bluuebunny/crossref_metadata_2025_split huggingface dataset:
Annular Flow Dynamics
Authors: Willis H. Craig , Tomm Wayne R. , Forbes Eugene E. 
Published: December 2007

Abstract
The new analysis technique of Annular Flow Dynamics is a simple, practical way to predict and control rheology and hydraulics in predict and control rheology and hydraulics in Drilling Fluid Systems. It is based on field experience in the sloughing shale areas of Canada and on a recently developed method of calculating Annular Pressure Losses with greater accuracy and more simplicity than previous methods. previous methods. Annular Flow Dynamics is primarily oriented towards improving drilling practices in sloughing shale situations. However, as holes become deeper, additional restrictions are imposed on casing programs and hole size. These make it even more important to be able to determine and possibly predict certain drilling fluid parameters for maximum performance. This paper shows how, by use of performance. This paper shows how, by use of a logarithmic plot of viscometer data, the following can be determined:Effective annular viscosities at any pump rate and for any flow properties.Flow type (laminar or turbulent).Accurate annular pressure losses.Approximate bit nozzle shear rates.Upper and lower limits on both flow properties and pump rates for optimum well bore stabilization and minimum E. C. D. (Equivalent Circulation Density).Approximate ascending velocity of cuttings.
In the past year, Annular Flow Dynamics has been used on a field basis in Canada with very positive results.

Introduction
Well bore instability occurs primarily when shales absorb water. Controlled activity oil minds are presently the only way to satisfy the shales affinity for water. The mechanism of sloughing shales due to actual change in the physical and chemical properties of the shale physical and chemical properties of the shale have been thoroughly researched and discussed by the industry. Less attention has been paid to the mechanical aspect of stabilizing shales by well planned and flexible rheological and hydraulics programs.
The Influence of Gas Saturation on Waterflood Performance - Variations Caused by Changes in Flooding Rate
Authors: Dandona Anil K. , Morse R.A. 
Published: December 2007

The Influence of Gas Saturation on Waterflood Performance - Variations Caused by Performance - Variations Caused by Changes in Flooding Rate

Abstract
It has been recognized that the presence of a gas saturation prior to waterflooding can have an important influence on oil recovery. The published results on the subject are derived from laboratory experiments on essentially one-dimensional horizontal systems flooded with low pressure differentials. In field applications, high pressure gradients could cause important effects not noted in the laboratory studies such as the disappearance of part or all of the gas by solution in the oil bank. Also, it has been realized that gravity forces make it impossible to initiate and maintain a uniform gas saturation from top to bottom of the production section.
By the use of numerical models a study has been made of the effects of flooding rate on performance of waterfloods in reservoirs having performance of waterfloods in reservoirs having gas saturation. Flooding rates over a very wide range have been simulated. At very high rates the gas is put into solution in the oil bank ahead of the water so no gas saturation effect is noted. The simulated performance at very low rates in the absence of gravity check very well with the published laboratory data. Introduction of gravity causes markedly different performance from that of the one-dimensional performance from that of the one-dimensional horizontal systems because of the nonuniform vertical distribution of initial gas saturation and gravity effects on the injected water distribution.

Introduction
At the present time, a large fraction of the oil originally in place is left unrecovered in oil reservoirs after depletion by the best methods available. The need for added recovery is of equal importance with the search for new oil-producing structures. Waterflooding is, and has been in the past, the most universally used method for increasing oil recovery beyond the levels provided by natural depletion. Improvements of waterflooding should lead to economic recovery of additional oil in substantial quantities. One of the methods that has been proposed for increasing recovery of oil by water proposed for increasing recovery of oil by water displacement involves creating a gas phase ahead of the waterflood front.
As early as 1922, Russell found experimentally that flooding of oil reservoirs by a mixture of water and gas yielded considerably more oil than water or gas drive alone. In the year 1932, producers in the Bradford field injected their surplus produced gas into oil reservoirs to conserve gas. The operators noted that the injection of gas prior to waterflooding resulted in improved oil recoveries.
East Leman Unit Water Influx Investigation
Authors: Jeffries-Harris M.J. 
Published: December 2007

This paper was prepared for the Second Annual European Meeting of the Society of Petroleum Engineers of AIME, to be held in London, England, April 2–3, 1973. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor 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 two dimensional, two phase vertical reservoir model was used to simulate bottom water influx into the East Leman Unit. The influence of well cluster drainage, well drainage area, aquifer extent, permeability level, horizontal-vertical permeability ratio, aquifer-gas zone permeability ratio, and production after breakthrough were production after breakthrough were investigated. The results indicate that water influx will not be a significant factor in future performance primarily because of extremely low water mobility associated with the reservoir rock.

Introduction
The Leman Field is a large dry gas reservoir located approximately 30 miles off the East Anglian coast. It was discovered in 1966 and produces from the Rotliegendes sandstone, an aeolian deposit of Permian age, the gas being trapped in a northwest-southeast elongated dome approximately eighteen miles long by eight miles wide. The top-of the producing formation varies from 5,900 to 6,750 feet subsea within the field area providing a gross pay thickness at the crest of the structure of up to 850 feet.
The Leman Field reservoir is underlain by bottom water almost everywhere, and the influence on both well and field performance requires evaluation. performance requires evaluation. Furthermore, the importance of the field, its location offshore, and the essential fulfillment of contract requirements necessitates accurate long range development planning. To achieve this objective for the heterogeneous reservoir rock reservoir simulation for performance prediction is highly desirable. performance prediction is highly desirable. A two phase, three dimensional simulation model would permit the best evaluation of aquifer influence. However these models require elaborate data input and are time-consuming and difficult to set up.
Theoretical, Laboratory and Performance Characteristics of a Seawater-Salt Base Mud System for the North Sea
Authors: Methven Norbert , Schumann Claus 
Published: December 2007

This paper was prepared for the Second Annual European Meeting of the Society of Petroleum Engineers of AIME, to be held in London, England, April 2–3, 1973. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor 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 drilling mud system has been developed and applied in the North Sea and its environs that has a pollution free composition, a seawater-salt base and other unique advantages.
The salt base includes use of magnesium chloride, potassium chloride and/or sodium chloride. In addition to the seawater-salt base, the mud system includes magnesium compounds and a blend of polymers. The formulation does not include clays or poisonous thinners. The included salts poisonous thinners. The included salts provide shale inhibition and minimize provide shale inhibition and minimize dissolution of subsurface salt formations. Also, the salt water reduces formation damage and the included colloids and polymers are acid soluble to assure maximum acid stimulation results where applicable.
This paper describes the general chemistry, the results of laboratory tests, and the field performance of this mud system. In addition, this paper provides similar information on an adaptation of this mud system that has been developed in the United States and applied in the Gulf of Mexico.

Introduction
Three prime considerations in drilling exploration and development wells are prevention of pollution, minimization of prevention of pollution, minimization of drilling cost and maximization of well productivity. Each of these can be significantly productivity. Each of these can be significantly affected by the drilling fluid.
Pollution Prevention Pollution Prevention Pollution can occur from drilling fluids and drilling operations through use of poisonous and/or unsightly materials in the poisonous and/or unsightly materials in the formulation that may find their way to the sea. Thus in designing a drilling fluid, it is most desirable to start with non-poisonous materials and materials that are compatible with the environment.
New Developments in Platform Production Safety Systems
Authors: Carman R. Jan , Curington Wayne 
Published: December 2007

Abstract
A review of new equipment developments for platform wellhead safety systems is presented with special emphasis on increased operating efficiency and improved safety. This equipment more effectively meets new requirements of stricter regulations and inspections by the various regulatory agencies, while still maintaining maximum production efficiency and minimum downtime. For example, a much-improved flowline pressure monitor and safety-valve shut-down system has been developed, which allows the operator to set his low and high pressure shutdown points rapidly and with a resolution and accuracy not obtainable with conventional equipment. This capability is especially valuable in high production gas fields, such as those found in some North Sea areas, where the difference in flowline pressure at normal flowrates and at broken-line flowrates is small.
High capacity hydraulic equipment used in blow-out preventer control systems is being utilized to control hydraulic downhole safety valves, which are replacing the velocity-operated check valves previously used. Equipment such as high capacity gas driven and electric driven piston pumps, large float type accumulators and sliding seal pilot valves, all pumps, large float type accumulators and sliding seal pilot valves, all well proven in the drilling industry, is being applied to downhole safety valve control. This increased hydraulic capacity allows the safety valves to be opened at much faster rates after a shut-down, thus reducing lost production time and safety valve seal wear. production time and safety valve seal wear. New developments in the areas of electrical control systems, new safety valve operator designs, safety valve operator fire caps and position sensing limit switches are also described.
Legal and Regulatory Aspects of Fieldwide Unitization of Petroleum Reservoirs Extending Across Jurisdictional Boundaries of Bordering States in the North Sea
Authors: Horigan James E. 
Published: December 2007

This paper was prepared for the Second Annual European Meeting of the Society of Petroleum Engineers of AIME, to be held in London, England, April 2–3, 1973. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor 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
The discovery of commercial petroleum deposits straddling international sub-sea boundary lines in the North Sea has become a reality. Present bilateral agreements between States bordering on the North Sea anticipated the possible existence of such jurisdictionally divided deposits or structures and established in general terms a joint policy understanding for the making of future international agreements on exploitation. These agreements are examined, particularly with reference to differing legal particularly with reference to differing legal and regulatory requirements between the bordering States as pertain to their respective exploration and production licensing practices. Fieldwide unitisation of such deposits and structures, as a method of apportionment and cooperative exploitation, is recommended for the avoidance of physical and economic waste, for the protection of the interests of the States and their respective licensees, and to achieve the greatest ultimate recovery of petroleum resources. The various and differing petroleum resources. The various and differing licence and regulatory terms are considered with reference to a formal unitisation plan, and consideration is given to the need for a uniform policy between the bordering States with respect policy between the bordering States with respect to the conduct of operations and other matters.

TEXT
The boundary lines which serve to delimit geographically the sub-sea jurisdictions of the bordering States of the North Sea were established, for the most part, prior to the discoveries of commercial oil and gas deposits in the North Sea. Consequently, there was no predetermined certainty on the part of the Governments on how and in what manner nature itself might cooperate to confirm or deny the validity of the equitable principles on which the manmade political lines of subdivision were drawn and agreed.
Operating Experiences - Offshore Storage and Loading Facilities
Authors: Muller S.E. , Prince C.A. 
Published: December 2007

This paper was prepared for the Second European Meeting of the Society of Petroleum Engineers of AIME, to be held in London, England, April 2–3, 1973. 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 requested 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 discussions 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 Company has been operating the following offshore installation for three years:
One 500,000 barrel storage tank.
Two 250,000 barrel floating storagevessels.
One SPM, capable of handling 200,000DWT tankers.
The installation was selected based on economics of a given design and an assumed weather condition, tanker schedule, and mechanical failure. Experience has shown the submerged storage to be superior mechanically as well as exhibiting good quality wateroil separation. Costs, both initial and operating, are presented to show the relative economic merits of each type of storage. The weather conditions for the past three years as well as tanker schedule will be compared to that which was predicted before operations were commenced.
There have been some revisions made to the original installation. These revisions have been dictated by experience and will be presented in this paper.

Introduction
Dubai Petroleum Company, a wholly-owned subsidiary of Continental Oil Company, and operator for a multinational group of companies of a concession offshore from Dubai, U.A.E., has been operating a fully offshore crude oil producing and export facility in the Fateh Field for three and a half years.
At the time of start-up, the totally offshore characteristic of this operation was unique in the petroleum industry. The most renowned component of this installation was the Khazzan Dubai No. 1, the first submerged crude storage vessel of its kind. Complementing this vessel were two floating storage vessels, Majmaa I and II, converted from the forebodies of ocean going tankers. Total storage volume was 1.1 MM barrels.
Structural Relations of Organic Corrosion Inhibitors and Scale Preventives as Applied to Oil Field Chemistry
Authors: Hansen Gerald D. 
Published: December 2007

Abstract
Semipolar molecules such as surfactants are extensively employed in the production of petroleum for the solution of problems of petroleum for the solution of problems of corrosion, scaling, emulsion formation, etc. This paper describes some fundamental relations which have been developed between the structure of surfactant molecules and their action as corrosion inhibitors and as scale preventives. Also given are laboratory methods for predicting when scaling, etc., may be expected due to incompatibility of oil-field brines with one another or with additives such as employed in polymer and micellar flooding. polymer and micellar flooding. Correlation of published data on certain polar materials based on sulfur, oxygen and polar materials based on sulfur, oxygen and nitrogen have shown that in a given homologous series, corrosion inhibition effectiveness increases with increasing number of carbon atoms in the alkyl chain(s) attached to the polar group which adsorbs onto the metal. The polar group which adsorbs onto the metal. The Langmuir Adsorption constant increases by a factor of ten for each additional four carbon atoms added to the molecule, whether the chains are straight or branched, for sulfuric acid used in the pickling of steel. There is no significant difference in corrosion inhibitor efficiency in this system among the homologous series of oxygen and nitrogen compounds such as amines, ketones, and aldehydes reported; however, sulfur compounds of a given carbon number appear to be about two orders of magnitude more effective than nitrogen or oxygen compounds of the same carbon number.
Studies carried out on polar materials used as corrosion inhibitors and/or as scale preventives in other systems such as simulated preventives in other systems such as simulated oil field brines, cooling waters, boiler feed-waters, have indicated that although the adsorption concepts developed for acid corrosion inhibitors are of importance, other factors are of equal or greater importance. The concept of rate control of a precipitating salt such as calcium carbonate is developed and data presented indicating that the effectiveness presented indicating that the effectiveness of rate control additives such as phosphonates and polymers is determined by the magnitude of the formation constant of the compound formed by the cation and the additive as compared to that of the cation and the precipitating anion.
Stimulation Of Low Permeability Gas Wells In The Rocky Mountain Area
Authors: Carney M.J. , Wieland D.R. 
Published: December 2007

This paper was prepared for the Rocky Mountain Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in Casper, Wyoming, May 15–16, 1973. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon requested 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 discussions 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 shortage of natural gas, which has resulted in an increase in gas prices, has stimulated the interest in gas production. Law pressure, low permeability gas producing formations are presently being completed, which in the past were plugged or completely neglected.
The majority of these gas wells have to be stimulated for them to be economical. Because of the low formation pressures and/or low permeability, great care must be taken to choose the proper fluid when performing a stimulation treatment. Fluid imbibition, capillary forces, frac fluid impurities, formation composition are some of the more critical factors that have to be considered.
This paper discusses the approach taken to evaluate the different low permeability gas formations as to the type of frac or acid stimulation fluid to use, the new fluids developed specifically for this type of problem, and field stimulation results for the problem, and field stimulation results for the different fluids used.

Introduction
Increasing demand and resulting shortage of natural gas has renewed interest in the search for and production of this product. Many wells and reservoirs which have been marginal or non-commercial in the past can now be produced profitably. The reason for their marginal or non-commercial status in the past has been the inability to successfully stimulate them to provide flow rates which were adequate at existing prices. Increased prices have reduced flow rates required for profitable production, but stimulation is still necessary production, but stimulation is still necessary and the stimulation problems still exist.