bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Applications of a New Nuclear Magnetic Resonance Fluid Characterization Method
Authors: Freedman R. , Heaton N. , Flaum M. 
Published: December 2007

Summary
This paper discusses the application of a new magnetic resonance fluid (MRF) characterization method to field data acquired by a nuclear magnetic resonance (NMR) well-logging tool. The theoretical and experimental foundation underlying the method was discussed in a previous publication.1 The MRF method provides a detailed formation evaluation of the near-wellbore region investigated by modern NMR logging tools. This information includes total and bound-fluid porosities, hydrocarbon saturations, oil viscosities, and hydrocarbon-corrected permeabilities. This paper presents MRF oil saturation and viscosity estimates in oil-bearing wells.
In this paper, we first provide a short review of the main ideas and key equations that make up the MRF method. We discuss the generalization of the MRF method to logging data acquired by the Combinable Magnetic Resonance (CMR)** tool and apply the method to mixture data acquired by a CMR tool on crude-oil and water samples.
We also discuss the existing database of MRF results on partially saturated rocks and present new laboratory results that include blind tests on Yates field dolomite rocks measured at initial and residual oil saturation.
The sources of uncertainty inherent in NMR diffusion-based viscosity estimation in reservoir rocks are discussed, and we propose a strategy that accounts for the uncertainties and provides reasonable estimates of oil saturations and viscosities. The strategy is applied to the MRF analysis of the field data in this paper.
The MRF method is applied to CMR station log data acquired in three wells. Analysis of the MRF data and the results from each of these wells is discussed.
Sampling Procedures for Oil Reservoir Fluids
Authors: Reudelhuber Frank O. 
Published: December 2007

Introduction
The problem of determining the productive capabilities and ultimate yield of oil reservoirs is approached through use of various engineering calculations utilizing basic data. These data are concerned with the formation itself, the fluids contained therein, and the fluid-flow relations between the formation and the contained fluids. The first and last of these are obtained from core samples and are, in the main, based on an accumulation of data which can be evaluated and applied in a statistical manner. The fluid properties, on the other hand, are usually obtained from one sample and are applied to the reservoir as a whole. While considerable effort has been expended in developing the procedures for laboratory analysis, little his been done toward perfecting procedures for obtaining the samples from which all data are obtained and upon which, subsequently, all calculations are based. It is readily apparent that no laboratory procedures, however intensive, can result in sound engineering data from unreliable, possibly non-representative, fluid samples: therefore, it is important that every practical effort be made to obtain representative samples through proper well conditioning and sampling. Many of the difficulties encountered in sampling reservoir fluids can be avoided, or minimized, if samples are collected as soon as possible in the productive life of a reservoir. Some difficulties are inherent, however, and the following discussion is directed toward a better understanding of the problems involved and of the procedures available for collecting reliable fluid samples.
Ewald Method for the Analytic Solution of Simple Reservoir Problems With Neumann Boundary Conditions
Authors: Natoli Vincent D. , Pergler Joseph , Mifflin Richard 
Published: December 2007

Summary
Analytic solutions to reservoir flow equations are difficult to obtain in all but the simplest of problems. Under the assumption of steady-state conditions, incompressible flow, and a translationally invariant permeability tensor, the Darcy equation leads to Laplace's equation for the hydrostatic potential. Methods of potential theory in both two and three dimensions may then be brought to bear on the problem, which is usually classified by the type of boundary condition. Dirichlet and Neumann-type boundary conditions, where the value of the potential and the flow respectively are specified on the boundary, are elegantly solved by simple superposition of sources in the case where the boundary is at infinity, or by Green's function techniques in cases with finite boundaries. Reservoir simulators, limited by the finite extent of their models, impose conditions on the flow at the boundary, which through Darcy's equation is proportional to the gradient of the potential. Analytic solutions to these Neumann boundary conditions are in general approached using the method of images to explicitly construct the Green's function for a point source. However, as can be easily shown, problems with no-flow boundary conditions lead to an infinite array of images. The sum of the potentials of the infinite lattice results in the solution in the simulation box. In this paper, we make use of the direct analogy between the reservoir flow equations and electrostatics to illustrate a method commonly used in the field of solid-state physics to sum the potentials of crystal structures. The advantage of this method is that it is fast, easily implemented, and may be used for an arbitrary configuration of injecting and producing wells, as long as net flow is zero. In addition, it is useful for a very general class of simulation boxes, not limited to orthogonal axes.
Unique Offshore Recovery System Dramatically Reduces Environmental Impact by Recycling Stimulation Proppant
Authors: Slater Martin , Perez Daniel , Teesdale Chris , Hilbig Nicholas 
Published: December 2007

Summary
During the past 4 years, the use of multiple-zone proppant fractures has significantly improved production and the ultimate productive life of horizontal wells in the Valhall chalk field. A typical well is designed with up to 10 proppant-fractured zones. The stimulation technique involves pumping as much as 300,000 lb of proppant into each zone, and during this process, up to 70,000 lb of excess proppant may remain in the wellbore, which is cleaned out with coiled tubing. Because the material contains a resin coating to facilitate adhesion in the reservoir, disposal is restricted.
This waste previously had to be collected offshore, placed in large bags, containerized, and shipped onshore for incineration—a practice that was costly, wasteful, and environmentally suspect. In 1997, engineering studies revealed that the properties of the waste material made it suitable for recycling and use in future operations with minimal impact on fracture performance. While reusing proppant has become an accepted practice with no noticeable effect on well productivity, logistically it had some limitations. The material still had to be collected offshore and transported onshore, where it was stored for several months before being reloaded into the stimulation vessel for reuse in the next fracture treatment. This represents storage problems and environmental exposure of these materials. Furthermore, with no unforeseen delays, this was a 24-hour, two-way trip.
This paper describes the development and successful application of a unique system that allows the excess proppant to be collected, treated, and recycled on location. The authors will discuss the evolution of the recycling technique and discuss the stepchange improvement that allows the material to be immediately reused offshore using specialized vacuum equipment.
Approximately 150,000 lb of proppant was successfully recovered and recycled from the first well. The technique is still evolving and is likely to become a standard operation on Valhall wells. The offshore collection and recycling technique has eliminated the logistical problems associated with the previous method and will in time reduce the total proppant costs, along with minimizing the associated health, safety, and environment (HSE) impact.
Real-Time Specific Energy Monitoring Enhances the Understanding of When To Pull Worn PDC Bits
Authors: Waughman Robert J. , Kenner John V. , Moore Ross A. 
Published: December 2007

Summary
Knowing when to change dulled bits can significantly reduce costs, which can be particularly important in high-cost environments. However, current techniques are based more on speculation and hope rather than science.
The concept developed to dramatically improve this inefficient decision process involved measuring the mechanical energy input at the drill rig floor, calculating the drilling specific energy (SE), checking the current formation type with real-time downhole gamma ray (GR) readings, comparing the SE with the benchmark new-bit SE, and then using these values to assess the bit's "dull" state.
This method has been proven to work in synthetic-based mud systems in which balling does not mask the bit's dull condition. It was imperative that the operator proved that this process worked in water-based drilling fluids that had replaced earlier synthetic muds because of environmental concerns, cost, and improved performance in water-based mud (WBM). Recently, the operator established that this process worked in water-based mud systems treated with antiballing chemicals. The case studies in which this methodology was developed are presented and discussed.
Management of Environmental, Social, and Health Issues Involving Indigenous Communities at the Villano Project in the Ecuadorian Amazon Region
Authors: Vacas Francisco , Gonzalez Mario , Sanabria Vinicio , Madera Angelo 
Published: December 2007

Summary
As one of the leading oil and gas companies in the world, Eni has always operated with full respect for the culture, society, and environment of each country in which it works. Through the work of its affiliate companies, the Eni Group pursues an active policy of involvement and cooperation that aims at contributing to the overall socioeconomic well-being of the communities with which it interacts.
In Ecuador, Eni's affiliate, Agip Oil Ecuador B.V. (AOE), is the operator of Block 10 in the Ecuadorian Amazon region and is faced with a number of critical environmental, social, and health issues involving indigenous communities. Most of these communities belong to the Quichua ethnic group with other groups, like the Huaorani and Shuar-Ashuar, also represented. AOE's health programs cover more than 6,000 people, involving some 3,000 colonists.
The program is now in full development since its original inception more than 2 years ago (1999). It aims at protecting the environment and improving the quality of life for the inhabitants of more than 24 indigenous communities by providing primary health care. AOE has a comprehensive environmental-protection program as well as social and health programs. Agip is involved in disease prevention and control, health education, basic sanitation and safe water distribution, vaccination, nutrition, maternal and child care, treatment of common disease and injuries, access to essential medicines, and emergency medical evacuation. In addition, a new program is now being implemented to preserve the local tradition of natural medicine.
AOE's program is supported by the local branch of the Ministry of Health and nongovernmental organizations (NGOs), such INNFA (Inst. Nacional del Niño y la Familia) and SNEN (The Natl. Malaria Eradication Inst.).
As a result, this program has successfully reduced the morbidity and mortality rate in the region. At the same time, it protects the delicate environment of the Amazon region surrounding Block 10 and its area of influence, always respecting the culture and traditions of the people.
Case Study: First Intelligent Completion System Installed in the Gulf of Mexico
Authors: Nielsen V. B. Jackson , Tips T. R. 
Published: December 2007

Summary
To maintain profitability in the development of marginal fields, many new technologies and concepts have been exploited. One of the most promising technologies has been the "Intelligent Well Concept," which allows the operator to produce, monitor, and control the production of hydrocarbons through remotely operated completion systems. These systems are developed with techniques that allow the well architecture to be reconfigured at will and real-time data to be acquired without any well intervention. This paper concerns a case history in the Gulf of Mexico in which an operator was able to justify completion of marginal wells based on the cost savings generated from innovative technologies.
A Field Test of Microemulsion Flooding, Chateaurenard Field, France
Authors: Putz A. , Chevalier J.P. , Stock G. , Philippot J. 
Published: December 2007

Summary
A pilot test of microemulsion flooding was conducted in a single five-spot pattern in the Chateaurenard field in France. The test had to accommodate a 40-mPa·s (40-cp) oil viscosity and a regional pressure gradient across the pattern. A very clear oil bank was observed, resulting in a substantial increase in oil production.

Introduction
Société Nationale Elf Aquitaine (Production) is conducting a microemulsion/polymer flooding pilot test in its Chateaurenard field in the southern part of the Paris basin. This project involves the participation of the Inst. Franç du Pétrole, and it has been partially funded by the Commission of the European Communities. The primary objectives of the pilot are to (1) demonstrate the efficiency of the process under field conditions, (2) develop the technology involved in such an operation, and (3) assess the economics of fieldwide extension.
The permeability of the unconsolidated sand reservoir is very high, and the connate water is fresh. Both of these factors are favorable for micellar flooding application. The oil is relatively viscous [40 mPa·s (40 cp)]. Even though the oil saturation is far from residual, the well effluents have a high water cut due to poor areal efficiency of oil displacement by water. A microemulsion flooding scheme, with its readily achievable mobility control, appeared to offer a feasible recovery mechanism. However, the injection of viscous fluids limits the injection rate and requires a higher concentration of chemicals. The Chateaurenard oil viscosity is above the limit of 20 to 30 mPa·s (20 to 30 cp) mentioned in some publications.1,2
The well arrangement is a 10´103-m2 (2.5-acre) inverted five-spot pattern with one observation well. The pilot area was determined through coring, logging, and interference testing. These data indicated an initial pressure gradient across the pattern.
Three separate injection phases compose the process: microemulsion, polyme, and chase water. Microemulsion was formulated using field crude and water. Injection was initiated in Feb. 1978 and followed by polymer concentration started in April 1979 and led to chase water in Nov. 1979. The polymer buffer has been overdimensioned somewhat to test specifically the efficiency of the microemulsion, without interference from poor mobility control following it.
A significant response was observed from the producing wells 2 months after the start of operations. In this paper we present pilot design, performance, and an interpretation of the results.

Field Description
The Chateaurenard field, outlined in Fig. 1, is part of the Neocomian (Lower Cretaceous) oil reservoirs found in the southern part of the Paris basin. They are located 100 km (62 miles) south-southeast of Paris; the oil-bearing zones extend over an area of 20 km2 (7.7 sq miles).
Offshore Pile Grout Monitoring Method
Authors: Brooks Fred A. , Ruez William J. 
Published: December 2007

An electrical conductivity method of monitoring offshore pile grout isdescribed. By using this method, the initial appearance of the grout, itscontinued presence, the subsequent extent of set, and its quality can bemeasured remotely.

Introduction
The connection between the seabed and offshoresteel platforms is achieved by using tubular steel pileswhich are passed through the main leg and/or theskirt pile sleeves. The piles are either driven to final penetration or cemented in predrilled holes.Although piles passing through the main legs may beconnected to the structure by welding at the deck level, in many structures the anular space betweeneach pile and leg or skirt pile sleeve is filled to somepredetermined elevation with cement grout. Thepresence of annular grout can significantly enhanceplatform strength. This strength enhancement canbe included in platform design considerations if thedesigner can reasonably assume a given degree ofgrout coverage and quality.
Ref. 2 specifies minimum 24-hour compressivestrength for grout at 1500 psi (1034 kPa). API RP 2A(Section 6.12) also specifies that a "means should beprovided to determine that the spaces have been filledas required."The method described in this paperoffers a technique for satisfying the API standards, as well as providing other measurementsi.e.,the identity of the resident fluid in the annular space(fresh water, seawater, or air);the arrival of thecement top at predetermined elevations;the occurrence of cement "fallback" in the event ofpacker failure;the set of the cement; andthequality of the set cement.
In previous practice, visualobservations, diver-collected samples, andmonitoring of the volume of grout pumped havebeen used for these purposes.
For example, in the grouting of the piles of theCognac platform "the overflow of the grout at thetop of the pile sleeve was observed with the remote-control vehicle (RCV). The diver caught two samplesfrom the overflow in plastic bottles. The volume ofgrout pumped was about 40% in excess of thevolume of the annulus." These methods are limitedto practical diver operating depths and, with regardto the use of the RCV and the collection of overflowsamples, information is generated regarding only thegrout that overflows the annulus. Knowledge of thepermanent level of the grout and the quality of thegrout inside the annulus is lacking.
JPT
P. 2234＾
Rate of Return Calculations as a Measure of Investment Opportunities
Authors: Glanville James W. 
Published: December 2007

Introduction
Investments or capital expenditures form the frame-work for a company's future development and are a major determinant of efficiency and competitive power. Consequently, the wisdom of corporate investment decisions has a profound effect upon a company's future earnings and growth. From the standpoint of the stockholder, an effective capital expenditure program is apparently the only bulwark against the seemingly endless inflationary spiral. From the standpoint of labor, capital expenditures represent the basic source of future income which must exist before wage advances can be made.
Any business is continuously faced with the problem of making investment decisions. For the large integrated oil company, opportunities for investment exist in enterprises ranging from marketing to petrochemical, to exploration for and development of producing oil properties. Even for the very small business the problem of reinvestment of earnings, expansion, or diversification is a continuing one.
Foresighted judgment is an essential requisite for wise decisions about capital expenditures. However, for such judgment to be sound, it must be based on an analysis of all the facts, many of which may be extremely technical and complex. Management needs an objective means of measuring the economic worth of individual investment proposals in order to have a realistic basis for choosing among them and selecting those that will mean the most to the company's prosperity and growth. Probably a business organization will not have adequate investment capital at its disposal to make all the investments which have the potentiality of producing a profit; and even given unlimited capital, there is a maximum number of investment opportunities which can be efficiently handled with a given size organization. Therefore, it is apparent that either limited capital or the size of the organization may restrict the number of investments which can be made in a given period. Choosing among these investment opportunities, therefore, is of paramount importance.
A High-Pressure Dry-Gas Miscible Displacement SchemeSimulation and Economics
Authors: Flores Jorge , Pawelek J. 
Published: December 2007

Summary
To develop an enhanced recovery scheme for theCardium E pool, the feasibility of waterflooding andgas injection was examined. A compositional modelwas developed to account for mass transfer andchanges in composition of this undersaturated, highly volatile oil system. High-pressure dry-gasinjection was desirable to achieve a high degree ofmiscibility.

Introduction
The Caroline Cardium E pool, discovered in June1974, is approximately 65 km (40 miles) southwest ofRed Deer, Alta. (Fig. 1). The discovery well was theHudson's Bay Oil and Gas (HBOG) 10–16–34–06W5, which was followed by the drilling of five additionalwells in the Bearberry Cardium A pool(T34, R06W5).
The existence of a 23-km (14-mile) northwestextension of this Cardium trend was proved by thedrilling of the Pacific et al. Ricinus 10–22–36–08W5 inAug. 1975 and subsequently confirmed by the Pacificet al. Ricinus 11-28-35-07W5 in Jan. 1976. The arealextension involving T36, R08; T35, R07;and part ofT36, RO7 will be referred in this study as the areaoperated by Pacific Petroleums Ltd. The oil reservoirin these wells initially was referred to as the CardiumU pool.
In Aug. 1976, an application was filed with theAlberta Energy Resources Conservation Board(ERCB)** requesting a special 130-ha (320-acre)spacing unit comprising either the northern orsouthern half of the section. This request was basedmainly on the marginal economics for developingthis thin-pay, narrow-type reservoir. It was approvedby the ERCB in an order prescribing drilling spacingunits in the Caroline area that became effectiveNov. 1, 1976. On this basis, the well allowable wasapproximately 9 m3/d (58 STB/D).
By Dec. 1976, a total of 13 wells had been drilled inthe Pacific-operated area. At that time, based onpressure data and reservoir fluid analysis, Pacific pressure data and reservoir fluid analysis, Pacific filed an application requesting that the RicinusCardium E pool and the Bearberry Cardium A poolbe coalesced into the Caroline Cardium E pool.The ERCB's approval to this matter was given inFeb. 1977.1 As of June 1979, a total of 34 wells hadbeen drilled in the Pacific-operated area.
To develop an optimum enhanced recovery schemefor the Caroline Cardium E pool in the Pacific-operatedarea, the feasibility of a waterflooding andhigh-pressure dry-gas miscible displacement schemeshave been examined in this study. A number ofpapers have emphasized the field application of papers have emphasized the field application of high-pressure dry-gas or vaporizing gas miscibledisplacement. It has been shown that a miscibledisplacement of oil with dry gas can be accomplishedif the oil is rich enough in the intermediatecomponents (C through C). The reservoir fluid fromthe Cardium E pool, being a highly volatile oil, appears to be amenable to undergo miscibledisplacement under high-pressure dry-gas injectionand involving multiple-contact miscibility of the gaswith the reservoir oil.
JPT
P. 359
Nitrification and In-Situ Uranium Solution Mining
Authors: Johnson David , Humenick Michael J. 
Published: December 2007

Abstract
The objective of this research was to determine the potential for conversion of ammonia to nitrate as a result of uranium solution mining operations. The work included literature evaluation and laboratory experimentation in both batch and continuous sytems. Results have indicated that a potential for nitrification could exist for some portions of the solution mining operating cycle. However, inhibition of nitrification was observed due to high ammonia and peroxide concentrations. Nitrification of ammonia also was observed to occur due to chemical oxidation by peroxide.