bluuebunny/crossref_metadata_2025_split huggingface dataset:
Salinity and Hardness Tolerant Microemulsion Formulations
Authors: Maini Brij B. , Batycky Jim P. 
Published: December 2007

ABSTRACT
The optimization of surfactant formulations has involved varying the salinity of an NaC1 brine for a selected reservoir oil-surfactant-cosurfactant combination. Use of the resulting optimal salinity mixture in a particular reservoir has necessitated the injection of low salinity preflush slugs to precondition and alter the reservoir environment. However, limitations in the level of success than can be expected occur due to the presence of poor sweep efficiencies within an invariably heterogeneous reservoir and the persistence of hardness or multivalent ions which both become magnified in the presence of larger interwell spacings, as is typical in Alberta reservoirs.
A more plausible approach to the design of surfactant slug compositions is one that involves matching reservoir oil-reservoir brine pairs to suitable combinations of surfactants and cosurfactants. An extensive screening of combinations of anionic and nonionic surfactant materials was conducted using two hydrocarbons, n-octane and a mineral oil, and synthetic brines that ranged in salinity from 2% to 20% total dissolved solids. The ratio of Na:Ca:Mg was kept at 20:2:1, since this typifies a large number of reservoir brines.
Phase behavior studies were conducted to establish conditions needed to form middle-phase microemulsions which contained surfactant concentrations in the 5% to 15% range and which did not reveal the formation of insoluble materials at either interface. These phase behavior studies involved the mixing of surfactant mixtures with equal volumes of oil and brine in order to determine the amounts of oil and/or brine solubilized into a surfactant-rich or microemulsion phase.
Promising formulations were composed of combinations of either a single ionic and two non-ionic surfactants or two ionic and one non-ionic surfactant. The principle anionic surfactants that were examined included both synthetic and petroleum sulfonates, but once a compatible cosurfactant pair had been identifed the particular sulfonate chosen became immaterial.
Interfacial tensions measured between adjacent phases, which were in the millidyne region, also proved to be relatively insensitive to salinity scans.
Modeling Natural Gas Reservoirs: David vs. Goliath
Authors: Collier Richard S. , Monash Ellis A. , Hultquist Paul F. 
Published: December 2007

ABSTRACT
For many years it has been standard practice to use very involved grid models to describe the reservoir behavior for the oil and gas industry. These grid models represent sizable investments in both time and money and are used in many instances in a sparing manner so that the cost of getting the needed reservoir information does not become prohibitive. In this paper we present an alternative model for a gas reservoir that is averaged over the geometry of the reservoir and hence represents a "zero-dimensional" model. It is called a "reservoir per se" model and describes the state variables as space averages through time.
"David" is thought of as a small, efficient, low cost and low maintenance model that can be used as a simple alternative to, or prelude to, the use of the larger grid or "Goliath" type models. "Goliath" is pictured as big, bulky, not very efficient, high cost, high maintenance, and needing large amounts of input data.
The particular "David" model — the reservoir per se model — that is presented does a good job in describing the bulk properties of the gas reservoir and has been validated in eighteen distinct cases. This model can and should be used when "simple" reservoir answers are needed quickly and at low computer cost.
Gas-Condensate Flow in Perforated Regions
Authors: Jamiolahmady M. , Danesh A. , Sohrabi M. 
Published: December 2007

Abstract
The most crucial region affecting well productivity is the perforated region. Considerable effort has been directed to study this subject, mathematically by many investigators, but they are mainly focused on single-phase flow with limited information on the two-phase flow systems.
It has been demonstrated, first by this laboratory and subsequently by other researchers, that the gas and condensate relative permeability (kr) can increase significantly by increasing the flow rate, contrary to the common understanding. This effect, known as positive coupling, complicates the flow of gas and condensate near the wellbore even further when it competes with inertial forces at higher velocities typical of those around perforation tips.
The flow of gas and condensate in perforated regions was studied in this work using a finite-element modelling approach. The model allows for changes in fluid properties and accounts for the positive coupling and negative inertial effects using a fractional flow based relative permeability correlation. A sensitivity analysis on the impact of perforation characteristics such as density, phasing, length and radius as well as that of fluid properties, rock characteristics, wellbore radius, fractional flow and rate on well productivity was conducted resulting in some valuable practical guidelines for optimum perforation design.
The results were expressed in terms of the productivity ratio, PR, defined as the ratio of the total flow rate of gas and condensate in the perforated completion to that of an unperforated open-hole for the same pressure drop. The results indicated that PR is independent of fluid properties, fractional flow and rates for most practical purposes.
A TLP Well Design
Authors: Goldsmith Riley G. 
Published: December 2007

ABSTRACT
This paper describes the design, installation, and operation of the drilling, completion and production equipment used with the Conoco TLP well design. This TLP is securely fixed on location which permits "modified conventional platform type" completions with the Christmas trees on the platform. The production and completion systems are discussed to point out the many similarities and explain the few differences from conventional platform systems. Components that are unique to the TLP systems, such as riser tensioners and tieback systems, are described. The TLP deck designs and well arrangements are described. The TLP drilling system, with high pressure drilling riser, platform BOPS and tensioner, is described. A description is also presented of the offtake "sales riser" system.
CO2 Injection for Enhanced Gas Recovery and Geo-Storage: Reservoir Simulation and Economics
Authors: Al-Hashami A. , Ren S. R. , Tohidi B. 
Published: December 2007

Abstract
CO2 can be injected into gas reservoirs for enhanced gas recovery. The main benefit of CO2 injection is pressure support to prevent subsidence and water intrusion. Enhanced gas recovery can be via both displacement and repressurisation of the remaining natural gas. The objective of this paper is to investigate the process of injecting CO2 into gas reservoirs using a compositional reservoir simulator. The effects of gas mixing, CO2 diffusion and CO2 solubility in formation water are investigated. Simulation studies are performed to assess the sensitivity of various design and operating parameters to the process. In general, an incremental gas recovery of 8% can be achieved by CO2 injection for a reservoir with a primary recovery factor of 85% by natural depletion. Economic feasibility of CO2 project is also investigated. The profitability of the project is sensitive to gas price, cost of CO2, original gas composition in the reservoir, and further processing of the produced gas.
Shifting the Gaussian Curve to the Right – A Fully Stochastic Approach to Marginal Offshore Field Development
Authors: Graf T. , Henrion H. , Bellavance R. , Fernandes J. 
Published: December 2007

Abstract
A significant part of any field development planning exercise resides in adequately quantifying reservoir uncertainty, particularly when information availability is limited. For marginal fields, accurate appraisal of the project downside becomes even more crucial, as different development options carry a substantial probability of negative net-present-value and project economic viability relies on reservoir risk minimization.
It then becomes imperative to undertake a complete and detailed risk analysis in order to identify key contributors to reservoir uncertainty, and determine their combined effect and impact on asset economics. A thorough understanding of the risk-setting can lead to better focused resource allocation, data acquisition and identification of management solutions. This will then help mitigating against uncertainty and shift to the right and/or narrow the distribution of recovery and net-present-value. The evaluation and quantification of the impact of key uncertainty factors is exacerbated by the multiplicity of combinations in development options and can only be represented by a very high number of numerical simulations. It is only with today's computing power and recent software developments, in stochastic data analysis and statistical optimization, that it is possible to quickly and exhaustively encompass all relevant uncertainty parameters.
The following case of a marginal offshore field in Angola illustrates the successful application of a stochastic planning approach in defining the optimum field development strategy. A novel workflow in stochastic analysis was applied allowing proper identification and mitigation of all relevant risk factors. This resulted in the determination of optimum surface facilities dimensions, well locations, drilling plans, wellhead structure locations, coring programs and logging suites. This methodology was key in establishing an economically viable option in this high cost, high-risk area.
Geophysical Logging and Exploration Techniques in the Appalachian Coal Fields
Authors: Miller Marshall S. , Moore Mackey 
Published: December 2007

ABSTRACT
The Appalachian Region, although developed heavily in the past 75 years, remains as a tremendous source of future coal reserves. However, with the thicker and more accessible coals now well developed, the coal industry is adjusting rapidly to new exploration techniques for defining new thin coal reserve potentials. Many of these techniques have been derived from the oil and gas exploration industry, while others rely on applications of depositional modeling.
Extremely high resolution electric logging (EHR) is fast becoming an integral part of exploration programming. With very small diameter design and simple construction, the logging tools are providing "in-place" thickness and parting measurements in extraordinary detail. Rock and bone partings within coal seams are now being defined to within less than an inch. Ash quality of the seam is also well defined by these new probes, as well as roof and floor rock competency, and percent reject within the seam. The high resolution electric logging process is also establishing new reserves where previous poor coal recoveries had left conservative impressions.
The more detailed data being generated by electric logs and the increasing knowledge of paleo-depositional environments strongly suggest the need for a revision of present reserve classification systems. This is particularly true for thin (28 to 36 inch) seams, where a loss of a few inches is critical to economical mining. A new reserve system, based on depositional environments, is suggested in this paper.
Early Implementation of A Full-Scale Waterflood in the Abo Reef, Terry Co., Tx – A Case History
Authors: Benton Jerry P. , Maslanka Paul M. , Smith Robert L. 
Published: December 2007

Abstract
The Kingdom Abo Reef Field, located in the northwestern portion of Terry County, Texas is a relatively recent discovery along a linear organic bank trend which is intermittently productive from Eddy County, New Mexico to Hockley County, Texas (Fig. 1). Gulf Oil Corporation operates a major portion of the Kingdom Abo Reef Field, thus enabling Gulf to rapidly apply the technology that is highlighted in this paper.
The first part of this paper deals with the history and initial development of the field with the objective of providing a basis for a waterflood project. The emphasis is placed not on the development of new technology, but rather the application of existing technology in characterizing the reservoir to assist in the early recognition of a low primary recovery factor. An analysis of basic data taken during development and early production operations led to the conclusion that primary operations would result in a low primary recovery, which provides the setting for the waterflood feasibility study. The description of the waterflood feasibility study emphasizes the specific methodology employed to predict the waterflood performance. The physical development of the waterflood is discussed which emphasizes both the infill expansion project and the water-injection systems. The paper concludes with a discussion of the present operations and a review of the flood’s performance.
Interest in Abo carbonate reservoirs began with the discovery of the Lovington Abo Field in Lea County, New Mexico in 1951. Subsequent discoveries were made in the Empire Abo Field in 1957 and Vacuum Abo Field in 1960 along what is today called the Abo Reef Trend. It is along this geologic trend in Terry County, Texas that the Kingdom Abo Reef Field is located.
Mineralogical Analysis and Uranium Distribution of the Sed Imentary-Type Uranium Ores
Authors: Fishman Paul H. , Huang Wen H. 
Published: December 2007

ABSTRACT
Nine cores and approximately 200 samples from a sedimentary-type uranium ore body of the Upper Jackson formation located in Karnes County, Texas were studied to determine the stratigraphy and the mineralogy, in relation to the uranium distribution. The ore body is generally a fine-grained, gray, well-sorted arkosic sandstone enclosed in finer-grained, poorly-sorted lagoonal or paludal mudstone or lignite. The deposi-tional environment of the ore body is presumably a beach-barrier-bar sequence. The bulk mineralogy consists primarily of quartz, and feldspars with minor amounts of biotite, muscovite, augite, clinoptilolite and very minor amounts of hematite, pyrite and cof-finite. The clay analysis reveals a preponderence of smectite with very minor amounts of kaolinite and illite.
High concentrations of uranium are generally associated with a high concentration of clays, zeolites and/or carbonaceous material. Additionally, uranium concentration usually increases with a decrease in size fraction. Thus, the expandable and absorptive smectite and/or the absorptive and ion exchangable zeolites could play a significant role in uranium mineralization.
Natural Gas Price Regulation - Its Problems and Prospects
Authors: May Henry S. , White Carol A. 
Published: December 2007

Abstract
The Natural Gas Policy Act of 1978 (NGPA), is frequently accorded the dubious distinction of being the most complex, ambiguous, and internally inconsistent piece of legislation ever passed by Congress. This paper will take a brief look at the history of natural gas pricing policy, analyze the ways in which the NGPA fits into this historical perspective, discuss the achievements and shortcomings of that statute and speculate about the future of natural gas regulation.
Few would disagree that from a standpoint of economic efficiency and public policy decontrol of at least new natural gas is warranted. The simple fact is that if the price level for natural gas is kept artificially low, there will be less natural gas produced than the demand for it. Despite what is coming to be an increasing perception that deregulation would be generally beneficial, the NGPA fell far short of the ultimate goal of deregulation. In order to understand why political reality has not kept pace with economic reality it would be helpful to briefly consider the history of natural gas regulation.
In 1954 the Supreme Court extended FPC regulation to the wellhead price of natural gas sold for resale in interstate commerce.1/ During the seven years following the Phillips decision there was little indication of a disequilibrium in the supply and demand of natural gas. Indeed, during the 1950's the supply of natural gas continued to increase as it had since World War II and increase dramatically. During this period, natural gas was still largely a by-product of the exploration for and production of oil, so that the relative availability of gas was not dramatically affected by federal price controls. Although economists and the gas industry at times raised dire forewarnings of the longterm adverse effects of price control, the immediate, practical effect did not appear particularly severe.
The Development Decision: Frontier Areas
Authors: Warren Joseph E. 
Published: December 2007

ABSTRACT
Production development in a frontier area subject to adverse environmental conditions-–deep and/or stormy water far from shore or remote arctic regions--will generally require a massive capital investment. The magnitude of this expenditure, per se, will provide sufficient incentive to optimize the design of the production system before making a decision. However, owing to political and economic pressures, the development decision-–to commit to the implementation of a specified design--will usually be required at a time when estimates of reserves, well productivities, prices and costs are quite uncertain. It will be necessary, therefore, to account explicitly for the uncertainty in the decision-making process.
In this paper, a realistic procedure that allows the development decision to be approached in a consistent, rational manner is presented in detail; e.g., Quantification of the uncertainty associated with the Individual parameters--particularly, reserve and well-productivity estimates.Determination of the optimal design parameters for a particular level of reserves based on the specified economic criterion.Specification of the optimal level of reserves to be used to establish the final design which stipulates the capital investment, number of wells and maximum production rate (facility capacity).Evaluation of the expected value of the economic criterion specified for decisionmaking purposes-–and characterization of the uncertainty involved.
To illustrate the use of the suggested procedure, several numerical examples are included-–and, some heuristic simplifications are indicated. The examples are structured to show the significant effect of the tax regime on the development decision.
North Sea Associated Gas Economics: The Reliability of Complex Systems
Authors: Spanning Aller 
Published: December 2007

ABSTRACT
Gas conservation and utilisation are prominent objectives in the development of North Sea oil fields. In fields like Brent, the composition and large volume of associated gas, together with regulatory, commercial and reservoir management considerations have led to the construction of offshore gas handling plant of great complexity.
The reliability characteristics of individual system components form an inadequate basis for predictions of total system behavior. Yet, for several years before the system will be fully commissioned this very behavior represents a vital input to the decision making process: sales contract volumes need to be determined and system vulnerabilities need to be identified.
The paper describes how an integrated Monte Carlo simulator was designed and built to fill the specific requirements of economic evaluation, commercial planning and regulatory compliance.
Setting, layout and operating modes of the four-platform Brent gas handling system are briefly discussed. The paper then outlines model objectives, input data requirements and simulation techniques. Specific features discussed in some detail are the implementation of real-world operating priorities and secondary system limitations in the model. Application examples discussed to illustrate the use of the model include the analysis of sales contract shortfall risk as a function of nomination level and the economics of system modifications.
Waste Water Treatment Facilities and Disposal Well Injection System
Authors: Al-Arfaj Khaled A. , Nomitsu Takeshi 
Published: December 2007

ABSTRACT
In order to eradicate the chances of sea and land pollution, Arabian Oil Company have introduced wastewater treatment facilities and disposal well injection system, where this system will treat different kinds of oily contaminated industrial wastewater and produce a quality of water which can be readily disposed of into a chosen subsurface formation.
With all the difficulties that would have been expected for treating different kinds of incompatible wastewater, the system have been started up and put into service successfully since October 1979.
Seismic Data in Sand Dune Regions: Data Quality in the Rub-al-khali
Authors: Shamlan Abdullah A. , Hibshi Mohammed B. , Lang Douglas G. , Preston Maurice W. J. 
Published: December 2007

ABSTRACT
When seismic lines traverse major sand dunes, data acquired beneath the dunes is often of such poor quality as to render the data unuseable.
Experiments conducted by the Saudi Arabia Ministry of Petroleum and Mineral Resources and Petty-Ray Geophysical resulted in a method of computing static corrections which greatly enhanced the quality of sub-dune data.
Jurassic Arab-C and -D Carbonate Petroleum Reservoirs, Qatif Field, Saudi Arabia
Authors: Wilson Augustus O. 
Published: December 2007

ABSTRACT
The Arab-C and -D reservoirs in the Qatif field are carbonate members of cycles which deposited shallow marine carbonate sediments capped by regressive sabkhah anhydrites. The impermeable capping anhydrites prevented subsequent extensive fresh water influx and thus prevented extensive late diagenetic cementation. As a result, much primary and early diagenetic porosity has been preserved. The Arab-D carbonates are mostly fine grainstones which were deposited in current-swept shelf environments and later extensively dolomitized. The dolomitized grainstones are the best Qatif Arab-D reservoir rock. The Arab-C carbonates consist of a lower transgressive oolite-mollusc grainstone facies (with high primary porosity and high permeability), a middle regressive lime mudstone – algal boundstone facies, (ranging from tight to moderately porous and permeable), and an upper slowly transgressive Clypeina algal and peloid facies (with high primary and moldic porosity and good permeability).
Application of An Air-Drilling Package in Oman
Authors: Cobbett James S. 
Published: December 2007

Abstract
In order to reduce water requirements for drilling on their desert concession area, Petroleum Development Oman (P.D.O.) made a 12-month trial of air-drilling techniques. By using foam as a circulating medium, top-hole sections can now be drilled with only 30 bbl/hour water-supply, where previously 500 bbl/hour were needed to drill with total losses. Cores of friable, fractured formations have also been successfully taken using foam as circulating medium, where previous attempts at coring failed. So successful were the trials, that the initial contract has now been indefinitely extended so as to include an air-drilling package as a permanent part of the drilling fleet.
Stochastic Methods in Reservoir Engineering
Authors: Cekirge H. M. , Kleppe J. , Lehr W. J. 
Published: December 2007

ABSTRACT
The field parameters used for predictions of hydrocarbon reservoir behavior are obtained through field and laboratory experiments. Some of these parameters have a distinct random nature. This random character influences the predictions that are made using the conservation equations. The aim of this paper is to analyse the random nature of the field parameters in the reservoirs. An example is given which investigates the random nature of one of the parameters, permeability or the effective permeability, obtained from the pressure draw-down tests.