bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pattern Of Chemical Changes In Fugitive Hydrocarbon Fuels In The Environment
Authors: Kaplan I.R. , Alimi M.H. , Galperin Y. , Lee L.P. , Lu S.T. 
Published: December 2007

I.R. Kaplan, M.H. Alimi, Y. Galperin, L.P. Lee and S.T. Lu

Abstract
This presentation describes a set of chemical tests which have been developed to characterize hydrocarbon fuels released into the environment. The methods examine various homologous series of hydrocarbons including straight chain (paraffins or n-alkanes), branched chain (isoparaffins or isoprenoids), cyclic (naphthenes or alkylated cyclohexanes), polycyclic (steranes and terpanes) and aromatic structures (BTEX, alkylated benzenes, PAH and alkylated PAH compounds and aromatic steranes). Each one of these groups of hydrocarbons has a different tolerance to alteration (evaporation, water washing and biodegradation). When used as an analytical system on environmental samples, the data obtained provide information on fuel type recognition patterns and on degradation levels of the various fuels.

Introduction
It has been well established. with a large literature citation extending back over forty years. that crude oil in the environment is altered by a series of processes leading to tar balls and asphaltenic residues.
These processes involve evaporation. water solution or water washing and biodegradation of various components. As a general rule, the low molecular weight hydrocarbons with the highest vapor pressure will escape from the crude oil rapidly. Next. in the presence of either standing water (ocean, lakes, rivers or aquifers) or rain, the soluble components begin to be removed. Benzene is the most soluble hydrocarbon (1750 ppm) followed by toluene (550 ppm) and other aromatic hydrocarbons. The light hydrocarbon gases such as methane and ethane are also among the most soluble hydrocarbons.
Following the selective removal of the most volatile and most soluble components of a crude oil, the residual components can remain in a sterile environment for an indeterminate period of time. Crude oil has been produced from early Paleozoic reservoirs. more than 500 million years old and Precambrian source rocks approaching one billion years in age. such as the Weiyuan in the Sichuan Basin in China and sediments in McArthur River Area. Northern Territory, Australia. The two controlling parameters that regulate the decomposition rate of the hydrocarbons in crude oil are (1) temperature and (2) the presence or absence of oxygen.
Although thermophilic bacteria that grow at temperatures between 90 - 100 C have been known for a long time, recent work by Stetter and his colleagues has shown that it is possible to grow bacteria at temperatures above 110 C at elevated pressures. Empirical observations, however. indicate that whereas in shallow crude oil reservoirs containing water. biodegradation of hydrocarbons occur, those more deeply buried with temperatures exceeding 82 C (the Pasteurization temperature) do not show evidence of significant biodegradation.
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Enhancing Area of Review Capabilities: Implementing a Variance Program
Authors: Leon Fernando De 
Published: December 2007

Abstract
The Railroad Commission of Texas (RRC) has regulated oil-field injection well operations since issuing its first injection permit in 1938. The Environmental Protection Agency (EPA) granted the RRC primary enforcement responsibility for the Class II Underground Injection Control (UIC) Program in April 1982. At that time, the added level of groundwater protection afforded by an Area of Review (AOR) on previously permitted Class II wells was not deemed necessary or cost effective.
A proposed EPA rule change will require AORs to be performed on all pre-primacy Class Π wells unless a variance can be justified. A variance methodology has been developed by researchers at the University of Missouri-Rolla in conjunction with the American Petroleum Institute (API). This paper will outline the RRC approach to implementing the AOR variance methodology.
The RRC's UIC program tracks 49,256 pre-primacy wells. Approximately 25,598 of these wells have active permits and will be subject to the proposed AOR requirements. The potential workload of performing AORs or granting variances for this many wells makes the development of a Geographic Information System (GIS) imperative. The RRC has recently completed a digitized map of the entire state and has spotted 890,000 of an estimated 1.2 million wells. Integrating this digital state map into a GIS will allow the RRC to tie its many data systems together.
Once in place, this integrated data system will be used to evaluate AOR variances for pre-primacy wells on a field-wide basis. It will also reduce the regulatory cost of permitting by allowing the RRC staff to perform AORs or grant variances for the approximately 3,000 new and amended permit applications requiring AORs each year.
Soil Remediation by Surface Heating and Vacuum Extraction
Authors: Stegemeier G. L. , Vinegar H. J. 
Published: December 2007

Abstract
A novel in-situ, thermal-vacuum method has been developed to remove contaminants from near-surface soils and pavements. Heat is supplied to the soil by downward conduction from a surface heater. Vaporized products are collected under an impermeable sheet into a vacuum system for further treatment or disposal.
Capillary Force Barriers in a Carbonate Reservoir Under Waterflooding
Authors: Namba T. , Hiraoka T. 
Published: December 2007

ABSTRACT
This paper shows that the horizons with finite vertical permeability can act as barriers for the injected water and prevent water slumping due to the effect of capillary force in a carbonate reservoir. The proposed concept ‘capillary force barriers’ can explain the various monitoring results consistently including the data obtained from pulsed neutron logs and dynamic testing tools.
The Role of Technology and Decision Analysis in Reservoir Management
Authors: Thakur G. C. 
Published: December 2007

Summary
The need to enhance recovery from the vast amount of remaining oil- and gas-in-place requires better reservoir management practices. Proper timing has a profound effect on the implementation of sound reservoir management technology on recovery efficiency. With this in mind, our goal should be to maximize volumetric sweep early in the project’s life. Trying to squeeze more oil from marginal projects will generally yield marginal to average results. The purpose of this paper is to identify the major attributes of a successful reservoir management organization and program and outline critical reservoir management issues and technical areas, and document benefits received from a team approach to reservoir management. In addition, the decision analysis technique is used to look at value creation as a result of reservoir management activities.
Any development of new reservoir management technology and its applications must be subjected to thorough economic screening so that use and support of such technology is justified based upon business needs.
A Rigorous Simulation Study of Water Coning and Edge Water Encroachment Using A Sector Model
Authors: Bu-Hulaigah E. H. , Rabbani G. , Lin C. , Al-Khowaiter A. O. 
Published: December 2007

ABSTRACT
A simulation study was conducted in a shaly sandstone reservoir to study field observed coning behavior of a single well and recommend an optimum production rate for its sustained operation. The simulation model covers a 13 km by 5 km area to enable simultaneous simulation of individual well coning and regional edge water encroachment.
The effect of areal grid size on matching the observed coning behavior was investigated using Local Refined Grid(LRG). A 20-meter LRG model was chosen to perform various prediction cases to determine the optimum production rate for the coning well. The model was also used to investigate development options to accelerate the recovery of downdip oil, where a 50 feet shallower oil-water contact is observed.
This study shows the utility of sector models to study individual well coning behavior and optimize production rate restrictions due to coning, where the regional oil-water contact is dynamic. Conventional single well radial models are considered inappropriate in such cases.
Development of a Network and Gas Lift Allocation Model for Production Optimization in the Ras Budran Field
Authors: El-Massry Y. A. -W. , Price A. D. 
Published: December 2007

Abstract
The Ras Budran Field lies on the east side of the Gulf of Suez 5 KM offshore. The field commenced production in Jan 1983 and gas lift was implemented in 1985. The production system consists of 3 well-head platforms delivering production to a central process platform via 12" pipelines. The produced fluids are subjected to a firststage gas Ioil separation before being pumped onshore. All 15 wells are gas lifted with limited potential for natural flow. The high pressure gas lift supply is limited by compressor capacity and field production optimization is achieved by proper gas lift allocation between wells.
The paper describes the construction and use of a network and gas lift allocation model simulating the combined performance of the reservoir, production wells, flowlines and gas lift system. A network model analysis is performed by calculating the overall system pressure losses by iterating for pressures and flow rates at all production nodes having specified two points at the reservoir and separator. The integrated production network is treated as a single interactive model through the application of multiphase flow correlation(s) which best describe the performance of each component within the system in a step by step approach which is simple to follow and applicable to other fields. The constructed model predicts individual wells performance from the perforations to the firststage gas foil separation at the process platform, taking into account the interaction of the other wells in predicting pressure and flow rate responses. The gas lift allocation model has been used for routine production optimization and allocation of lift gas in a multi well networked model, as well as for prediction of future systern requirements and identification of debottle-necking opportunities.
Seismic Inversion for Reservoir Delineation and Description
Authors: Maver Kim Gunn , Rasmussen Klaus Bolding 
Published: December 2007

ABSTRACT
Seismic inversion can be used to derive acoustic impedance information from seismic data. The seismic inversion methods globally optimised nonlinear seismic inversion and fully linear seismic inversion are introduced to describe a porous Zechstein carbonate interval in Denmark as a correlation exists between the acoustic impedance and porosity.
The globally optimised non-linear seismic inversion method enables a detailed delineation of a potentially porous carbonate interval due to interfaces that are derived as part of the inversion. The inversion is guided by the acoustic impedance log and uses a wavelet calculated at the well location. As the inversion does not use a prior model the result is not biased by the interpreter.
The fully linear seismic inversion method enables an evaluation of the possible variation in acoustic impedance that can be derived from the seismic data. The inversion method utilizes a prior model defined by extrapolating the low frequency trend from the acoustic impedance log along interpreted horizons. Based on this model the best fitting mean acoustic impedance section resolved in the seismic section is found. Additionally the upper and lower confidence limits of acoustic impedance, which can be derived from the seismic section, are defined.
Sequence Stratigraphy of the Hith / Upper Arab Formations Offshore Abu Dhabi, U.A.E.
Authors: Azer Samir R. , Peebles Ross G. 
Published: December 2007

ABSTRACT
The Kimmeridgian Upper Arab zones A, B, and C, are prolific hydrocarbon bearing reservoirs in central and western Offshore Abu Dhabi, (OAD). They were deposited in an arid climate which dominated the Arabian peninsula during Late Jurassic times. The Berriasian to Tithonian Hith Formation which overlies the Arab reservoirs constitutes the cap rock, which just to the east of central OAD gradually pinches out and forms a N-S feather edge.
The Hith and Upper Arab zones A,B, and C form 450 to over 600 feet of massive to interbedded anhydrites with varying proportions of limestones and dolomites in central and western OAD. The Arab Formation in OAD is a major regressive unit which was deposited on a broad carbonate platform and prograded eastwards into an open marine shelf environment.
The Upper Arab zones A,B, and C consist of small scale shallowing upward cycles of varying thicknesses (6 to 30 feet) which typically consist of shoal grainstones (TST) passing upwards into thin bedded lagoonal burrowed mud/wacke-stones (MFS). These are overlain by coarse bioclastic grainstones capped by algal laminites and culminate into supratidal anhydrites, which pinchout eastwards. In the west, cycles are thicker and consist of intertidal pack/grainstones overlain by anhydrites. The parasequences or meter scale cycles have layercake stacking patterns arranged in transgressive, regressive episodes, and are driven by climatic, synde-positional tectonics and their associated low amplitude sea level fluctuations (eustacy).
Early evaporative and reflux dolomitization of peloidal and oolitic grainstones has greatly enhanced reservoir characteristics. Meteoric leaching associated with relative drops in sea level resulted in aragonite dissolution and reservoir enhancement Early marine cementation and late post-burial diagenesis such as anhydritisation resulted in reservoir deterioration.
The objectives of this paper are to develop a sequence stratigraphic framework, emphasizing cyclicity, fades architecture and diagenesis. Core and well log data geared with various inorganic geochemical analyses from four wells are used to constrain the current uncertainties in age dating and integrate the diagenetic signatures into the patterns of relative sea level change which considerably control the formation of those parasequences. This effort will help in better understanding and possible prediction of porosity in such prospective reservoirs.
Sequence Stratigraphy and Source Rock Potential of the Aptian (Bab Member) in East Onshore Abu Dhabi: A Model Approach to Oil Exploration
Authors: Azzam I. N. , Taher A. K. 
Published: December 2007

ABSTRACT
A new geologic model of the Aptian Bab Member (Shuaiba Fm.) have been built, in East Onshore Abu Dhabi, using sequence stratigraphy and biostratigrapby. The model reveals that the Shuaiba is subdivided into two sequences (Upper and Lower). The first sequence is comprised of transgressive and highstand systems tract that can be distinguished in the Lower Shuaiba of Early Aptian age. The second sequence, the Upper Shuaiba, consists of deeper intrashelf basin sediments comprising a transgressive and highstand systems tract of Late Aptian age.
A practical modeling on the Shuaiba Fm. for identifying and calculating Total Organic Carbon (TOC) content and it’s thermal maturity have been adopted using well logs. The modeling indicated that the upper part of Lower Shuaiba (basinal facies) is a prolific, mature source rock especially in the northern part of the study area. Volumetric calculations for Shuaiba source rock indicated that most of the Upper Thamama oils have been generated and migrated from the mature Shuaiba source.
Monitoring of Two Gas Injection Pilots in an Offshore Abu Dhabi Field
Authors: Stofferis M. , Boibien C. 
Published: December 2007

ABSTRACT
In one of the main producing reservoirs of an offshore Abu Dhabi field oil is produced by means of a strong bottom waterdrive. The reservoir is in its final stage of its primary development and gas injection is planned in the invaded part of the reservoir to boost total recovery.
Before embarking on a full field gas injection development, two pilot gas injectors were drilled in different parts of the reservoir and wet gas is injected below the miscibility pressure. According to a PVT-study, gas injection swells the oil by some 16% at the current reservoir pressure.
This paper summarises the various monitoring techniques, applied to these two pilots and discusses the further implications of some of the measurements. A split-up of the observed oil gains due to changes in oil mobility and flowing bottomhole pressure is also given.
A New Tubing-Conveyed Perforating Method
Authors: Mason Justin , George Flint , Pacheco Eduardo 
Published: December 2007

Abstract
Two new innovations — an automatically released gun hanger, and a modular gun-deployment system — have recently been introduced to the oilfield to better support perforating needs in wells in which the completion configurations differ from the older, traditionally accepted designs.
The first design, an automatically-released gun hanger, was planned originally for monobore completions to allow a zone to be perforated and tested without imposing any downhole restrictions. This gun hanger can be used below a retrievable or permanent packer, a polished bore receptacle, or an electric submersible pump.
A new modular gun system has also been designed to be run in conjunction with the gun hanger. This system allows operators to deploy long gun intervals, a section at a time, into a well The guns are run into the wellbore individually and stacked on a gun hanger until the appropriate length is achieved. Since this method avoids any gun length restrictions that could be caused by a lubricator, it is ideal for rigless completions. In addition, the capability of the system to allow retrieval of any or all of the modules under pressure makes it ideal for use in wells with limited rathole.
The combined technological advantages of these new completion tools increase production capability of the wellbore by allowing 1) maximum tubular ID usage and 2) perforating capabilities that include maximum gun size, optimum shot patterns and density, and maximum underbalance or overbalance. These enhancements are in keeping with the current operational and economic needs in today’s oilfield.
Performance of Hydraulic Fracturing and Matrix Acidizing in Horizontal Wellbores – Offshore Qatar
Authors: Edwards M. G. R. , Pongratz R. 
Published: December 2007

Abstract
Considerable debate in the Middle East has centred upon what was previously felt to be two separate methods of enhancing revenues and daily production; hydraulic fracturing and horizontal drilling. In an effort to maximize return on investment, these two issues have been successfully combined in other areas of the world1.
In order to establish the suitability of this technology in this area, two horizontal wells with over 3,050m (10,000ft) of lateral section were drilled into the Cretaceous Kharaib formation, overlying the North Field, Offshore Qatar.
A massive stimulation program was performed in order to evaluate the most feasible stimulation method from both a technical and economical perspective for further field development considerations.
Three propped hydraulic fracturing treatments were performed using 183,500kg (403,7001b) of 20/40 mesh sand, and seventeen acid matrix treatments placing over 3,217,250/ (850,000gals) of HCL into the lateral sections of both wells.
This paper describes the performance, operation and logistical support required to complete this offshore operation within a minimal time frame. The use of a mobile offshore jack-up platform, whereby a land based fracturing spread was placed onto the deck of a converted drilling rig is described.
Applications of the Array Induction Tool in Saudi Arabia
Authors: Zainalabedin K. A. , Minh C. Cao 
Published: December 2007

Abstract
Since its introduction in Saudi Arabia in 1993, the Array Induction Tool (AIT*) has been run extensively in a wide variety of petrophysical environments. These include fresh mud, salty mud, high and low resistivity formations, hydrocarbon-bearing or water-bearing reservoirs in carbonates and clastics sequences. In some examples, the AIT was also run in conjunction with the Phasor Induction (PI ) or Dual-Laterolog for comparison purpose.
As with any resistivity device, the AIT’s primary product, an accurate Rt measurement, should not be overlooked. However, owing to the AIT’s multiple vertical resolutions and depths of investigation, we found that the tool yields additional information about the reservoirs that is not possible with older induction tools.
The AIT improves the estimation of Rt in cases of thin laminations, complex invasion profiles or when the borehole correction is critical (wash-out, salty mud, high resistivity). In many instances, permeable beds that are invaded are much easier to identify with the AIT than with dual depths of investigation induction or laterolog tools. A typical case is the interpretation of annulus. Finally, we show the AIT characteristic response in a thin magnetic marker.
The Universal Modular Platform
Authors: North R. Bruce 
Published: December 2007

Abstract
A new and patented design for offshore wellhead platforms has been developed to meet a ‘fast track’ requirement for increased offshore production, from field locations not yet identified. The new design uses modular construction to allow for radical changes in the water depth of the final location and assembly line efficiency in fabrication. By utilizing high strength steels and structural support from the well conductors the new design accomidates all planned production requirements on a support structure significantly lighter and less expensive than the conventional design it replaces.
Twenty two platforms based on the new design were ready for installation within 18 months of the project start. Installation of the new platforms began in 1992 for drilling support and 1993 for production support. The new design has become the Company standard for all future production platforms. Large savings in construction costs have been realized through its light weight, flexibility in both positioning and water depth, and its modular construction.
Modeling of Downdip Oil Pockets Trapped Behind Flood Front
Authors: Liu J. S. , Al-Abdulkarim A. A. , Barber R. M. , Fontanilla J. 
Published: December 2007

ABSTRACT
The area of interest, located on the downdip flank area of a large carbonate reservoir, is geologically complex. Present at the northwest corner is a structural low which falls below the oil-water contact (OWC). On the southeast corner, the reservoir is known to be communicating with deeper reservoirs. This allowed water to enter the reservoir updip when the reservoir pressure fell prior to the initiation of water injection. Several wells drilled in this area have had significant oil columns in spite of the fact that they were planned as water injectors. The salinity map generated for reservoir management purposes also reveals the complexity of fluid flow in this area. The high total dissolved solids (TDS) content observed for these wells corroborates that the area was nearly stagnant since the production first began in the field. So far, three lagged oil areas have been identified.
A high resolution window model for this area was constructed to define the areal extent of the lagged oil trapped behind the flood front as well as to determine if any other unswept oil exists in the downdip area.
After a satisfactory history match was obtained, the cause of formation of the downdip trapped oil also became apparent and the areal extent of the lagged oil was defined more accurately. The model was thus used to formulate a depletion strategy to recover the lagged oil. A series of prediction cases were run to investigate various issues related to the recovery of the downdip trapped oil and the impact of future reservoir development plans on the lagged area.