bluuebunny/crossref_metadata_2025_split huggingface dataset:
Exploitation Of Minerals In Disposal Brines
Authors: Collins A. Gene , Crocker Michael E. 
Published: December 2007

Abstract
The practice of pooling disposal brines in gaining momentum in be petroleum industry, and large quantities of brines are processed by single disposal facilities. Through a survey of these facilities, the economic value of the minerals in some of these brines was determined. The results indicate that 6 of the 40 sampled brines contain concentrations of minerals and values comparable with those of a commercial brine, 29 brines contain concentrations of minerals more valuable than those found in seawater. One sample was near potable and one was usable for irrigation.

Introduction
The purpose of this study was to determine the composition of the salt water that is disposed of by some of the larger petroleum production facilities in the United States. According to Bleakley, Shell Oil Company disposes of 70,000 barrels per day (B/D) of salt water from the West Lake Verret field in Louisiana by subsurface injection. By subsurface injection, surface disposal, and evaporation pit, Shell Oil's Onshore Division, southern region disposes of about 375,000 B/D. If appreciable concentrations of valuable minerals are present in these waters, their recovery may be warranted. We were unable to obtain samples from these systems for this study.
For the study, samples of the salt waters were obtained from 40 disposal facilities. The samples were analyzed, and the maximum worth, brine value, and brine worth of each sample were determined. These values were compared with values for sea water and a brine that is used for mineral recovery as shown in table 6.

Minerals Recovered from Brines
Ever since someone inadvertently or premeditatively precipitated a compound from a salt solution the precipitated a compound from a salt solution the recovery of minerals from saline waters has been practiced. Salt water was produced from wells solely practiced. Salt water was produced from wells solely for the production of salt as early as 1800. Currently minerals other than sodium chloride that are recovered from saline waters include compounds of the following elements: Lithium, sodium, potassium, magnesium, calcium, chlorine, bromine, and iodine.
Lithium can be recovered by precipitation as lithium carbonate after removal of excess magnesium from a brine.
Multiple Use and Problems of Saline Aquifers in North Dakota
Authors: Noble E.A. 
Published: December 2007

INTRODUCTION AND SUMMARY
"A large proportion of the available water supply of North Dakota is saline," is a statement made in a recent U.S. Geological Survey Water Supply Paper assessing the saline water resources of this landlocked state at the geographic center of the North American continent. That federal agency report defines saline water as water containing more than 1,000 ppm dissolved solids; I shall use the same arbitrary definition in this paper. A quick inspection of a list of analyses of municipal water sources indicates that well over half of these sources are saline. Total dissolved solids in these town supplies are almost entirely within the 1,000–3,000 ppm range. Major anions are sulfate and bicarbonate; locally, chloride content is high. Sodium is a conspicuous cation; analyses showing several hundred parts per million are common.
Emphasis in this short paper will be on the "Dakota Aquifer," the most extensive and prolific bedrock aquifer in North Dakota. This aquifer is saline by the above definition and is only locally used as a source of water in North Dakota, although it is more widely utilized in South Dakota. It is the aquifer most commonly used for brine disposal in North Dakota oil fields. Water from the Dakota Aguifer is also injected in secondary recovery programs in some fields. In the agricultural field, natural discharge of saline Dakota water in a several-hundred square-mile area in the state's richest agricultural valley sharply reduces a productive potential that the world may productive potential that the world may someday need. Aquifers are locally present in the unconsolidated glacial deposits that mantle more than half the state, but both quantity and quality in many places are not suited for intensive development or wide application.
It is inevitable that North Dakotans must use saline water extensively, and must therefore look at saline water as a resource to be understood and managed to the best advantage. Feasibility of upgrading the quality of saline water for town supplies is now being investigated, and river diversion projects will introduce other possibilities. projects will introduce other possibilities. Background geologic studies of the nature and patterns of both bedrock and unconsolidated aquifers are furnishing information needed to interpret groundwater flow and chemistry, and to relate the two. Continuing studies are needed, not only for benefication and utilization of water, but also to furnish background knowledge for storage and waste disposal projects.
Sensitivity Studies in Profitability Analysis
Authors: Vogel Lawrence W. , Brons Folkert 
Published: December 2007

Abstract
In this paper a profitability model is developed for an exploratory drilling venture. Probability distributions are outlined for the Probability distributions are outlined for the model parameters and Monte Carlo simulation techniques are used to obtain estimates of venture profit, venture risk and a probability distribution of the profit.
Reported in the paper are the results of several sensitivity studies utilizing the data obtained in the profitability simulation. The sensitivity studies are designed to assist the decision maker in assessing the uncertainties inherent in an exploratory venture.
One sensitivity study analyzes the effects of changes in parameter values on venture profit and risk. This is done through the use of a Sensitivity Ratio which facilitates the measurement of the relative importance of changes in various model parameters on the value being observed.
In another study, two aspects of the convergence of the expected profit with model executions were analyzed. The first investigated a possible relationship between model executions and an accuracy range of profitability. No such relationship was found to exist. The second aspect investigated the differences in profitability simulated after 1000 and 10,000 model executions. No significant differences between profitability values was found.
A third study analyzed the relationships between return, risk and the number of wells drilled in the venture. Mathematical relationships were found which could relate these factors.

Introduction
Freedom from uncertainty is a luxury rarely enjoyed by the contemporary decision maker. In a society characterized by change, uncertainty is an established and accepted fact of life. This is especially true in the Petroleum Industry. Notwithstanding the Petroleum Industry. Notwithstanding the difficulties, the decision maker desires an evaluation which in some way measures the effects of these uncertainties.
In the face of uncertainties related to an exploratory venture, the most recurring questions are of the form, "What if. . . ?" What if the posted price of oil increases by 30%? What if we drill 30 exploratory wells rather than 20? How about 10 wells? What if the cost of a dry hole doubles?
Present Value of Hyperbolic Decline Production
Authors: Dietz D.N. 
Published: December 2007

Abstract
A new method for calculating present value of hyperbolic describe for all hyperbolic constants and all interest rates is presented that uses incomplete gamma functions. When the hyperbolic constant is an integer, the gamma function cannot be used and a new function is introduced to replace it.

Introduction
Brons and McCarry calculated present values of hyperbolic decline production for the cases in which the hyperbolic constant is either one (harmonic decline) or two. These are by far the most important practical cases, but it is still intriguing to find a universal solution to the problem. problem.

Derivation of Formula
Production is fully defined if the rate is Production is fully defined if the rate is given as a function of time. In many cases one uses the cumulative production and the rate of production decline. Thus there are four variables and there are six possible combinations of two variables. The relation between any two may serve as a definition. This study is based on the choice of production rate and time as the two basic variables.
(1)
Different wells may have production graphs of the same form, but do not necessarily have the same starting time on their common graph. in other words, there is no magic in taking the moment of initial production as zero on the time scale. A universal and mathematically more significant zero point for the time scale can be found where point for the time scale can be found where formula (1) tends to infinity.
(2)
The defining formula is thus simplified to
(3)a where (q t) is a single proportionality constant, i i though its components may differ for wells with different starting times on the same mathematical production curve. production curve. The production curve is fully characterised by the parameter a; the proportionality constant and the boundary conditions (time of start and stop) should not cause any difficulties.
PCP - A Computerized Data System for Manually Operated Oil Fields
Authors: Milton L. Harold 
Published: December 2007

Abstract
"Pumper Controlled Production" (PCP) is a system for gathering, storing, and recalling information on the status and producing capability of oil wells. This producing capability of oil wells. This system has been operational within Humble Oil and Refining Company's South Texas Division since the spring of 1968. Adapted to the IBM Model 1130 computer, the PCP system provides storage on disk files for data reported by field personnel regarding oil well status (Producing or shut-in? If shut-in, why?) and tested capability (bbls/day, gas-oil ratio, water cut, etc.). Available subroutines sort and manipulate the data into output formats useful for solving a variety of problems routinely encountered in the surveillance of oil producing properties. At present the operations of properties. At present the operations of 60 oil fields are being monitored with the PCP system.

Introduction
Some four years ago a need was recognized within Humble Oil and Refining Company's South Texas Division for a better tool to aid in maintaining a desirable level of surveillance over oil production. Rapid changes in well production. Rapid changes in well producing characteristics necessitate prompt producing characteristics necessitate prompt reaction by field and office personnel to sustain production volumes. In addition, permanent adoption of the Texas lease allowable assignment system in May 1968 (temporarily authorized during the 1967 Mid-East emergency) granted additional flexibility in scheduling production which had not been possible with the old "well allowable" system. This new allowable system permitted operators to transfer allowable" among wells within the same reservoir and/or field in order to optimize casinghead gas and gas-lift volumes and minimize water production. To maintain control of the rapidly changing field conditions and also benefit from the operating efficiencies offered by the new regulations called for collecting, transmitting, and storing large amounts of information on the status and producing capability of the wells.
Pressure Buildup in a Linear Gas-Condensate System
Authors: Pascal H. , Dranchuk P.M. 
Published: December 2007

Abstract
This paper examines the pressure buildup phenomenon for a gas condensate in a linear phenomenon for a gas condensate in a linear porous medium. The study considers the porous medium. The study considers the situation where the liquid-phase saturation is below the critical value (the liquid is immobile) and nondarcy flow of vapor occurs.
The results obtained indicate that the pressure buildup test may be used for the pressure buildup test may be used for the insitu determination of permeability, inertial resistance coefficient and liquid-phase saturation at the outflow face.

Introduction
Fluid flow through porous media depends upon the properties of the medium and the fluid, the physical laws that govern such flow and the initial and boundary conditions imposed. Consequently, if the laws governing flow are known and may be expressed mathematically, flow behavior can be predicted for any system for which the medium and fluid properties are known and the initial and boundary conditions are specified, by conducting the necessary mathematical experiments. On the other hand, given a mathematical statement of the laws governing flow and the fluid properties and initial and boundary conditions, observations taken while fluid flow occurs may be used to determine the properties of the medium. properties of the medium. In the exploitation of petroleum reservoirs, it is important that one be able to predict how a given reservoir will behave under various production schemes. It is equally important production schemes. It is equally important that well and field behavior be employed in the evaluation of reservoir properties.
In the particular case of gas condensate reservoirs, differential equations describing flow are available and numerical solutions have been developed so that the prediction of behavior is possible where reservoir properties are known. However, the development of closed form solutions for these equations appears to have been neglected so that the interpretation of field, well and laboratory tests results is at best uncertain.
It was, therefore, the object of this work to develop approximate analytical solutions to the differential equations describing gas-condensate flow through a simple porous medium and to show how these solutions might be used to interpret experimental observations.
High Pressure Miscible Gas Displacement Project, Bridger Lake Unit, Summit County
Authors: Burt R.A. 
Published: December 2007

Abstract
The Bridger Lake Unit is a 15,600 feet Dakota sand reservoir. The field was discovered by the Fork A No. 1 in December 1965. Since then, nine producing wells and two dry holes have been drilled to develop this near shore marine strat trap. laboratory tests indicated gas-crude miscibility at 5300 psi and 225 degrees F reservoir temperature. Gas injection was initiated in April 1970 and response to re-pressuring was observed in December 1970. Miscible pressure is expected in late 1971, and miscible recovery should be 80 percent of the swept reservoir volume.

Introduction
The Bridger Lake Unit is located about 81 miles east of Salt lake City, Utah, and twenty-five miles south of Lyman, Wyoming in Summit County, Utah and Uinta County, Wyoming, as shown on the attached index Trap, Figure 1. Township 3 North and Ranges 13, 14, and 15 West are in Utah and portions of 12 North, Ranges 114 and 115 West are in Wyoming. The field was discovered on December 17, 1965, with the Fork A No. 1 in Section 25, T3N, R14W. This Dakota sandstone stratigraphic trap has an average depth of 15,600 feet. Average ground level elevation is 9000 feet above sea level. The Unit was produced by reservoir oil expansion until April 4, 1970, when gas injection started. All produced gas less lease fuel and approximately 13 MMCFD of purchased gas are being injected. purchased gas are being injected.

Development
Since discovery, nine producing wells and two dry holes have been drilled. One producing well has been converted to gas injection, and one dry hole has been converted to water disposal. Table 1 summarizes the completion data for these wells. In general, 13-3/8 inch conductor pipe is set at 400–500 feet, and 9-5/8 pipe is set at 400–500 feet, and 9-5/8 inch intermediate is set at about 9000 feet. A full string of seven inch is run for production casing. A permanent packer is set above the perforations and 3-1/2" tubing is set into the packer. The first two wells were drilled with 2000 and 3000 feet of intermediate casing.
Deepwater Development Santa Barbara Channel
Authors: Rigg A.M. 
Published: December 2007

Abstract
In the 1968 Sarita Barbara Channel Lease Sale Humble acquired an interest in 47 offshore tracts. Of the Humble-operated properties, 80 percent are in water depths properties, 80 percent are in water depths exceeding 600 feet and 30 percent are in depths exceeding 1200 feet. Activities during the past 3-1/2 years include deepwater exploratory drilling and the development of deepwater producing technology.
About 30 wells have been successfully drilled in the Channel in water depths to 1500 feet. Two of the floating rigs have been equipped with special deepwater drilling systems. These systems are basically an evolutionary extension of proven floating drilling technology. proven floating drilling technology. Development plans include the use of deepwater platforms supplemented by submerged production systems. Design studies indicate the feasibility of extending platforms to 1000 foot water depths in the Channel. These structures are designed to resist the dynamic forces caused by earthquakes and storm waves, and are extensions of proven platform design and construction techniques.
The submerged production system developed by Humble includes clustered underwater wells drilled from a floating rig, manifolded together on a submerged structure, and produced to a nearby platform. Well control, monitoring, and servicing are performed remotely from the platform. The SPS is maintained using a remotely controlled manipulator. A 3-well SPS is now being land tested.
This paper discusses Humble's deepwater floating drilling activities and the development of technology for producing deepwater acreage in the producing deepwater acreage in the Santa Barbara Channel.
Applying Quantitative Risk Assessment to Casing Design
Authors: Keilty I. D. , Rabia H. 
Published: December 2007

Abstract
"There are three kinds of lies: lies, damned lies and statistics" - Mark Twain, ca. 1890
In 1993 British Gas decided that it would be advantageous to explore the possibility of developing a new casing design methodology, based on probabilistic concepts and historical data. This became necessary in order to align drilling design practice with that of other disciplines within the E&P group. For example, it was considered uneconomic to design a well to last for ever when platform life-spans were of the order of twenty years.. To date, British Gas has been encouraged by its findings, and the potential benefit from such an approach, demonstrated through initial studies into current casing designs.
Innovative Technology for a Cost Effective Land Rig
Authors: Mehra Sachin , Bryce Tom 
Published: December 2007

Abstract
Sedco Forex are currently building a new land drilling rig based upon the SIMPLER* concept. This SIMPLER* concept reviewed a wide range of issues associated with the well construction process and developed an innovative approach to drilling operations resulting in significant cost savings. The basis of this novel approach is to re-engineer and integrate the well construction activities with regards to personnel and equipment, and make extensive use of cost-effective technology from oilfield an&lt;J non-oilfield applications.
The use of multi-skilling and integration of personnel implies a smaller rig crew which results in direct and indirect cost savings. However, smaller crew also implies mechanisation of labour intensive tasks which not only reduces personnel exposure to hazardous activities, thus increasing safety, but also increases efficiency, thus reducing well costs. Smaller crew also implies improvements in rig design and material selection for minimum maintenance, ease of cleaning, etc.
This paper will briefly describe the methodology used for the rig design, which takes into consideration not only operator's priorities and needs, but also, local conditions and constraints. These issues combined with a simplified client/contractor relationship leads to a "fit for purpose" rig design.
In detail the paper describes the application of various cost effective technologies used on this land rig to achieve objectives of well cost reduction, improvements in HSE performance and rig mobility. Finally, it is explained; how these initiatives have influenced the overall rig design, showing that the use of innovative technology can have a marked positive effect on the economics of our future energy exploitation.
A Predictable and Efficient Short Radius Drilling System
Authors: Hill David , Askew Warren , Tracy Pat , Koval Vernon 
Published: December 2007

Abstract
A short radius drilling system has been designed and used commercially in reentry-sidetrack horizontal wells. The system consists of a unique articulated mud motor and a retrievable MWD tool. The articulated motor has a design that allows it to be used in both the build and lateral sections of the hole, reducing the number of motors required on location. The motor can be rotated in the lateral section for faster drilling rates, angle holding, less friction, and longer reaches. The build rate of the motor is smooth, predictable, and easily changed on-site. It has been used with both PDC and rock bits, giving the operator and the directional driller greater flexibility and better efficiency.
A set of case studies highlights the benefits of the system. Four wells, with curve radii between 75 and 260 feet (build rates between 75°/100' and 22°/100’) demonstrate the flexibility and robustness of the system. The drilling parameters, hardware and tubulars used are examined.
Balanced Risk Management of Drilling Process Accelerates Field Development at Reducing Horizontal Well Duration and Cost
Authors: Ogidan Biodun , Akinmoladun Toba 
Published: December 2007

Abstract
This paper addresses CHANGE and the process for managing associated challenges in well construction. It is based on 2 years of continuous drilling of horizontal wells in a desert environment, using a trailer mounted land rig.
Adopting a balanced risk management approach in introducing CHANGE to various critical operations, activities and contracting relationships, a carbonate reservoir in the Saih Rawl field in the Sultanate of Oman is being successfully developed with continuous cost reduction using a slim casing design.
Cost effective development of the Saih Rawl field is so successful that an initial plan of 6 medium radius horizontal wells has been revised to an actual plan of 30 wells. This medium depth (3000m) wells have been drilled back-to-back and at more than a 20% reduction in time and cost.