bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multipurpose Service Vessels: Conception, Design, and Well Intervention Operations
Authors: Galbrun Michel 
Published: December 2007

Abstract
Throughout the life of an offshore well, the operator can choose from a wide range of well intervention services to maintain adequate productivity. These services may be performed as planned preventive work, targeted campaigns or emergency well intervention requirements. In all cases, the repair or intervention work must be performed as efficiently as possible, so that production is recovered with minimum delay and intervention cost.
Until recently, such intervention work was carried out from existing vessels, such as drilling vessels, semisubmersibles, jackups, lift-boats, construction vessels or supply vessels. These units, diverted from their primary functions, are often less efficient and more costly than a fit-for-purpose unit. In addition, as the intervention service equipment is assembled temporarily on board these vessels, overall efficiency is reduced because of the nonproductive time needed to rig up, rig down and to interconnect the equipment, and to organize the resources needed to operate it.
This paper discusses the development of a new approach to well intervention that is achieved with a Multipurpose Service Vessel (MPSV). By analyzing most common intervention needs, reviewing safety issues, and evaluating operational factors and costs, the MPSV concept has been developed to provide operators with a cost-effective tool. The MPSV has specially adapted multifunction service equipment built in to ensure flexibility, reduce overall nonproductive time and optimize deployment of the services through improved logistics and reduced running costs.
The North Sea Supply Boat
Authors: Pruymboom A.A.W. , Strachan A.G. 
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.

Abstract
This paper presents the development of the North Sea supply vessel as from the past, present and future. It gives a brief present and future. It gives a brief statement concerning an anchor handling procedure in the North Sea of a semi-submersible and a large North Sea type tug/anchorhandling/ supply vessel. Special attention is required for a better cooperation between the drilling companies and the supply boat company, in particular during the designing stage.

Introduction
The history of the North Sea supply boat cannot be described as being a very long one but at the same time it has seen the introduction of many unique innovations in marine technology.
The actual number of supply ships operating in the North Sea area today cannot be accurately assessed as ships are constantly being moved into the area from overseas and assigned to other operational areas. The arrival of new buildings on the scene can also confuse the figures as can the seasonal demands of the construction contractors. However I would estimate that approximately 250 supply boats of varying capability will find employment in the North Sea area during the Summer of 1975. Most offshore support craft activities are nowadays concentrated on the United Kingdom Continental Shelf where the majority of oil and gas discoveries have been made. My own Company has always favoured international involvement and in the 10 years of the Company's history, we have serviced drilling operations offshore Denmark, The Irish Republic, Holland, Norway, Sweden and the United Kingdom.
I propose to divide this paper into 3 sections, the past, the present and the future.

1. THE PAST
The first purpose-built supply boat for North Sea duty reared its head during the Spring of 1965.
A Novel Integrated Approach to Enhance Interpretation of PNC Log Data for Characterization of Layered Reservoirs
Authors: Ali Liaqat , Sultan Ahmad J. , Metwalli Magdi H. , Paulson Rodney D. 
Published: December 2007

Abstract
One of the fundamental limitations of Pulsed Neutron Capture (PNC) log interpretation is that the capture cross-section of water (Σw) is unknown in a reservoir where salinity of formation water differs from injected water. Currently, no method is available to adjust the capture sigma cross-section, which may correspond to the salinity of water mixture that is present in the vicinity of the logged well. This paper presents a novel integrated approach to enhance the interpretation results of PNC logs using produced water analysis data to calculate new Σw. The methodology developed assists in characterizing stratified carbonate reservoirs.
Results of this study show that water breakthrough layers observed in PNC log interpretations correlate with the specific gravity trends obtained from produced water analysis of nearby wells. The specific gravity trends show that the injected water is advancing in different layers indicating that little or no cross-flow exist among layers. We estimated salinity of water mixture at the time when the logs were run from the specific gravity trends and devised a new algorithm for PNC log interpretations.
Observations from this study suggest that if the salinity of the produced water at the particular time when the PNC log was run is used, the interpretation of PNC log data would be relatively more realistic. With field examples, we demonstrate in this paper that the new approach is more representative than the existing PNC interpretation techniques.
Recovery of Acidic Crude Oils With PEI
Authors: Friedman R.H. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 45th Annual California Regional Meeting of the Society of Petroleum Engineers of AIME, held in Ventura, Calif., April 2–4, 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 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.
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
Polyethylenimine (PEI) in dilute aqueous solution has been found to be an unusually effective recovery agent for acidic crude oils. It is more effective than the mineral bases against both high and low viscosity oils. No equivalent substitute was found nor was any agent found which acted synergistically with PEI. Application has been made for U.S. patent. patent

Introduction
Research on the use of bases to recover acidic crude oils has been conducted for many years. The first patent on the subject was in 1927. patent on the subject was in 1927. All the work cited in the literature deals with the use of mineral bases, sodium, potassium, or ammonium hydroxides, and with the exception of Jennings, et al, with crudes of relatively low viscosity. In the work reported here, viscosities are an order of magnitude higher than reported before and reservoir temperatures are 80 degrees F. At these higher viscosities, sodium hydroxide is ineffective. Dilute polyethylenimine (PEI) solutions with these more viscous acidic crudes reduce saturation to lower levels than previously achieved with sodium previously achieved with sodium hydroxide on low viscosity oils.
Though the precise mechanism by which bases aid recovery is moot, it seems evident that a surface active compound, a reaction product of the base and acid native to the oil, is responsible. When an alkali metal hydroxide is used to displace a very viscous acidic crude, the most frequent effect of this "soap" is the creation of a low viscosity oil-water emulsion, which immediately fingers through the oil ahead. As a result, little more oil is recovered with such a base than with water alone. This consideration led to a search for a satisfactory polybasic polymer. polymer. High viscosity was not the objective.
Recompletion of Wells to Improve Water-Oil Ratio
Authors: Rensvold Roger F. , Ayers Hugh J. , Carlisle W.C. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 45th Annual California Regional Meeting of the Society of Petroleum Engineers of AIME, held in Ventura, Calif., April 2–4, 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 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.
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
A treatment technique has been developed to improve the oil/water ratio in producing wells. An inexpensive, inorganic, low-viscosity fluid is injected into the water producing interval. This fluid sets to a stiff gel after a predetermined pump time. By placing a sufficient volume of fluid in the formation, a long lasting barrier to water production is achieved. The placement technique uses low pump rates and injection pressures, and includes a low-volume, low-pressure cement slurry tail-in.
Variations in placement technique have been developed to adapt the process to a variety of downhole problems. These include:Plug back for bottom water.Balanced pumping above and below a packer for treating the water producing interval packer for treating the water producing interval and simultaneously protecting the oil producing zone.Where a Tracker cannot be used, balanced pumping with a radioactive interface technique pumping with a radioactive interface technique for treating the water zone and, at the same time, protecting the oil zone.
Case histories are cited which show that the process can be successfully used in limestone, dolomite and sandstone formations. In many instances, an increase in oil production occurs when the production of water is eliminated or reduced.
In conclusion, various placement procedures allow the treatment technique to be used in almost any producing well. Furthermore, the establishment of an in-depth barrier in the formation against the migration of water is, in most cases, superior to conventional cement squeeze techniques.

Introduction
The production of water usually increases during the life of a well and can present many problems to the well owner. Some of these problems to the well owner. Some of these problems are: problems are:Increased lifting costs.Decreased oil production due to increased fluid level, downhole scale accumulations, and emulsions.Shortened life of surface and subsurface equipment due to corrosion and scale accumulation.
Development And Testing Of Jet Pump Pellet Impact Drill Bits
Authors: Eckel J.E. , Deily F.H. , Ledgerwood L.W. 
Published: December 2007

Abstract
A new method for drilling the earth's formations has undergone extensive laboratory and shallow earth drilling experimentation. This method, pellet impact drilling, uses the energy of a large mass of high-velocity steel spheres to break and crush the rock. Pellets are confined to a region close to the hole bottom. Motive fluid for transporting and recycling the pellets is supplied by a modified jet pump.
The pellet drilling method has inherent advantages over conventional rotary drilling. Firs only a nominal amount of weight need be applied to the hole bottom. Second, only a very small amount of torque is required for bit rotation. Third, means are available for continual replacement of the cutter medium.
The experimental laboratory work and analytical procedures necessary for the design of a pellet drill bit are described. In the laboratory program approximately half the effort was devoted to the development of a better understanding of the physical process, and half to the empirical testing of new bit configurations. Factors such as pellet size and velocity, jet pump characteristics and modifications, and power distribution are discussed.
The design and construction of a pellet impact bit for drilling a 9-in hole with 1 1/4-in steel pellets are described. Drilling performance in representative rocks, hydraulic operating characteristics, and metallurgical problems are discussed.
This paper discusses an attempt to reduce drilling costs through the development of a drilling method basically different from rotary drilling.
Publications on drilling research indicate that the major effort on the part or manufacturers and operators has been confined to research in rotary, or rotary-percussion drilling. This applied drilling research has produced significant gains in drilling rates and bit life, but thus far it has failed to achieve any major decrease in general drilling costs.
A Team Approach to Heat Management: Monarch 2F Steamflood, Midway-Sunset Field
Authors: Morrison Cheryl , Griston Suzanne , Smedley Gary 
Published: December 2007

Abstract
Chevron's Monarch 2F steamflood project currently consists of approximately 35 injectors and 90 producers. Heavy oil (14° API gravity) is produced from multiple sand beds averaging 55° dip. In late 1992 and early 1993, the original Webster E and D sand steamflood ceased. Subsequent vertical expansion steamfloods were installed in the Webster A through C sands, using slim hole injectors and commingled producers. Additionally, an areal expansion steamflood was installed in the Monarch and 10-10 sands.
In late 1997, a multidisciplinary team was formed to develop and implement a comprehensive heat management review of the steamflood expansion projects. The main objective was to optimize steam use and maximize oil production. The team's approach was to incorporate all available project data to assess heat and fluid migration in each target sand. Additional monitoring data were gathered to "fill-in-the-gaps" as needed.
This extensive data gathering and review process and revised operating strategy was implemented in stages over several months. The final outcome was a 40% reduction in steam use and a 25% increase in oil production. Fuel savings for 1998 exceeded $500,000 and steam related operating costs decreased by nearly $1/boeg. In addition, the team developed an infill drilling program to further realign steam injection and recover oil that would otherwise have been bypassed. Part of this realignment project was implemented in 1998, while the remainder of the work is scheduled for early 1999. The 2F property currently has an oil production rate of around 5,000 bopd and a steam-oil ratio of 1.2.
An Approach to the Problem of Slow Convergence for Automatic History Matching Procedures
Authors: Bishop Kenneth A. , Knapp Roy M. 
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.

Abstract
The process of matching the performance history of a reservoir in performance history of a reservoir in order to determine parameter values for use in it numerical simulation may be described as an iterative effort to bring pressures and flows calculated by the simulator into close concert with those observed in the field. Development of automatic techniques which use concepts from optimization theory as strategy for parameter manipulation has been emphasized in recent years. Many of the studies which have appeared in the literature may be characterized by a preoccupation with algorithm development and relatively little concern for the nature of the performance measure chosen for performance measure chosen for optimization.
This paper focuses attention on the nature of a common performance measuring function. Certain characteristics of this function are analyzed in terms of their effect on the quality of a history match and on the performance of a common optimization algorithm. This analysis provides a basis for redefinition of provides a basis for redefinition of the independent variables of the function which modifies these characteristics an thereby improves algorithm performance.
The uncomplicated history match problem of determining porosity and problem of determining porosity and permeability values for the model of a permeability values for the model of a homogeneous reservoir which contains a single phase, slightly compressible fluid is used as a vehicle in the study.

Introduction
The development of reservoir engineering technology has been characterized by a steady increase in the sophistication of the mathematical and engineering techniques used.
Anomalous Potentials in Variable-Density Aquifers Affect Growth of Gas Storage Bubbles
Authors: Bond D.C. 
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.

Abstract
" Corrugated" flow in heterogeneous variable-density aquifers causes anomalous gradients in head or in potential. These gradients retard the establishment of equilibrium under and around a gas storage bubble after withdrawal of storage gas. The head under the storage bubble can be less than the head at the same elevation outside the bubble. Thus, gas can be forced into layers deeper than the injection strata.

Introduction
In a variable-density aquifer certain gravitational effects influence flow (Bond, 1973). The purpose of the present paper is to show:how these gravitational effects can be used to explain anomalies in indicated flow directions in reservoirs;how these gravitational effects reduce the response in pumping tests; andhow these effects pumping tests; andhow these effects influence the growth of a gas-storage bubble.
I have shown that in a variable-density aquifer, structure on the top and the bottom of the aquifer can influence the potential or the head in the aquifer. Also, relatively impermeable tilted barriers within the aquifer-barriers that divert flow from horizontal paths-can cause a difference in head. In an aquifer that contains such barriers, flow is diverted down and then up, over and over again, to give an undulatory, "corrugated" flow. That is, if water flows, it flows through a series of irregular U-shaped troughs (Bond, 1973).
In a region where a dense water is being displaced by a lighter water, the dense water in the U-shaped troughs is not necessarily displaced completely. The net result is a series of troughs, or U-tubes, containing light water on the inlet side and dense water on the outlet side of each of the U-tubes. Each U-tube produces a head difference, H 1.00 (in terms of fresh water), equal to (pD-pL) Delta Z, where pD and pL are the relative densities of the dense and light water, respectively, and Delta Z is the depth of the U-tube. In a series of U-tubes, the head differences are additive. Thus, anything within the aquifer that causes flow to deviate from the horizontal can introduce gravitational effects that result in differences in head.
One may argue that, even though barriers to horizontal flow are present, tortuous horizontal paths that permit some flow around these barriers can be found.
Potential Energy Sources
Authors: Jenny Wilbur M. 
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
The energy outlook for the United States for the next 10 years can be most grim when compared with the 50's and 60's. Prices and easy supply situation of these bygone years are only memories. We now face the realities of world interdependence for oil and gas supplies.
FEA Project Independence supply projections depend heavily upon selection of a range of policy options. All scenarios call for more policy options. All scenarios call for more coal and nuclear development. Vigorous energy conservation programs become a national imperative. Achieving the production levels that provide an acceptable degree of security will require massive infusions of capital, manpower and technology.
The broad strategic options outlined in Project Independence are: (1) increasing Project Independence are:increasing domestic supply,conserving and managing energy demand, andestablishing standby emergency programs.
The implementation of these strategies will have impact on:development of alternate energy sources,vulnerability to import disruptions,economic growth, inflation and unemployment,environmental effects, andregional and social impacts.
Whereas these points of impact are only illustrative of the energy concerns, a national energy policy will contain some elements from each point.

SUPPLY AND DEMAND BACKGROUND
Demand has been growing at a 4- to 5- percent rate in recent years. Since 1950, energy consumption in the U.S. has outstripped domestic production. Coal production recently has been at 1940 levels. Oil production has been dec g since 1970. The last year the U.S. added to gas reserves was 1967 (excluding the Prudhoe Bay addition in 1970).
Sixty percent of the world oil reserves and 70 percent of the oil moving in world trade is centered in the Middle East. All important oil exporting nations with the exception of Canada are members of the highly effective "trust" (OPEC).
Whereas the 1973 oil embargo had minimal effect on the U.S. economy at the time, it did set in motion a series of events that threaten U.S. well being as a nation. The first effects of the embargo were:cut off of 14 percent of U.S. oil supply,sharp oil price increase,reduction of $10 to $20 billion in (20, and500,000 unemployed as a direct result.