bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gaz De France Experience in Underground Gas Storage
Authors: Hugout B. 
Published: December 2007

Abstract
Like in most of the developed gas consuming countries, the French natural gas consumption varies greatly according to the day and the season. The distribution system alone, from producer to consumer, cannot provide all the flexibility required to handle such fluctuations, due to constraints arising from natural gas purchase agreements and the technical possibilities of processing, liquefaction, and transmission facilities.
As early as 1954, Gaz de France developed underground gas storage facilities for natural gas. These facilities have proven to be the only effective way to store the large volumes of gas required. For forty years, these facilities have fully lived up to their potential with confirmed high performance They have also demonstrated that they are environmentally safe and reliable.
In 1997,15 facilities are operated in France: 12 in aquifers and 3 in salt caverns. Their working gas capacity. 11 BCM, represents roughly one third of France's annual consumption. Two new facilities, one in a large aquifer in Aquitaine and one in a gas field operated by GDF in the East part of the Paris sedimentary basin since 1994, will be commissioned early 21st century.
To carry out its facilities development program. GDF lias made continuous R&D efforts. In so doing, it lias acquired a level of know-how that is acknowledged world-wide and benefits its subsidiaries and joint companies all over the world. New R&D projects aim at optimising the performances of the existing facilities, reducing the capital and operating expenditures for the further facilities, and developing unconventional facilities close to the areas of consumption even in unfavourable geological conditions.
Looking back upon long-standing construction and operation experience at more than twenty storage facilities throughout the world, thanks to its subsidiaries. Gaz de France is willing and able to become an industrial partner in storage facility projects which will be necessary for the future development of natural gas in all its uses.
Mineral and Energy Economics - A Milestone in "Mines" Dynamic Educational Program
Authors: Pederson John A. , Rudawsky Oded , Butler J. Samuel 
Published: December 2007

Abstract
The accelerated pace of applying modern technology to improve production has been well demonstrated in the energy field and particularly in the petroleum industry during the past two decades. The change in productive capability has been manifested in expanding markets, new sources of supply, and increasing demands. As a result the impact on the markets, especially in the form of substituting one source of energy form for another, has been significant. There have also been significant changes in the regulations and procedures used to guide businesses', changes that include financial reporting, tax laws, regulatory agencies, authority and responsibility. Such changes suggest that a study of the underlying concepts of market structure, as well as the financial and business implications of improving technology is in order. This study would enable the economy to make better use of the more complex technology currently available. There is a necessity for the development and use of more advanced economic methodology to keep pace with technical progress. This methodology must be such progress. This methodology must be such that it evaluates costs and results in a manner that is consistent with both short- and long-run objectives of firms.
The Colorado School of Mines, having recognized the changing and increasing role of technology in the mineral industry, has successively introduced new programs since the school's inception. As part of this policy, the Department of part of this policy, the Department of Mineral Economics was established in the Fall of 1969.
The Department was charged with an expanded program of undergraduate and graduate courses in economics, management, and mineral and energy economics. A graduate program on the Master of Science level in Mineral Economics was instituted at the same time. This graduate program was designed to enable individuals with a background in the mineral field to recognize and evaluate the relevant economic factors of the extractive industry.

Introduction
In a paper on the subject of the energy crisis, recently presented before the Society of Petroleum Engineers, Mr. Lawrence O'Connor, Jr., of the Federal Power Commission, stated that everything Power Commission, stated that everything that could go wrong within the energy industries has gone wrong. The situation referred to is the apparent simultaneous shortages that all supply sources of primary energy are facing. The failure of primary energy are facing. The failure of nuclear energy to meet projected time-tables, as an example, necessitates continued reliance on hydrocarbon products to supply most of the nation's primary energy.
The continued reliance on these energy resources may pose many problems in the near future, and apparent shortages is the most serious one.
Statistical Characterization of Metal-Contaminated Fills
Authors: Patzek Tad W. , Sullivan Patrick J. 
Published: December 2007

Abstract
We present a simple and easy to implement statistical method of estimating masses of metal contaminants in a shallow industrial fill. The current metal concentrations are assumed to have resulted mostly from random mixing, crushing and placement of the fill. With this assumption, it can be shown that the metal concentrations should be lognormally distributed, i.e., the distributions of the concentration logarithms should be normal. The properties of the lognormal distribution are then used to calculate the expected masses of zinc, lead, barium, cadmium, copper, antimony and mercury in the soil. In addition, a neural network/statistical model is used to account for a possible spatial nonuniformity of metal concentrations. The neural network model predicts the total metal masses within a factor of two from the lognormal model. This means that a significant spatial nonuniformity exists in the fill, but more work is needed to validate the neural network model.

Site History
The site (Fig. 1) is located in the San Francisco Bay region and occupies an area of roughly 500 by 600 ft. Although the site is approximately a quarter mile from the Bay, in the 1870's, it was mostly a tidal flat. During this time period, only the northern corner of the site was above sea level.
Lead smelting and refining operations began in 1872 on the dry land portion of the site. From 1872 through 1905, the operations at this site manufactured lead bullion, gold, silver, white lead (lead carbonate) and quicksilver. Smelting and refining required the storage and processing of ores that contained Arsenic (As), Antimony (Sb), Copper (Cu), Gold (Au), Lead (Pb), Silver (Ag), Sulfur (S), and Zinc (Zn). The major economic mineral in the ore processed at this site would have been Galena (PbS). The smelting process, generated both solid wastes which contain the elements listed previously and acidic air emissions that typically contain sulfur, lead, arsenic and antimony.
The solid waste generated at the site during this period of operation was dumped into the adjacent tidal flat as fill. As a result, the fill is a heterogeneous mixture of waste rock (or gangue minerals) and the following smelter wastes,Speiss, a combination of arsenic or antimony and metallic iron;Matte, consisting chiefly of a combination of sulfur and iron;Slag, which is partly a chemical and partly a mechanical mixture of melted gangue and waste matters contained in the ore and fluxes; andFlue dust, consisting mostly of the finer particles of ore and fuel.
By 1907, three-quarters the site had been filled, with only the southern quarter of the site still below sea level. At this time, the site had been converted to the manufacture of sulfuric acid from the roasting of pyrite (iron sulfides). The pyrites that were roasted at this facility contained percent levels of zinc and copper and trace amounts of arsenic, cadmium, lead and silver.
P. 445^
Performance Analysis of Polymer Injection On Pilot Scale: A Case History
Authors: Sharma S.K. , Singh S.K. , Dayal H.S. 
Published: December 2007

Abstract
Polymer flooding on pilot scale in an inverted, asymmetrical five spot pattern had started in Sanand field of ONOC, India in 1985 and has completed recently. The reservoir is made of silty sand stone at a depth of 1300 m containing oil of 20 cp viscosity at 85 C (reservoir temperature). Average permeability in the pilot area is 1000 md and average sand thickness is 7 m.
Polyacrylamide polymer was used for injection on pilot scale. Polymer concentration of 400 ppm and 15 % pore volume of slug size was chosen for field injection on the basis of laboratory experiment, However, during polymer injection an average concentration of 440 ppm was injected. A total of 94,408 m3 solution containing 41,758 kg of dry polymer was injected through one well in 55 months and response was analyzed in terms of tracer and polymer break through, decline in salinity, improvement in rate etc. Being first project of its kind in the country extra care was taken in handling polymer and other chemicals in the field.
Injection response in terms of polymer breakthrough, decline in produced water salinity, improvement in oil rate and stabilisation in water cut were obtained in the monitoring well and in one of the producers. Since injection was done through one well only improvements in terms of recovery could not be quantified. The aim was to gain field handing experience of such pilots as well as to assess field recovery potential of the process. On final analysis scheme has been considered as successful in terms of injection and production performance and has led to expansion of the process in the neighbouring areas of the pilot.

Introduction
Use of aqueous polymer solutions for improving reservoir sweep efficiency by controlling mobility of injected water has become an established practice in oil field operations. The process is more effective in case of a heterogeneous reservoir containing moderately viscous crude and has been successfully implemented in Sanand field situated in western part of India. Production from the field commenced in 1969 and primary recovery predicted on the basis of simulation studies was 14 % of IOIP. Considering wide variation in petro-physical properties of the reservoir and also the low primary recovery expected from the field, polymer flooding was thought to be the appropriate EOR process.
Injection of polymerised water in Sanand field on pilot scale through one well started in 1985. Performance analysis of the pilot indicated improvement in areal and vertical sweep of the reservoir and also enabled to rectify many problems encountered during field implementation of the process. Encouraging results obtained from the pilot and experience gained during field implementation led to expansion of the scheme in neighbouring areas. P. 549^
Coreflood Study of Surfactant-Alternating-Gas Foam Processes: Implications for Field Design
Authors: Kibodeaux K. R. , Rossen W. R. 
Published: December 2007

Abstract
The success of surfactant-alternating-gas (SAG) foam processes depends on foam behavior at very low liquid fractional flow fw-i.e., on whether and how foam breaks as it dries out during gas injection. It is difficult to conduct steady-state corefloods at extremely low fw, however. Therefore simulation studies of foam SAG processes rely on extrapolating steady-state data taken at much-higher values of fw Unfortunately, grossly different results are predicted depending on how these data are extrapolated.
This Berea coreflood study of SAG foam processes uses a unique coreflood apparatus in which both water saturation Sw and capillary pressure Pc are measured throughout the flood. Steady-state data were obtained to as low a value of fw as feasible, followed by continuous gas injection. Because Sw and pressure drop were measured during this period, the fractional-flow function could be extrapolated below the range in fw of the steady-state data.
During steady-state foam injection, for fw &gt; 0.01, foam weakened and Sw fell as fw decreased. Foam was stable to a remarkably high value of capillary pressure. Between fw = 0.008 and 0.002, foam weakened sharply, and, remarkably, reimbibition occurred: Sw rose and Pc fell as fw decreased. This suggests that the fractional-flow curve for foam is not single-valued. Stated differently, there are at least two steady states, a "strong foam" and "weak foam" state, over a range of water saturations, and the behavior observed depends on injection history. This sudden foam collapse and reversion to the "weak foam" behavior under dry conditions mirrors the sudden jump to "strong foam" state reported in studies of foam generation. For lower fw, and during gas injection, Sw again declined as fw declined.
Implications of these results for field design of foam SAG processes are discussed. In particular, we illustrate how to extrapolate from a properly designed coreflood to field scale ID displacement using fractional-flow methods.
Well abandonment in the Los Angeles Basin: A Summary of Current Requirements, Practices and Problems
Authors: Evans B.L. , Sailor R.P. , Santiago E. 
Published: December 2007

Well abandonment in the Los Angeles Basin: A Summary of Current Requirements, Practices and Problems.

Abstract
Due to declining oil production increasing and real estate development, an increasing number of oil wells are being abandoned (or reabandoned) each year in the Los Angeles Basin. This paper summarizes the current requirements of the Department of Conservation's Division of Oil, Gas and Geothermal Resources (Division), the current abandonment practices of the industry and some of the difficulties encountered in properly abandoning or reabandoning wells. The paper has viewpoints from authors representing (1) the Division, (2) a major oil company with a large abandonment program, and (3) a consulting petroleum engineer engaged in reviewing wells and preparing abandonment programs.
This paper is considered to be particularly timely and important as the petroleum industry endeavors to leave oil fields in such a condition that surface development can safely follow.

Introduction
The Los Angeles Basin is one of the most prolific oil producing basins in the world. It contains over 60 oil fields where cumulative oil production exceeds 8 billion barrels.
Some of the major onshore fields and oil production are as follows:
Oil production in 1995 in the Los Angeles Basin totaled 38.6 million barrels (106,000 B/D) from 4,900 producing wells. At the end of 1995 there were 3,081 idle wells. Most of these wells are abandonment candidates. During 1995, 498 wells were abandoned in the Los Angeles Basin (Table 1). Since 1988, the rate of well abandonments has increased significantly (Fig. 1). This paper discusses the current regulatory requirements, practices and problem related to abandoning wells in the Los Angeles Basin.

A. Current Requirements
Since 1915, the Division has been charged with regulating the drilling, operation, maintenance and abandonment of all oil and gas wells in California, to prevent damage to life, health, property, and natural resources. Under Section 3106 of the Public Resources Code (PRC) the State Oil and Gas Supervisor has the authority to regulate the manner in which the Division's programs are carried out in the best interest of public safety and ultimate recovery of oil and gas.
In the early 1970's, additional safety concerns were raised by the Division regarding building in and near former oil producing areas. Although the oil and gas wells in these areas may have been abandoned properly in previous years, they may not be in conformance with today's more stringent abandonment regulations. The prevention or mitigation of methane gas migration from other sources into proposed or existing overlying structures also became an important matter for the Division; including, developers and building and fire inspectors.
P. 701^
Stimulation for Methane Gas Recovery from Coal
Authors: Jeffrey R. G. , Wold M. B. , Choi S. K. , Settari A. 
Published: December 2007

Abstract
Over the past several years, a combination of data from field and laboratory experiments, published data from commercial treatments, and concurrent analysis and model development activities has led to a better understanding of the processes occurring in coal during stimulation operations. At the same time, better modeling capabilities have been developed. For example, a new hydraulic fracture design model that includes pressure-dependent non-linear leakoff, multiple interacting fractures, and failure in the coal near the fracture plane as a result of changes in effective stress, is being developed and is being used to study fracture propagation in coal. In addition, two- and three-dimensional discrete element and hybrid finite element models that couple the mechanical and multi-phase fluid response of the coal have been applied to analysing problems arising in cavity completion operations.
The paper compares data obtained from field trials in coal seams with model simulations and discusses implications for stimulation design and execution.
Field Evaluation of Wells Fractured in The North La Barge Field Using Continuous-Mix Gelled Oil
Authors: Maberry L. J. , Tanner K. V. , McConnell S. B. , Hinkel J. J. 
Published: December 2007

Abstract
The chemistry and field application of a continuous-mix gelled oil fluid are described. A brief history of oil gelation and phosphate ester chemistry is presented, followed by a discussion of new complexation chemistry. Field case studies are presented on 90 wells fractured in the Wyoming North La Barge field, from Aug. 1994 to Oct. 1996. Gelled oil fracturing treatments performed using prior art chemistry are compared to those performed using an enhanced complexation chemistry.
Integrated Reservoir Description From Seismic, Well Log, to Production Data
Authors: Yang An-Ping 
Published: December 2007

Abstract
The increasing need to improve production from developed oil and gas fields requires more detailed and more accurate reservoir description. Our answer is a multidisciplinary approach integrating geophysics, geology, geostatistics, and engineering. For a field with seismic data, well logs, and production data, an integrated reservoir model can be more accurate than the conventional approach of passing the model from geophysicists to geologists then to engineers.
In the development stage of a field, a geological model would have been built. The model would have been tested against production data. Now If we are going to build a more detailed model, the existing reservoir model is a valuable input. When dealing with seismic data, time permitting, known information of structure and stratigraphy may be used. When converting time data to depth, well data may be used together with seismic information to build a 3D velocity model. Geostatistics may be used with velocity logs and seismic data to build a more accurate and detailed velocity model. Without a reasonable velocity model for time depth conversion, it is difficult to integrate well data and seismic data. A lithology model or porosity model may be built with well data, structure information, and seismic attribute as soft data. Seismic attributes are calibrated to well data. Geostatistics provides a way to properly weight between well data and seismic data. The reservoir model may be compared or calibrated with production data. Then we may go back and modify the velocity model or horizon picks, or we may modify the conversion from seismic attribute to soft data used in the geostatistical gridding. By iteration, our reservoir model will become more accurate because it honors geophysical, geological, and engineering data. Common data links and tools like geostatistics make the integration easier.
Field applications show that an integrated iterative approach to detailed reservoir modeling can provide a better model and help optimize production.
The Benefits of Integrating Different Information Disciplines
Authors: Bigelow E.L. 
Published: December 2007

Abstract
The technical and economic benefits of integrating different information sources is well founded. It is important that drilling, well completion, and production personnel be included in such task forces if optimal information gathering is to be accomplished. The pulling together of people and data from several information disciplines, and utilizing individual strengths, while learning to accept specific weaknesses as such, leads to a cooperative team effort in resolving difficult reservoir characterizations.

Introduction
As our proven oil and gas resources diminish. and new sources become more difficult to find and produce, technology in virtually every inflation discipline has demonstrated dramatic advances. Despite the technical improvements, there are many cases where individual disciplines continue to achieve only marginal success. Too much impetus is directed toward self-promotion of a particular information discipline, and too often competitive disciplines are criticized for their particular weaknesses.
Combining the attributes and strengths of different disciplines, and recognizing where each have inherent weaknesses leads to much more accurate analysis of subsurface real estate. When petroleum reservoirs are found with fewer exploration wells. and when accurate analysis of all the available information is utilized to appraise and describe newly discovered reservoirs, oil company economics is drastically improved. Case histories show:
- the positive aspects of using both seismic and borehole data to establish the size and location of a potential reservoir.
- the use of well logs, seismic, and borehole seismic methods to define the size. shape. and internal characteristics of a newly discovered reservoir, and
- the capability of planning and implementing the most economical and technical extraction of discovered reserves. Total integration of both surface and borehole data and personnel is cost-effective and leads to more effective reservoir evaluation. Effectiveness of information gathering is enhanced when drilling, well completion, and production personnel are made aware of the difficulties some procedures cause for the different information-gathering disciplines. Reconciling procedures before a problem arises is beneficial for all.
Coiled Tubing Applications in the Sultanate of Oman
Authors: Al-Harthy Salim Said , Kalam Mohammed Zubair 
Published: December 2007

Abstract
The use of coiled tubing (CT) drilling technology is rapidly expanding and its important to note that the technology is still in the process of testing its boundaries and limitations. However, this is a necessary phase in the learning curve. Probably the most logical approach is to consider the market or application niches best suited to coiled tubing drilling technology.
Six horizontal sidetrack wells were drilled in North Oman using CT. The objective of these trials was to evaluate the technical and economical feasibility of this drilling technique. For all the six wells, the existing completion was removed from just above the upper packer and the remaining completion abandoned, then a window was milled in the 7 inch casing, allowing the well to be sidetracked using a whipstock, and built up through the formation of interest.
This paper discusses the three main problems faced during drilling these wells, and the suggestions for improvement. The problems discussed involves the following: difficulties in setting the whipstock, problems in cleaning the hole, and difficulties in handling the tubing. Whipstock types are discussed, and the one best suited for this type of application is recommended. A proposed schematic of a rig is shown to minimize the problem of handling the tubing for this type of application.