bluuebunny/crossref_metadata_2025_split huggingface dataset:
H2S Need Not Be Deadly, Dangerous, Destructive
Authors: Samuels Alvin 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
IRONITE SPONGE is a significant new product specifically formulated to scavenge hydrogen sulfide from drilling, completion and workover fluids. The material is believed to be unique both in terms of its composition and its reaction with H2S. Because of this it can result in a level of safety not now possible using any other method of possible using any other method of treatment. When added to the drilling, completion or workover fluid in recommended concentrations it is capable of eliminating the danger to personnel, equipment and the environment even when a high pressure, low volume feed-in containing high H2S concentrations is encountered and this even if high strength drill pipe is in use!
This is possible because IRONITE SPONGE reacts on contact with H2S to form mainly FeS2, pyrite, which is safe and stable. The reaction appears to instantaneous, complete and irreversible and the efficiency is directly proportional to bottom hole pressure. proportional to bottom hole pressure

Introduction
Hydrogen sulfide, commonly referred to as rotten egg gas, is deadly poisonous. Concentrations above 600 poisonous. Concentrations above 600 ppm can be fatal in 3–5 minutes, Table ppm can be fatal in 3–5 minutes, Table 1. Its toxicity is comparable to cyanide. It is the most destructive gas known! Fifty ppm will cause highly stressed, high strength steel to fail in only minutes and small concentrations can reduce drill pipe life by a factor of ten. Even 0.1 ppm will greatly reduce the time to failure of highly stressed, high strength drill pipe. In addition to being the only pipe. In addition to being the only gas which causes embrittlement, H2S also contributes to corrosion fatigue of any grade of drill pipe.
Heretofore there has never been a satisfactory method of scavenging H2S except in small quantities and involving less than desirable situations. The use of zinc and copper compounds results in time, temperature and pH sensitive reactions. Slow reactions, the need for high pH, plating tendencies and corrosive and unstable by-products are but a few of the problems wholly eliminated by the use problems wholly eliminated by the use of this new material. Most important, however, is the ability to protect people, pipe and the environment even people, pipe and the environment even with the well on choke due to a kick containing high concentrations of hydrogen sulfide.
Recovery Of A Fuel From Waste Solvents Generated In The Chemical Laboratory
Authors: Cerceo Eugene 
Published: December 2007

Introduction
For years clinical laboratories have been conducting routine quantitative analyses on hormones (steroid and peptide), vitamins, drugs, enzymes, and a variety of other relatively small molecules in physiological fluids. Many of these test methods require the use of organic solvents as a means of separating the component to be analyzed from interferring substances. The separating techniques are either extraction of the component into an organic phase or chromatography (thin layer or column) of the substance from its interferrants utilizing organic solvents.
In a relatively large number of tests the solvents used are petroleum-related; such as, petane, hexane, isooctane, benzene, petroleum-related; such as, petane, hexane, isooctane, benzene, toluene, and xylene. For reasons of safety, many laboratories take the extractant to dryness in a distillation apparatus recovering the solvent in a separate vessel. Thus, under no circumstances can explosive combinations of air and vapors build up in the fume hood. From thin layer and column chromatography excess solvents are recovered from trays and columns. Therefore, as the laboratory conducts these routine analyses on a daily or weekly basis, waste solvents tend to accumulate and the problem becomes one of disposal of these fluids. Since these organic compounds are an intrinsic part of gasoline, it was summarized that quite possibly these solvents could be recovered and blended into a fuel very similar, if not identical to it. Thus, a recovery program was initiated in our laboratories from those clinical test program was initiated in our laboratories from those clinical test methods utilizing petroleum-type solvents. The wastes were placed in five-gallon metal containers and stored in cabinets specifically designed for the storage of flammable organic fluids.
Feasibility Study of the Stability of Openhole Multilaterals, Cook Inlet, Alaska
Authors: Moos D. , Zoback M. D. , Bailey L. 
Published: December 2007

AbstractA study of in situ stress, rock strength and wellbore stability was initiated within the Hemlock Sands of the McArthur River Field, Cook Inlet, Alaska, to evaluate the potential of leaving the near-wellbore portions of multi-laterals uncased. A NW-SE direction of maximum compression and a strike-slip faulting regime were predicted from analysis of leakoff test data and observations of failure (breakouts) in adjacent wells. Caliper, well-log, and core data indicated that cementation, and hence rock strength, is highly variable within the reservoir. Thus, it was decided to evaluate the stability of the lateral sections (that is, the likelihood of wellbore failure during production) as a function of both stratigraphic position and well orientation. Laboratory rock strength measurements were carried out on cores selected from target intervals in adjacent wells to provide sufficient precision to quantify the results. The results indicated that, while some reservoir intervals have high enough strengths to be left uncased when drilled in the most stable direction, these intervals are too thin to provide sufficient support at the point where the laterals leave the parent well. This justified the decision to case back the laterals to the parent well in spite of the cost.
A Numerical Description of Hot-Water and Steam Drives By The Finite-Difference Method
Authors: Vinsome P.K.W. 
Published: December 2007

Abstract
A stabilised-'IMPES' method has been developed for the hot-water and steam-injection processes. While the method is much simpler processes. While the method is much simpler than implicit methods, it maintains second-order accuracy on the space derivatives, and large time steps may be realised. The techniques can easily be incorporated into existing simulators to increase their efficiency, and have a wide range of applications e.g. coning, and miscible drives. Simulations have already been performed both on laboratory and field scales. Examples of steam drive in tar sands and steam soak are presented. The finite-difference equations presented. The finite-difference equations contain some peculiarities when applied to steam drives, which are illustrated and discussed by means of numerical examples.

Introduction
Numerically, steam drive is a tough problem. Consider what happens in a typical 'IMPES' (implicit potential, explicit saturation) finite-difference potential, explicit saturation) finite-difference simulator. Under normal conditions about half a pore volume of any fluid may be pushed through a pore volume of any fluid may be pushed through a grid block per time step before the calculation goes unstable. If this is the flow rate of steam just behind the condensation front, then because of the large density difference between steam and water, the water flow rate just after the front will be of the order of 1/100 of a pore volume per time step. One difficulty is obvious: that of stability. In order to keep the conventional IMPES scheme stable, it is necessary to have thousands of time steps for a simulation. Pioneering attempts to simulate the steam-injection process utilised an explicit calculation of either the mass balance or the energy balance, and as a consequence suffered from this severe stability limitation.
Traditionally, the method used to remove the high flow-rate stability limitation has been to calculate the volume, mass, and energy balances implicitly, either sequentially or simultaneously. This approach has been particularly successful on coning problems but it does particularly successful on coning problems but it does have certain drawbacks. The programming effort involved is much greater. The programs become larger and more unmanageable. Only single-point upstream mobilities are used, which leads to significant loss of accuracy in the space derivatives. Overshoot problems occur, especially near residual saturations, and these must be checked out and corrective measures taken. Other non-linearities such as potential reversal can cause trouble, even bomb-out, especially when the flow rates are high.
A third major problem with steam-drive calculations is the treatment of the condensation term. It can vary rapidly at a grid point during a simulation, which means any explicit evaluation of this term causes computational difficulties. Coats has presented a novel formulation of the condensation term which attempts to eliminate such troubles.
The Current Status of Commercial Deployment of the Freeze Thaw Evaporation Treatment of Produced Water
Authors: Boysen J. E. , Harju J. A. , Shaw B. , Fosdick M. , Grisanti A. , Sorensen J. A. 
Published: December 2007

Abstract
Evaporation is an economical way to dispose of oil and gas produced water in warm, arid climates. During colder seasons, it is not as effective. The freeze-thaw-evaporation (FTE®) process couples freezing with evaporation. By combining these natural processes, produced water can be treated economically on a year-round basis.
Glycol Used for Natural Gas Dehydration: Evaluation of Subsurface Transport and Fate Issues
Authors: Sorensen J. A. , Hawthorne S. B. , Gallagher J. R. , Harju J. A. 
Published: December 2007

Abstract
Triethylene glycol (TEG), diethylene glycol (DEG), and ethylene glycol (EG) are commonly used to dehydrate the natural gas stream. These compounds may be introduced into the sub-surface environment as a result of spills, leaks, mechanical failures, and past disposal practices. The toxicity of the dehydration glycols at concentrations typically found in the subsurface in the vicinity of a dehydration unit is generally considered to be low. However, the miscibility of the glycols suggests that they may act as cosolvents for other more toxic, less soluble, organic compounds such as polycyclic aromatic hydrocarbons (PAHs), thereby increasing the subsurface mobility of those compounds. In 1998, a series of laboratory-based research activities was initiated to determine 1) the nature of cocontaminants that may be associated with the gas dehydration process, particularly spent glycols, 2) the biodegradability of the dehyradation glycols under environmentally relevant conditions in soils from three different gas-producing regions of North America, and 3) the potential effect of the dehydration glycols on the subsurface mobility of PAHs in the same three North American soils.
Training Techniques in Well Control
Authors: Kendall H.A. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Blowouts must be prevented if the drilling industry is to survive. While most governments are anxious to produce oil and gas, this may be produce oil and gas, this may be secondary to avoidance of environmental pollution. A sequence of such pollution. A sequence of such incidents can shut down drilling efforts, perhaps temporarily, or perhaps permanently. Most incidents perhaps permanently. Most incidents occur due to a failure to understand the basic principles involved in well control.
Not only must drilling personnel be thoroughly trained in the basics of well control, but all personnel involved in any position who can influence drilling operations must also understand the consequences of any order or command given. Training should also be given to personnel not directly involved in drilling operations but who are normally in the vicinity of the drilling rig.
In addition to the many articles written and published on this subject, there are several excellent well control simulators available worldwide, where firsthand experience can be obtained in well control without the hazards of learning in the real world. This paper illustrates what Amoco has done to promote as well as carry out well control training seminars to all personnel associated with our European personnel associated with our European drilling operations.
Installation of Fixed Steel Piles Platforms in Deep Water
Authors: Heerema P.S. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the SPE-European Spring Meeting 1975 of the Society of Petroleum Engineers of AIME, held in London, England, April 14–15, 1975. 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.
A fixed platform consists normally of:A substructure: a space frame of pipes welded together, called jacket or template.A pile foundation, to nail the substructure to the sea bottom.A deck construction over the substructure.Prefabricated units containing production and/or drilling equipment.
With deep water is meant, depths of over 150 feet. Presently structures are being designed and fabricated for water depths up to some 500 feet.In water depths up to some 300 feet, the jackets weigh normally less than 6000 tons and may be transported and launched at location from specially designed launch barges. The load-out of such structures is usually done by sliding them from the fabrication site on a barge over a rail system with surfaces of steel or wood or teflon, overgrease.In greater water depths, the jackets usually weigh more than 6000 tons and up to 20,000 tons. Although launching of such huge structures is possible, they are usually built so that they will float, and are towed to location, and upended by a system of selected flooding of the legs.The piles for deep water structures vary from an O.D. of 36" to a maximum of 72",with wall thicknesses varying from 7/8"to 2 1/4".Penetrations vary from 100 feet to 350 feet depending on soil conditions and required bearings. Ultimate design loads on piles vary from 1500 tons to 5000 tons. If the piles cannot be driven to the penetration required to obtain the necessary design bearing, drilling out of the plug, or other means, like the patented Heerema "slip joints", to obtain more penetration, may be used. As a last ressort insert piles, pin piles or underreaming may be used.
The first length is then driven to a practical penetration, usually with the use of a drilled pilot hole. Then a smaller diameter hole is drilled inside the first pile and well below of the tip of the pile, with mud circulation, to maintain the hole and grouted with a cement mix to obtain adherence to the walls of the hole.
Laboratory Test Performance Methods For Additional Products Used In Petroleum Production Processes
Authors: Couget Paul 
Published: December 2007

Couget, Paul, ELF, R.E., Department Recherche Technique et Etudes Nouvelle, BOUSSENS, FRANCE
Oil field development is characterized by the fact that many problems arise which could not be foreseen at the beginning of operations (or were underestimated when they were not purely or simply unknown)
Among the problems most often encountered are those of:–corrosion due to dissolved carbon dioxyde and/or hydrogen sulfide–corrosion due to dissolved oxygen–sulfate reducing bacteria corrosion–emulsions–paraffin dirt-minerals salts deposits–foams.
When these problems have not been foreseen at the beginning, they often require the injection of appropriate products.
The choice of these depends of course on their SPECIFIC EFFICIENCY for the purpose. But it also depends on the INTERACTION that these products may have either with each other when used simultaneously, or with the environment in which they are used or due to their SECONDARY EFFECT or the CONDITIONS in which they are used.
So a product, for example a bactericide, may have the best characteristics of its kind without however being the most suitable product for use in a given working site, because of its incompatibility product for use in a given working site, because of its incompatibility with the other additives or with the environment.
The laboratory specialist who must make a choice from among a large range of products, will have to consider all the conditions of utilization for selecting the most suitable product.
Recent Developments in Numerical Simulation Techniques of Thermal Recovery Processes
Authors: Tamim M. , Abou-Kassem J. H. , Ali S.M. Farouq 
Published: December 2007

Abstract
Numerical simulation of thermal processes (steamflooding, cyclic steam stimulation, SAGD, in-situ combustion, electrical heating, etc.) is an integral part of a thermal project design. The general tendency in the last ten years has been to use commercial simulators. During the last decade, only a few new models have been reported in the literature. More work has been done to modify and refine solutions to existing problems to improve the efficiency of simulators. The paper discusses some of the recent developments in simulation techniques of thermal processes such as grid refinement, grid-orientation, effects of temperature on relative permeability, mathematical models, and solution methods.
The various aspects of simulation discussed here will promote better understanding of the problems encountered in the simulation of thermal processes and will be of value to both simulator users and developers.
Long-Stroke Pumping System at Shell Canada's Peace River Multilateral Thermal Wells
Authors: Zatka Mirko J. 
Published: December 2007

Abstract
Shell Canada Limited produces 6-9° API bitumen from a number of multilateral horizontal ("SoakRadial") cyclic steam wells as part of its thermal recovery project at Peace River in Alberta, Canada. These wells typically utilize a conventional beam lift pumping system with a variable frequency drive for speed control. In seeking ways to optimize the artificial lift system, Shell Canada initiated, in 1998, a controlled test of a mechanical long-stroke pumping unit as a possible alternative to conventional pump jacks. The objective of the test was to evaluate the unit for operating reliability, its ability to lift available production, lifting cost (power consumption) and frequency of maintenance. In addition, the test included a pump-off controller system on one long-stroke and one conventional pumpjack, enabling close monitoring of well conditions and differences in operating parameters.
Variations in productivity due to the cyclic nature of the steam soak operation of these wells present unique challenges to conventional pumping systems. Ability to closely match pumping rates to well inflow is expected to result in lower operating and maintenance costs, a feature that long-stroke units were expected to offer. Field tests have in fact shown that these units can increase daily production rates through better pump efficiencies and longer stroke lengths, while reducing the amount of power consumed and thus operating cost. Other benefits include reduced wear in downhole pump components and comparable equipment reliability to conventional pumpjacks. While some issues arose around servicing of wells equipped with the long-stroke units, changes to wellhead and surface facility design on future wells is expected to overcome most of these.
Storage Of Natural Gas In Salt Caverns
Authors: Medley Alfred H. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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.

Introduction
Natural gas can be stored in many ways but when geologically feasible, salt cavern construction is usually the method of choice. Salt caverns permit the highest rate of gas delivery, provide a secure for of storage, permit full product recovery, and usually require the least cost for construction. This paper presents a review of cavern paper presents a review of cavern design parameters.

GENERAL CONCEPT
Three ingredients are necessary to develop a solution mined storage caverns: a thick salt formation, a supply of fresh (or low salinity) water, and a means of brine disposal. The fundamental principle of development is to simply expose the salt in a drilled hole, inject fresh water into the hole, allow time for dissolution, and withdraw the resulting brine from the hole, As the salt dissolves, the hole enlarges into the form of a cavern.
In actual practice, the procedure for cavern development is somewhat more complex. In the case of a thick salt mass, a single leaching well is usually sufficient as shown in Figure 1. Thinner salt may require two fracture connected wells as shown in Figure 2. In either case, each well should have a fully cemented string of casing extending from surface into the salt. Leaching is conducted by injecting the light fresh water down a tubing string with sufficient pressure to force the heavier brine up the other tubing string. Concentric tubing strings must be used in the single well configuration but separate strings can be run when dual wells are available. In either case, the annular region enclosed by the cemented casing must be filled with a light nonleaching and noncorrosive fluid such as oil or propane.