeze lifetime vs potential for formation damage.
It is intend that this paper contributes to the development of better designed and safer field applications of both adsorption and precipitation scale inhibitor squeeze treatments in the light of individual reservoir petrography and petrophysical properties.
The Selection and Application of Loss Control Materials to Minimize Formation Damage in Gravel Packed Completions for a North Sea Field
Authors: Hodge R. M. , MacKinlay W. M. , Landrum W. R. 
Published: December 2007

Abstract
This paper describes a laboratory evaluation of Loss Control Materials (LCM) commonly used to control fluid-loss during completions and workovers and the development of on-site Quality Control procedures for monitoring the performance of the LCM at the well site. In addition to the laboratory results, case histories are provided detailing application of the findings in gravel-packed completions.
Conoco has recently completed five gravel-packed wells in the North Sea. The gravel packs were conducted in two stages: a perforation pre-pack and an annular gravel pack. During this completion procedure, LCM was used to wash excess gravel out of the casing following the pre-pack and to control fluid-loss. Analysis of the first completion indicated production was restricted through the completion. Subsequent evaluation of the completion procedure and LCM products indicated the most likely source of formation damage was residual LCM filter-cake.
Laboratory tests monitoring fluid-loss control, rheology, and formation damage were performed on commonly-used LCM candidates. These candidates included sized-salt formulations, sized-calcium carbonate systems, and polymers from a variety of commercial suppliers. In addition to the evaluation of LCM products, remedial treatment options and a new delayed-release breaker were tested.
Based on test results, an LCM composition using sized-salt, biopolymer, starch, and a slowly-soluble, acid breaker was selected. This composition provided maximum fluid-loss control, maintained adequate rheology, and minimized formation damage in laboratory tests simulating anticipated completion conditions.
Utilization of Biologically Generated Acid for Drilling Fluid Damage Removal and Uniform Acid Placement Across Long Formation Intervals
Authors: Almond Stephen W. , Harris Ralph E. , Penny Glenn S. 
Published: December 2007

Abstract
A method of drilling damage removal is presented which uses biologically generated acid (BGA) as the stimulation fluid. The BGA solution is not reactive during the actual pumping stage which allows its displacement into the reservoir to be controlled by the relatively low permeability of the near wellbore damage. Catalytic generation of acid occurs at a controlled rate once the BGA has been injected into the formation and results in uniform damage removal around the near wellbore region.
The ability of BGA to be generated under a variety of temperature and pressure conditions and the compatibility evaluation of BGA with a variety of commonly used oil and water based drilling muds is first presented to establish some of the operational guidelines for BGA use. Drilling damage removal studies utilizing the modified API linear conductivity flow cell and carbonate material with BGA is presented to demonstrate the effectiveness of this stimulation fluid. Dual core flow test data is then presented which shows BGA's ability and HCL's inability to remove drilling damage over long horizontal intervals in carbonate formations.
Downhole Video Services Enhance Conformance Technology
Authors: Maddox Steve , Gibling Glen R. , Dahl Jeff 
Published: December 2007

ABSTRACT
Conformance Technology can be defined as "the application of processes to reservoirs and boreholes to enhance recovery efficiencies." The purpose of these processes is not to increase production but to reduce and dispose of unwanted bi-products; i.e., water, gas, sand, etc., and the associated costs generated by their disposal.
Conformance technology has been practiced in the oilfield for many years, but it is gaining in importance because of environmental and economic constraints that limit operator options for the disposal of unwanted production. The successful practice of conformance technology is dependent upon a thorough understanding of the downhole conditions in each well, as misinterpretation of downhole data can result in the application of treatment that will not successfully address the problem.
This paper describes applications for downhole video services that facilitate:
Planning of conformance technology treatments Provision of in-process treatment monitoring Confirmation of post-treatment success
Three case histories showing different applications of video services in conjunction with the planning and confirmation of treatments are presented. The first case determined fluid entry under flowing conditions and better defined which zones required treatment. The second case showed that the original well diagnosis was incorrect and that the planned treatments would not be effective, while the third case showed how a downhole video survey was used as a pretreatment analytical tool and later used to confirm a successful treatment.
Horizontal Wells – Are They Worth the Cost?
Authors: Doan Q. T. , Ali S. M. Farouq 
Published: December 2007

ABSTRACT
Horizontal and extended-reach wells are making an important contribution to world's oil production. Well over five thousands horizontal wells and drainholes have been drilled, with approximately fifteen hundreds such wells in Canada. Horizontal wells can be valuable under certain conditions, as discussed in this paper, but they are not necessarily always better than vertical wells. Horizontal well drilling and production technologies, with particular emphasis on their application in naturally fractured reservoirs, are considered in light of the North American and European experience.
The paper also discusses the current trends in horizontal well drilling, production and completion. The increasing use of coiled tubing, multilaterals drilling and underbalanced drilling are described. While horizontal wells are an important development, some care should be exercised in planning afield using horizontal wells, in particular with regard to the subsequent application of secondary recovery methods.
NodalB©: A Unique Program for Optimum Production of Sucker Rod Pumping Oil Wells
Authors: Guirados Carlos D. , Ercolino José M. , Sandoval José L. 
Published: December 2007

Abstract
Sucker rod pumping is the oldest artificial lift method used in production of oil wells. This method is usually designed and analyzed with the assistance of programs based on simplified models, such as the API RP 11L1,2, or with a wave equation simulator3,4,5. In many cases, however, a technique that permits consideration of the inflow and outflow performance of the well is a more efficient way to design and analyze an oil well. This technique, referred to as Total Analysis or System Analysis (SA), has been successfully applied to flowing and artificially lifted wells.
This paper presents a computer program developed by Intevep S. A., called NodalB©, created to perform the SA of sucker rod pumping wells. NodalB©'s unique characteristics make it a competitive program in today's market of design and optimization software. This program allows consideration of the inflow performance of the reservoir depending on the drilling scheme, either vertical or horizontal, and determination of the sensitivity of the rod pumping system to its most relevant parameters, such as: pumping speed and stroke, pump diameter, gas oil ratio, gas separation efficiency, tubing diameter, pump depth, rod string design, oil viscosity, injected diluent (diesel, kerosene, etc.) ratio, water cut, reservoir pressure, productivity index, and different production schemes (i.e. production through the tubing or through the casing-tubing annulus). These features show the power of this program as a predictive tool. NodalB© is specially applicable to design, optimization and troubleshooting of heavy and viscous oil wells, taking into account the viscosity effects in the rod pumping system.
PC-Based Interactive Technical Training
Authors: Novotny Rudolf J. 
Published: December 2007

Abstract
Write a comprehensive training manual on a technical oilfield subject, print it, and send it around the world. Six months later only a few individuals have taken the time to review, much less study the contents. Write an interactive, interesting computer program, put it on the company BBS system, and before long, every PC in the company has a copy.
Computer interactive training has been common place for years, but generally its focus is training on computer software. This paper describes a PC-based program that facilities the study and training of technical or company-related information via interactive computer operation. The program is versatile, compatible with any level of PC hardware, and easily updated.
The program prompts answers to multiple choice questions about the technical information. To prevent memorization of the questions and answers, each training session consists of answering 25 questions randomly selected from a pool of 200 questions. This approach provides the student with multiple training sessions with minimal duplication.
This paper describes the methodology and application of this type of computerized training. An explanation of the programming logic and an example of a sample session is provided.
Multidisciplinary Approach to Successful Implementation of Production Information System (PRISM)
Authors: Shariff Mahd Ridza Md , Gapalakrishnan Sri Ganesh , Francis Nelly , Mansor Raslan Abu , Daniel Davies 
Published: December 2007

Abstract
A company wide corporate and regional production database supporting all production areas was envisaged critical to the current expansion within Petronas Carigali Sdn Bhd (PCSB). A multi disciplinary project team was thus formed to analyze the requirements prior to developing, testing, implementing and training users.
PCSB has currently evolved into a mature E & P company on par with other E & P companies within the region. This expansion necessitates a common Production Information System for the efficient dissemination of vital Production Information for Production Surveillance, Reservoir Management, Reserve Assessment, Special Studies and Standardized Group-wide Reporting.
This paper will discuss all the phases involved in the project which includes Systems Requirement Study, Data Migration, System Development, System Implementation and Post-Implementation Plan.
The Design of a Submerged, Buoyant, Anchored Transoceanic Pipeline for Transporting Natural Gas
Authors: Savage Godfrey H. , Marsden Sullivan S. , Street Robert L. , Boutin Pierre L. 
Published: December 2007

Abstract
The particular case of using a submerged, buoyant pipeline, anchored below the surface energy effects, to transport natural gas from North Africa to Southern Europe is analyzed. A design, mathematical model of the pipeline with its anchoring system is presented. A typical segment of the model is analyzed to determine the maximum stresses developed in the pipeline and in the anchoring cables and the maximum motions of both the pipeline and the anchoring cables when subjected to forces due to ocean currents, surface wave action and buoyancy. The method of imaginary reactions, combined with the method of successive approximations, is used in these static analyses. Computer programs used in the analysis are referred to, but not presented. The design, mathematical model is given structural authenticity because it is based upon full scale ocean tests of the basic trimoored anchoring station component using steel cables and glass floatation units where the system withstood measured ocean current and wave forces with measured motions of only a few feet as predicted. A mathematical model of the ocean current velocity versus depth that exists for the Mediterranean location is presented. It is based upon current measurements that have been made in the area and information documented by physical oceanographers who have studied the area. This model is used to determine the drag forces used in the analysis of the structural model of the pipeline and its anchoring system.
With consideration for specific limitations on cable sizes, pipe welding speeds, and other state-of-the-art constraints on off-shore construction, and assuming several rate levels of gas delivery, the several probable diameter pipelines are incorporated into specific pipeline and anchor systems and analyzed to determine the required cable spacing, cable sizes, anchor sizes and the other important cost determining factors, including installation costs.
Finally, for various levels of predicted market demand (maximum gas rate), the preliminary capital investment, costs, and preliminary capital investment, costs, and return on investment are estimated. Critical considerations such as safety factors selected and the need for preventative maintenance are incorporated, quantitatively, in this economic evaluation.