bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Experimental Investigation of Formation Damage Due to the Induced Flocculation of Clays Within a Sandstone Pore Structure by a High Salinity Brine
Authors: Bishop Simon R 
Published: December 2007

Abstract
Formation damage induced by the invasion of low ionic strength brines is well understood and frequently documented. However, very little has been recorded regarding damage induced by very high ionic strength brines. A formation damage reaction between specific pore lining clay species and saturated salt drilling mud has been identified with the potential for significant permeability impairment in the near-wellbore region. This reaction was found during a reservoir condition core flood investigation into well performance in a field in South America operated by BP Exploration. Damage levels around 70% were recorded in reservoir core samples. Characterization of the formation damage mechanism was carried out by scanning electron microscopy. This revealed that flocculation of the pore lining clays had occurred, due to the invasion of the very high salinity brine, producing significant pore throat bridging and plugging. The type and concentration of the clays was determined in order to predict if this damage mechanism was an issue in future investigations. Further testing with an alternative drilling system showed that a non-damaging mud could be formulated for this field. A subsequent formation damage investigation into the likely impact of saturated salt drilling mud on the productivity of a North Sea field operated by BP Exploration revealed a sandstone with an almost identical clay fraction. It was predicted that the same damaging mechanism would occur. Return permeability testing confirmed this and validated the mechanism. However, in this specific case the extremely high permeability of the formation significantly reduced the impact of the pore bridging and plugging. It is recommended that when high salinity water based drilling muds are being considered for inclusion in reservoir drilling programmes the clay fractions of the formation are carefully considered to identify potentially sensitive sandstones. Specific formation damage testing should then be carried out to assess the likely impact on well productivity and whether this is acceptable.
Modeling Foams for Acid Diversion
Authors: Rossen W. R. , Wang M.-W. 
Published: December 2007

ABSTRACT
Successful foam diversion in matrix acid treatments depends on foam mobility during foam injection and liquid (acid) mobility after foam injection. We present new coreflood data for both flow regimes. At fixed quality and high flow rates, we find that foam behaves as a shear-thinning fluid with power-law exponent of about 0.6. For qualities below about 80%, when gas and liquid flow rates are varied separately, pressure gradient is nearly independent of water flow rate, as reported by Osterloh and Jante (1992) for foam below a threshold foam quality. Upon liquid injection after foam, pressure gradient falls to a steady-state value that varies little with liquid flow rate. The transition to this steady-state pressure gradient is strongly affected by gas expansion as pressure falls, which makes extrapolation from laboratory coreflood to field application tricky. However, although some gas escapes during this transition period, the foam front does not advance; that is, this escaping gas moves as free gas, not foam. These findings are intermediate between the simple quasi-Newtonian model of Zhou and Rossen (1994) and the extremely shear-thinning behavior reported by Parlar et al. (1995) and Robert and Mack (1995).
A simple new model accounts for many of the trends observed. This model assumes that foam mobility is controlled, not by foam coalescence and capillary pressure as for high-quality foams, but by trapping and mobilization of foam bubbles of fixed size. This model explains how foam mobility can be independent of liquid flow rate; why steady-state pressure gradient falls moderately during liquid injection following foam; and why this pressure gradient is relatively insensitive to liquid flow rate. Implications of the model for design of foam processes are discussed.
Evolution of Control Systems Associated with the Management of Electrical Net in a Distribution Company
Authors: Minio E.E. , Rovira J.M. , Colombo D.H. 
Published: December 2007

Abstract
This document summarizes the evolution towards the new technologies of the Control Systems within the restructurization process of a private Electric Energy Distribution Company. In the first part of the document, the control systems that the company had at the time of its privatization are described.
Following is the implementation strategy that joins technology, operatives, and organization.
Then, the architecture and organization of the Telecontrol System implemented is detailed (with a horizon of 15 years). This system serves the purpose of telesupervising and teleoperating the Transmission, subtransmission and distribution networks in the optimal technical economic conditions.
Finally, it is concluded with the future vision of the project.

Introduction
Within the Electric Energy Distribution business, one of the keys is the control of the electric process from the interconnection points, where energy is exchanged up to the point of supply to the clients.
Under this process, the objective searched for by Edenor for the control of its electrical process is Telesupervision and Telecontrol of the transmission, subtransmission and distribution networks In optimal quality and security conditions, with minimal losses, operative costs, and penalties.
Give solution to the whole acting environment of the Control Center: Operation Preparation, the Operation and the Analysis of the Exploitation Results; its integration with all the distribution systems: Complaint Center Service Quality, Network Planning, Enery Service, Client Service, Maintenance, and Energetic Balance.

2.- Situation at the beginning of service
In September 1992 and within the privatization process initiated in the electric sector of the Greater Buenos Aires, Edenor was born as one of the private Distributors.

2.1.- Installations
Edenor's electric network was (or is, being that some of the data is current) composed of:–High tension Transmission and Subtransmission Networks (levels of 220 kV, 132 kV, and 27.5 kV. Aerial lines cover 651 km and underground lines cover 492 km).–Medium tension Distribution Network (13.2 kV and 33kV. Aerial lines: 3,201 km; Underground lines: 2,954 km).–Low tension distribution network (levels of 380/220 V. Aerial lines: 20,699 km; underground lines: 3,652km).–Substations high tension and high/medium tension (56)–Medium tension Centers (18)–Medium/low tension Transformation Centers (9357)–Clients: 2,100,000
Legal Framework for the Enviroment Required from a Distribution Company in the Privatization Process
Authors: Rovira José María , Márquez Julio A. , Mazzei Humberto R. 
Published: December 2007

Abstract
Different organizations are showing more preoccupation for acheiving a greater performance in the protection of the environment. This growing worry has as an envolving frame a series of environmental pressures that are added to the already existing worries in the companies. It's worth noting that national and international legislation is getting stricter, the public opinion is exercising a much more severe role, consumer requirements are growing considerably in order to improve the quality of their lives, and the development must be completed within a circle of restrictive economic measures.
As a consequence of this, many companies have started to take actions, such as: environment audits, environment impact studies, etc. But these studies do not insure, within themselves, a good organization performance, they simply show us a situation regarding the follow-up of current policies, besides showing us the positioning of the company in order to meet all of the future reglementary measures. Our country has also started its part in conserving the environment on an energetic level, creating organizations at the highest government levels in order to control said policies and taking advantage of the privatization wave, establishing environmental obligations for the companies, through the regulation of their activities.
In the case of Edenor, which grants services of distribution and commercialization of electric energy, according to its Concession Agreement, it must: adequate its actions with the objective of preserving and/or improving the ecosystems involved in the development of its activity, fulfilling the policies currently in force, as well as those established in the future, destined to the protection of the environment, approved by Resolution N° 170/92 of the National Energy Department. With regards to this, we will proceed to show a brief analysis of the environmental policies in force on a national, provincial and municipal level, which directly or indirectly regulates the protection of the environment in general and, particularly, natural resources.
Investment Decisions Under Uncertainty Conditions
Authors: De Lellis V. , Ferro H. 
Published: December 2007

Abstract
The main objective of the current analysis is related to the need everyday found in the Sector, and essentially in the electrical sector, to have at hand a methodology allowing us to decide upon the convenience to perform or not an Investment, to delay or not such a decision, and mainly about the possibility of establishing the degree of uncertainly contained in each of the explanatory variables (prices, demand, rates, etc.), allowing to reach the maximum profits with the least Riski.
There are two levels of problems to solve. The first on refers to the decision of establishing the opportunity for an investment, and the second, is the conceptual and highly conflictive problem posed by the need to differentiate the classical technical-economical analysis based on the marginalist theory from the managing aspect of the financial investment which, in its search of maximum performance (profit), is not necessarily reached through the marginalist theory.
Current experience in Califomia-Oregon (COB) and Palo Verde, the Scandinavian countries, New Zealand, and Cammesa, permits to suggest the convenience to implement an auction system allowing to bring face to face both the offering parties (producers) and the demand parties (distributors, major users, etc). They should confront the contingency and, not necessarily, should they be guided by the economical optimums, thus reaching spot prices which could be under 20 US$/MWh.
Regional Energy Interconnection Gas Pipelines vs. Power Transmission Lines Comparison
Authors: Carranza Hugo Alberto 
Published: December 2007

Abstract
The countries of the Southern Cone of America are experiencing deep changes in their Energy area. The sustained growth in the demand of energy, in some cases at a yearly rate exceeding 7%, and the need of maintaining the long term cost of energy within competitive values, are moving the region to a higher energetic integration and to a diversification and optimisation of their resources.
Within this new transformation scheme, the existence of large natural gas regional reserves, plus the technological advances in thermoelectric generation, using combined cycles with natural gas, and with an efficiency near to 60%, offer clearly the lower cost long run marginal alternative for power generation. The great distance that exists between the gas fields and the consumer markets, the rates of growth and the concentration of the demand in certain areas, the need for the conversion of the electrical frequency amongst Brazil and the countries of the region, are subjects that have their influence and condition the decisions regarding investments in energy. In this context, the selection of the means for transporting the energy, by Natural Gas Pipelines (NGP) or Electrical Power Transmission Lines (EPTL) is starting to be an interesting subject of study for the specialists in energy.
The technical and economic comparisons performed between both transmission means allows us to arrive at some conclusions regarding the future range of application of each technology. This study submits the conclusions of the above mentioned comparison. It also shows the methodology used for its application to different situations than those assumed.
Gas Geopolitics in the Mercosur Countries
Authors: Barreiro Eduardo M. 
Published: December 2007

Lic. Eduardo M. Barreiro

Abstract
In a world context in which the economy tends to globalize; in which the oil prices are the same in any point of the planet, only depending on the API gravity and sulfur content, to speak of "Gas Geopolitics in the Mercosur Countries" seems redundant and old fashioned.
In the concept of "geopolitics" a local connotation is implicit, particular and different of the rest of the world; therefore opposed to the globalization concept.
But the globalization is not yet valid for the natural gas.
Its value is not the same in United States, in Europe or Japan. Neither the prices, nor its oscillations, nor the contracts, are equal; there are market differences. This is due to a fundamental motive: transportation. To transport gas is more expensive than to transport oil.
If transported by pipeline, same pipe diameter transfers only 1/5 of the implicit energy in the crude transportation. The needed investment in the gas pipeline construction is higher (pretreatment plants are more complex, safety procedures are strict, control systems much more expensive). The cost is much higher if the gas is carried by ship; LNG transports demand a previous liquefaction process, transportation in a special and dedicated ship, more expensive than an equivalent tonnage oil tanker, and the regasification at the arrival point.
The World Gas Market has been divided in three main geopolitical regions:Canada/United States/MexicoNorth Africa/Europe/C.I.S. RepublicsJapan and North Pacific Countries.
Up to now, South America and specially the Mercosur countries have been ignored as an emergent geopolitical new area, because its emerging gas market only recently started to be delineated.
But in spite of the fact that is new, possibilities are big. With potential markets which foreseeable characteristics are presented in this work, and providing countries that can supply gas reserves for those markets, Mercosur is appearing as a new geopolitical area to consider, and in a region for large investments in production, transportation, distribution and natural gas utilization.
Nevertheless, the development will not be as explosive as has been outlined by some authors; it will be slow. The bottle neck is not only the huge amount of money needed for the necessary investments, but the time that will take the accomplishment of the needed infrastructure works. The historical conversion process to gas use in Argentina, first gasified country of the region, will be analyzed, and the analogies and differences with the other countries are going to be outlined.
Gas reserves, that exist in the countries in several basins to cover the supply to other member countries, are going to be presented.
The necessary transportation infrastructure to send natural gas to other Mercosur markets will be summarized.
With this work I shall try to present a photograph of this new geopolitical area for the natural gas, to define it, and to incorporate it by own rights into the other geopolitical areas of the world.
Horizontal Well and Extended Reach Technologies with Reported Problem Areas and Operational Practice in North America and Europe
Authors: Crouse P. C. , Tada H. , Takeuchi T. 
Published: December 2007

Abstract
In 1994 and 1995, studies were initiated to investigate developments, activity, and philosophies of the larger oil and gas industry in implementing horizontal well and extended reach technologies. North American and European operators, contractors, service companies, government authorities, and educational institutions were interviewed directly along with the development of data resources and references. Over 100 people shared in direct interviews, constituting 13 operators in Europe, 14 operators in North America, 2 drilling contractors, and 5 major manufacturing/service companies. Over 40 person-to-person interviews were accomplished in North America and Europe. Interviews along with approximately 1000 references and industry well information provided a detailed look at horizontal well and extended reach technology industry along with application strategy and philosophy. This paper is essentially the same paper as IADC/SPE 350548 except certain sections were not included and sections added encompassing other areas investigated over the two years.
Gas Frac - A New Stimulation Technique Using Liquid Gases
Authors: Hurst R.E. 
Published: December 2007

Abstract
Gas Frac is a fracturing treatment using a new and absolutely water-free fluid system. The fluid is liquefied petroleum gas and liquid carbon dioxide mixed in such a ratio that they remain a liquid and behave as other liquids as long as they are under adequate pressure and below their critical temperature. After the fluid is heated to this temperature in the reservoir and pressure released, the liquid reverts to a gas. This results in extremely rapid clean-up and no residual fluids are left in the formation.
Gas Frac was developed especially for gas well stimulation. Results to date have proved the technique to be very successful.
This paper discusses the technique of Gas Frac and the materials and equipment used. analysis of results of treatments is presented.

Introduction
Many gas bearing reservoirs have resisted stimulation from conventional methods of liquid injection. Expected stimulation results often are totally or partially offset because of liquid retention by the reservoir. Core testing on many reservoir rocks, especially those with pore structures displaying a high surface area pore structures displaying a high surface area (pin point porosity), verifies this type of damage.
Frequently, liquid retention damage was credited to water sensitivity when water, brine, or acid was used as the treating fluid. It is recognized that water sensitivity is a real problem and frequently adds to the complications problem and frequently adds to the complications associated with liquid retention. When oils were used in gas reservoirs with negative results, the problem was related to the creation of a third phase.
Without becoming involved in the academic merits of classifying negative stimulation results according to the aforementioned problems, a new stimulation fluid has been created which can be useful in the prevention of liquid retention and/or water sensitivity. For these reasons, this new fluid will have widespread application in gas reservoirs and to a lesser degree will prove its value in many oil wells. The new stimulation fluid is one composed of liquefied petroleum gases and liquefied carbon dioxide in varying volumetric proportions such that the resultant liquefied gas can be used to perform hydraulic work, then allowed to perform hydraulic work, then allowed to volatilize at reservoir producing conditions.
Application of Coiled Tubing Drilling Technology on a Deep Underpressured Gas Reservoir
Authors: McGregor B. , Cox R. , Best J. 
Published: December 2007

Abstract
In November of 1996, Apache Canada drilled a gas well with coiled tubing in the Harmatten Field northwest of Calgary. A a true vertical depth of 2572 metres, the well was the deepest successful coiled tubing horizontal well in Canada to date. The reservoir was underpressured with a pressure gradient of 6.5 kPa per metre. The well was drilled and cased to 90 degrees with conventional rotary drilling operations, after which a coiled tubing unit was rigged on and the horizontal section of the well drilled underbalanced. A total of 368 metres of underbalanced 120.7 mm wellbore was drilled, which included two open hole sidetracks. Gas production rates during drilling were in the range of 5-6 MMSCFD, and reservoir gas contained approximately 0.5% hydrogen sulfide.
This paper will describe the equipment and associated drilling performance for this operation, and will elaborate on open hole sidetracking capabilities. Drag modeling, tubing lockup, and potential lateral extent for drilling at these depths will also be assessed.
Advances in Sliding Sleeve Technology and Coiled Tubing Performance Enhance Multizone Completion of Abnormally Pressured Gulf of Mexico Horizontal Well
Authors: Plauche Ricky , Koshak W.E. Skip 
Published: December 2007

Abstract
Advances in sliding sleeve technology combined with improved coiled tubing services have resulted in the successful completion of an abnormally pressured, multi-zone horizontal producer. An operator was planning to develop a horizontal completion in the Gulf of Mexico and required a design that would successfully address certain unusual reservoir conditions; i.e., the primary zone was abnormally pressured, and below the primary zone, there was a secondary reservoir that could not be accessed unless an additional well was drilled or the initial well depleted and a sidetrack performed.
To enhance the economic and operational feasibility of the completion, the operator needed a well design that would address the above pressure conditions and allow production from either or both zones.
This paper will discuss the methods and equipment that were used to successfully provide the project needs.
The completion configuration that was finally adopted utilized a concentric production string with pre-packed gravel pack screens, an external casing packer and multiple sliding sleeves in the concentric production string to provide the zonal isolation as well as wash-down capability since wash pipe would not be run. Significant in the success of the completion was the use of computer simulation of the coiled tubing operations to confirm capability to provide the required forces, and the use of a new sliding sleeve device that only required 500 pounds of shifting force to operate as opposed to three to five times that amount normally required to shift conventional sleeves. In addition, the sleeve had demonstrated superior operational integrity in conditions similar to those expected in this completion in which shifting forces usually caused premature equipment erosion.
The case history will provide information concerning the development of the completion as well as the actual completion scenario and how the completion design allowed fluid losses to the formation to be minimized during the completion phase.
This success demonstrates the capability to complete in several zones with isolation potential in abnormally pressured reservoirs and in completions with depths in excess of 13,000 ft. The use of advanced coiled tubing techniques and the new sliding sleeves that could maintain operational integrity in extremely corrosive environments enabled the job parameters to be met.
Serviceability of Coiled Tubing for Sour Oil and Gas Wells
Authors: Cayard M.S. , Kane R.D. 
Published: December 2007

Abstract
Coiled tubing is an extremely useful tool in many well logging and workover applications in oil and gas production operations. Several important concerns regarding its use include the need for improved guidelines for the assessment of mechanical integrity, fatigue damage, and the effects of hydrogen sulfide in sour oil and gas production environments. This paper provides information regarding the use of coiled tubing in sour environments with particular emphasis on sulfide stress cracking, hydrogen induced cracking and stress-oriented hydrogen induced cracking and how they work synergistically with cyclic cold working of the steel tubing.