bluuebunny/crossref_metadata_2025_split huggingface dataset:
Permeability Damage by Deposition of Colloidal Particles
Authors: Nabzar L. , Chauveteau G. 
Published: December 2007

Abstract
The formation damage due to retention of colloidal particles suspended in injection waters has been recently analyzed as consisting of four more or less overlapping steps: 1) deposition onto pore surface, 2) pore bridging, with accumulation upstream from bridged pores 3) internal cake building near non-percolation threshold and, 4) external cake formation. A new formation damage model accounting for these different steps has been recently proposed. The results reported in this paper show the consistency between model predictions and experimental results in the convective diffusion regime in the absence of pore bridging. The experiments have been carried out by injecting both negatively and positively charged well-characterized hydrophilic latex microspheres inside model granular packs made of negatively charged sharp-edged silicon carbide grains of narrow size distribution. To prevent any pore bridging, dilute suspensions of latexes having a size much smaller than that of pore throats were injected at low Peclet number.
In the absence of any energy barrier between particles and pore walls, i.e. with positively charged latexes or with negatively charged ones at high ionic strength, the model predictions assuming that the potential of pore surface is homogeneous are in very good agreement with experimental results. Colloidal particles are progressively deposited onto pore surface as a monolayer which reduces pore size and thus permeability. Maximum surface coverage is found to be that predicted by random sequential adsorption theory and the corresponding hydrodynamic thickness is equal to nearly 0.8 times the particle diameter. With negatively charged latexes at low and medium ionic strength, the results reveals that the pore surface of our model porous medium is definitely heterogeneous in term of surface potential. Since the surfaces of natural porous media are obviously heterogeneous, this heterogeneity must be taken into account in the model to predict both deposition kinetics and subsequent permeability reduction.
Modified Acidification Procedures for Deep Gas Sandstone Reservoirs Offshore Netherlands
Authors: Rodot F. 
Published: December 2007

Abstract
ELF Petroland gas wells were acidized traditionally with HC1-HF (Mud-acid)
The standard acidification procedures have been modified as follows: HF has been removed from the treatments and HCl alone is used, and in reduced quantities.The acid is followed with an overflush designed to push the acid into the sandstone far enough so all the acid can spend on the carbonates of formation. The results show a dramatic decrease of clean up time needed, and thus of the gas quantity flared.
Those simple modifications in procedures led to substantial savings, good production performance, and ecological improvements.
Determination of the Filtration Coefficient and the Transition Time for Water Injection Wells
Authors: Wennberg K. E. , Sharma M. M. 
Published: December 2007

Abstract
Injectivity decline due to particles in the injection water takes place to some degree in most injection wells. To understand and predict this decline requires knowledge of the rate of particle deposition for the water/formation system considered. The rate constant for particle deposition is commonly referred to as the filtration coefficient. The filtration coefficient is a dynamic quantity and changes with the number of previously deposited particles. Many investigators have carried out extensive theoretical and experimental work aimed at determining the filtration coefficient under varying conditions. This paper presents a review of past work and its application to injection wells. Tables presenting experimental values for the filtration coefficient as well as theoretical and empirical correlations are reproduced and evaluated. Finally, a new method of determining the development of the filtration coefficient with time, utilizing a concept of critical porosity, is outlined. In particular, this method includes a correlation for the transition time, i.e. the time when an external filter cake starts building on the wellbore.
Service Quality in the Argentine Electrical Market
Authors: Díaz L. Ruiz , Rovira J. M. , Colombo D. 
Published: December 2007

Abstract
The following is an analysis of the policies of the National Authority of Regulations (ENRE) and the effect on the quality of electric service in different sectors (Generators, transportation, distributors, suppliers and services within the electric branch, as well as the clients), and the consequences on the distributing companies.
The initial conditions of the networks of the distribution company (Edenor S.A.) are described, at the time of its privatization, the exact actions of quality improvement and the results.
The implementation of the Quality Control System is described at an individual client level, showing the earliest information obtained.
The report is based on the analysis of the current legal documentation, field information, and its processing in the computer systems that have been developed.
Processing of EFM Information as a Management Tool in the Processes of Assignment and Control in the Gas Industry
Authors: Roffo Edgardo , Seghesso Gabriela 
Published: December 2007

Abstract
The following work describes the processing and flow of the information arising from EFM devices and collected by SCADA system to be used in the different stages of the gas transportation operation.
Different type of information collected from EFM devices (instant values, hourly and daily LOGS, Event and Alanti records) is shown, as well as the processing of such information, produced by the Measurement System in order to generate audited information.
The information previously mentioned is used in the processes of Assignment and Control, through the SPAC application (Nomination, Scheduling, Allocation and Control processing System) allowing, among other tilings, to perform an accurate follow up of the received and delivered volume, as well as performing projections of such volumes at the closure of the working day.
This allows any of the parties involved to forecast and make corrective actions during the day in order to guarantee the accomplishment of the transportation schedule.
Furthermore, it is highly important to sliare consistent information between the Gas Transportation Company and its Customers who have remote access to such information by means of SPAC system.
Energy Economie Information System. Latin American Energy Organization (OLADE)
Authors: Torres Stella Mans 
Published: December 2007

Abstract
The main purpose of this report is to make a brief description of the SIEE (Energy-Economic Information System) from OLADE, with special emphasis on natural gas and the electric power sector.
Two different information areas are enhanced: The historical and the prospective ones. It is intended to present the different indicators which can be built for the various modules which integrate those two areas, and also have an outlook at the system's potentials to carry out studies easing decision making processes.
Reflections on a Downhole Steam Generator Program
Authors: Donaldson A. B. 
Published: December 2007

Abstract
Downhole steam generator development activities are discussed beginning with the Department of Energy program carried out at Sandia National Laboratories, Albuquerque, New Mexico. This was followed by a venture which was funded by a Fortune 500 company with the objective of commercializing the development work from Sandia. The activities at both facilities are discussed, with emphasis on field operations. Field projects included experience in a variety of heavy oil fields in Texas, New Mexico and California. The purpose of this "reflection" is to provide a historical record of these activities and to make projections which may be helpful in considering future extractive methods for heavy oil.
The Cost of Quitting a Stripper Well
Authors: Merklein H.A. 
Published: December 2007

Abstract
Some three out of four producing oil wells in this country are classified as stripper wells. Taken together, these stripper wells produced at a rate of approximately 1.3 million produced at a rate of approximately 1.3 million BOPD in 1970. This corresponds to about 14 percent of the total U. S. oil production. percent of the total U. S. oil production. Clearly, the decision to farm out or to abandon a stripper well assumes a status of national significance. Is that decision, as it is presently rendered, always optimal? The authors presently rendered, always optimal? The authors think not, and by presenting their case they focus attention on an area in the oil industry that has been neglected in the past. Hopefully, the paper will engender a discussion within the industry.
It is agreed that wells are often abandoned or farmed out too early, simply because they get choked to death by valid (in an accounting sense) but unrealistic (in an economic sense) and excessive cost allocations. There are two kinds of these, and both deserve review.
1. Variable costs, by definition, vary with output. More specifically, they become zero when a well is abandoned. Examples of such costs are well maintenance and repair, lifting costs, etc. But other "variable" costs are not eliminated by shutting down a well. An example would be the lease operator's wage allocation to a well, if as a result of abandoning that well, he does not pick up another one. If that is the case, his wages are simply transferred to the remaining wells. Certain concrete proposals on how to handle this problem are offered. problem are offered.
2. Fixed costs, by definition, do not vary with output rates, at least not in the short run. In the long run, they are eliminated by closing down operations and appropriate divestitures. But, as in the preceding variable-cost case, oil wells are charged with fixed costs that are not eliminated by abandoning them. For example, overhead charges currently allocated on a per-well basis are not reduced as a result of shutting down a well. They are reallocated to the remaining wells. Yet, overhead charges are typically treated as fixed costs in the oil industry. The authors propose a new system, the "variable-fixed cost" propose a new system, the "variable-fixed cost" allocation system. If instituted, it will have a major impact upon oil (and gas) production.
At the present time of rising production costs and intensified exploration activities on a worldwide scale, this paper draws attention away from what be in store, in the future and abroad, toward what is in store, now and at home. It may reverse or, at least, retard the current trend of declining average lives of oil wells that have come down to 24 years in 1970 from 30 years a decade earlier. If so, the paper will have contributed to a substantial paper will have contributed to a substantial increase in recoverable U. S. oil reserves.
The Role of Independent Oil and Gas Companies in California's Changing Marketplace
Authors: Marquez T. 
Published: December 2007

Abstract
As the major oil companies divest properties in California, the role of independent oil companies grows in importance. California is one of only two states in the country where the major oil companies dominate drilling and production. It is important for the major oil companies to have a strong, vibrant independent presence. A healthy independent oil and gas presence in California assures the majors of the following in their divestment programs: Financially capable companies to assume plugging, abandonment and environmental liabilities; Responsible acquisition companies to assure that the major's reputations remain intact; and a competitive market place.
Independents have traditionally been risk takers in other producing areas, often leading exploration and development efforts and new technologies. A greater number of independents also assure more innovation in California's oil and gas operations. This paper documents the efforts of California independents over the past decade as they have successfully filled the void left by the major oil companies divestment of California properties. Further, it is demonstrated that the health of the oil and gas industry in California has improved by the emergence of these innovative and progressive California independent oil and gas companies.
Permeability Damage from Drilling Fluid Additives
Authors: Barna Bruce A. , Patton John T. 
Published: December 2007

Abstract
This detailed evaluation of various drilling mud particulate additives indicates that the composition of fluid loss and rheology agents has a decided influence on the permeability damage characteristics of the permeability damage characteristics of the resulting drilling fluids. Research was conducted at Michigan Technological U. in an effort to quantify the loss in wellbore permeability attributable to the particulate permeability attributable to the particulate additives in various drilling fluid formulations.
Preliminary tests were performed on Berea sandstone followed by experiments with cores from the Huntington Beach field, Calif. This is an area where significant permeability damage during drilling has been reported.
Water-base laboratory muds were formulated with 1 lb/bbl of clarified Kelzan XC polymer and 6 lb/bbl of the type and size of particle to be tested. Particulate materials investigated include drill solids, calcium carbonate, bentonite and starch. The latter three were fractionated into three size ranges from -200 to -400 mesh plus an "as received" sample of each.
Permeabilities to brine, before and after plugging with drilling fluid, were used to plugging with drilling fluid, were used to evaluate permeability damage. Plugging of the cores was arbitrarily defined as the point at which the pressure drop across the drilling fluid filter cake exceeded 100 psi. The plugged core was backflushed with brine at a pressure less than 50 psi before assessing the degree of permeability damage. permeability damage. Significant differences in the amounts of permeability regain were noted for the different permeability regain were noted for the different types of particles but not for the particle sizes. The greatest damage was noted for the gelatinous starch particles. Calcium carbonate and bentonite additives, however, were found actually to improve the performance of the base fluid. This aspect may be explained by the formation of a protective filter cake that limits the invasion of gelatinous, colloidal particles. This cake is effectively removed when the flow of fluids is reversed to simulate the clean-up, which occurs when a new well is placed in production. production. The results of this study should have valuable applications in the design of drilling fluids used in partially depleted reservoirs. They may also be used in designing nondamaging well-killing and workover fluids.
Drilling the Deep Well in the Rocky Mountains
Authors: Maser A.J. , Dallas D.E. , Myers R.G. 
Published: December 2007

This paper was prepared for the Rocky Mountain Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in Denver, Colo., April 10–12, 1972. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
There are many problems associated with deep well drilling. This paper will attempt to isolate these problems more common to the Rocky Mountain area:
The care of the drilling string and corrosion problems encountered and methods of damage prevention as employed by Mountain Fuel Supply Company.
A discussion of chemicals used in conjunction with the drilling mud system to control corrosion damage to casing and drill string.
The inspection methods and means of detecting the presence of corrosives.
A presentation showing how the Rocky Mountains are affected due to the mountainous terrain in which our drilling operations occur.
A discussion of pressure control methods and equipment used to allow us to drill with an underbalanced mud system.
The training methods and programs to assure proper procedures from drilling crews in case of blowout or high pressure formation kicks. pressure formation kicks. Results and values of training program observed during actual situation on the job.
Improved Primary And Remedial Cementing With Thixotropic Cement Systems
Authors: Spangle L.B. , Calvert D.G. 
Published: December 2007

Abstract
Specially designed thixotropic cement systems often aid in cement placement and obtain adequate fill-up in areas or situations where more conventional slurries are unsuccessful. These slurries are thin when mixed initially but develop a high gel strength almost immediately after placement. The purpose of the high gel strength is to make the cement column support its own weight and thus relieve hydrostatic pressure at the bottom of the column.
Originally developed to prevent fall-back of the cement column in areas of low fracture gradients, the thixotropic systems have proved capable of solving many difficult cementing problems. They have application in shutting off problems. They have application in shutting off lost circulation during drilling patching holes in casing, and reducing gas-cutting of the cement column during cementing operations.
The thixotropic, or Regulated Fill-Up Cement, slurries have been used successfully on many wells to date. Since their use permits casing to be set through the pay sections without excessive loss of slurry to the formation, more selective and efficient stimulation treatments can be used. Thus, production increases from stimulation treatments have been two to three folds greater than in wells where conventional slurries were used.
This paper describes the thixotropic slurries and compares their physical properties with conventional slurries. Information related to the hydraulics of cementing with thixotropic and conventional slurries is included.

Introduction
There are areas where the formation fracture gradients are of such low magnitudes that obtaining good cement jobs is difficult. These formations are normally highly-fractured zones, shale zones, granite washes, glacial deposits, etc. When using conventional cement systems, the combination of the hydrostatic pressure and frictional pressure is of such magnitude that these zones will break down and receive most of the cement slurry. Even in cases where a substantial quantity of cement is not lost to the formation during placement, the cement column will recede or fall back after the well is shut in. This leaves long sections of the pipe with no cement to support it.
The usual approach to the fill-up problem under such conditions is a reduction of cement slurry density. This approach has several disadvantages due to the limits of cement weight variance.
Low Pressure Carbon Dioxide Lowers Heavy Oil Viscosity in IOR Applications
Authors: Cady Gilbert , Foster Dan 
Published: December 2007

Abstract
This paper discusses the reduction of heavy oil viscosity by carbon dioxide injection for improved oil recovery (IOR). Carbon dioxide injection is recognized as a viable injection gas for reservoir stimulation in light oil (30° API or higher) reservoirs. Carbon dioxide is also applicable in heavy oil (10 to 25° API) reservoirs since it lowers oil viscosity, swells the oil, provides component extraction, and is soluble in both oil and water. Carbon dioxide sources include natural reservoirs, extraction of carbon dioxide from industrial processes, generation by oxygen combustion in reservoirs, and thermo-converter generation at the surface. The surface-combustor provides Carbon Dioxide in areas which lack sufficient supplies and require the transportation of Carbon Dioxide by pipeline or high pressure trucks. Research and development of this versatile surface and downhole combustors continue today at several U.S. Universities.

IOR benefits.
The benefits of using Carbon Dioxide include crude oil and water swelling, component extraction, oil viscosity reduction, and reservoir pressuring.
An article by Simon and Graue(1) in 1965 indicates that carbon dioxide solution in crude oil lowers the viscosity to approximately 0.02 to 0.12 of the oil's original viscosity at 120°F. They studied 5 oils which were below 20°API and had viscosities from 58.6 to 1300 cp at 120°F. The result of their study indicates viscosity reductions from 0.025 to 0.115 at a pressure of 1000 psia.
A 1986 topical report by Chung (2) reported on the viscosity reduction in 7 heavy oils which ranged from 10°API to 21.6°API. The oil viscosities ranged from 49 to 1484 cp at various temperatures (75 to 200°F). Chung observed viscosity reductions from 0.03 to 0.15 of the original oil viscosity.
Multi-Stage Fracture Stimulations are Making Better Wells Along the Cedar Creek Anticline
Authors: Green T. W. , Besler M. R. , Zander D. M. 
Published: December 2007

Abstract
In 1996, Williston Basin Interstate Pipeline Company (WBI), a wholly owned subsidiary of MDU Resources Group, Inc., implemented a pilot program to improve production from the Eagle Gas Sands in Southeastern Montana. The program included running Formation Micro-Scanner™ Logs (FMS) logs to identify natural fractures and permeable pay intervals and using three-dimensional fracture modeling to determine the optimum fracture treatment size. By applying technologies and multi-stage fracture treatments, WBI has more than tripled gas production rates. While the optimal completion program has yet to be determined, especially in the deeper (1700+ft) horizons, all wells drilled and completed in 1996 are producing gas. This 100 percent success ratio is a significant improvement over previous years when less than 60% of the wells responded to stimulation. A savings of $420,000 was realized in 1996 by eliminating the need to restimulate 50% of the wells. First year incremental NPV increased by 20% or $11,600 per well for the 24-well program in 1996. This equates to an incremental 10-year NPV of over $335,000 per well and over $8.8 million for the drilling program.