bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Improved Reservoir Conduction Heating Model
Authors: Connaughton Charles R. , Crawford Paul B. 
Published: December 2007

Abstract
Steam injection into petroleum reservoirs has become a common method of increasing producing rates and ultimate recovery. In producing rates and ultimate recovery. In addition, hot fluids are being studied for producing shale oil utilizing conduction producing shale oil utilizing conduction heating. This is a study of the temperature distributions resulting from heat conduction.
When steam enters an oil reservoir or shale-oil bed through a single high-permeability channel or fracture, conduction may be a principal heating mechanism. Under certain principal heating mechanism. Under certain assumptions this can be likened to the conduction heating of an infinite body from a disk source. This problem of reservoir or rock heating has been treated by Boberg, Satter, Thomas, Marx-Langenheim and others. Satter and Thomas proposed conduction models for reservoir problems. In reviewing these two models it was problems. In reviewing these two models it was found that both assumed vertical linear heating above and below substantially disk sources. It was suspected that the above models would lead to very optimistic heating as each lacked terms providing for radial or horizontal conduction. providing for radial or horizontal conduction. The radial-horizontal heat conduction terms have now been added, and it was found that the Thomas model forecast an optimistic heated zone. A Thomas isotherm may be 50 percent farther out than the same isotherm in percent farther out than the same isotherm in the new model incorporating radial heat conduction terms. Briefly, the radial term withdraws heat from the region above and below the source, thereby lowering the magnitude of the isotherms. Satter's model is similar to Thomas' model, and it, too, gave optimistic answers by about 25 percent or more.
In the new model, superposition of heating rates was used to evaluate temperature distributions for varying heat rates. Assuming that production can be simulated using negative conduction heating rates, temperature distributions through multiple injection-soak-production cycles were studied.
Using this model, it was found that, after steam injection, the temperature distribution is characterized by nearly horizontal isotherms. For injection periods and rates normally used in petroleum reservoirs, the vertical penetration of the isotherms is much less than penetration of the isotherms is much less than their radial spread for the initial injection period. During soaking, little radial spread period. During soaking, little radial spread of the isotherms occurs, but more vertical penetration occurs. Production of fluids results penetration occurs. Production of fluids results in a removal of heat from above and below the initial heat source. During any production period, a maximum of approximately 36 percent period, a maximum of approximately 36 percent of the injected heat can be removed in practical times. As a result, heat buildup occurs during successive cycles and both radial and vertical spread of the heated zone occurs.
Management Information Systems Software Evaluation
Authors: Al-Tunisi Nabilah , Ghazzawi Amin , Gruyaert Frans , Clarke David 
Published: December 2007

ABSTRACT
In November 1993, Saudi Aramco management endorsed a proposal to coordinate the development of the Management Information Systems (MISs) of four concurrent projects for its facilities Controls Modernization Program. The affected projects were the Ras Tanura Refinery Upgrade Project, The Abqaiq Plant Controls Modernization and the Shedgum and Uthmaniyah Gas plants Controls Upgrade Projects. All of these projects had a significant requirement for MISs in their scope.
Under the leadership of the Process & Control Systems Department, an MIS Coordination Team was formed with representatives of several departments.
An MIS Applications Evaluation procedure was developed based on the Kepner Tregoe Decision Analysis Process and general questionnaires were sent to over a hundred potential Vendors.
The applications were divided into several categories, such as: Data Capture and Historization, Human User
Interface, Trending, Reporting, Graphic Displays, Data Reconciliation, Statistical Analysis, Expert Systems, Maintenance Applications, Document Management and Operations Planning & Scheduling.
For each of the MIS Application areas, detailed follow-up questionnaires were used to short list the candidate products.
In May and June 1994, selected Vendors were invited to Saudi Arabia for an Exhibition which was open to all Saudi Aramco employees. In conjunction with this, the Vendors were subjected to a rigorous product testing exercise by independent teams of testers.
The paper will describe the methods used and the lessons learned in this extensive software evaluation phase, which was a first for Saudi Aramco.
Origin Of NORM in Ras Budran Oil Field
Authors: Abdeen F. , Khalil M. 
Published: December 2007

ABSTRACT
The Ras Budran (R/B) field lies in the Gulf of Suez and consists of a massive Nubian Sandstone which is compartmentalised by partially sealing major faults.
The field is undersaturated and production is maintained by gas-lifted wells with the field under secondary water flooding and limited aquifer drive.
Down-hole scale formation was recognised following the breakthrough of water at the well-bore. Initially diagnosed as calcium carbonate scaling, later observations, following breakthrough of injected seawater, revealed deposits of calcium, barium and strontium sulphates. Plugging or partial plugging of the production strings has provided the most common evidence of scale deposition either in the tubing and/or perforations.
During PLT and TDT logging the plugged intervals exhibit high gamma ray response with the retrieved scales from the tubing showing low Specific Activity (LSA) radioactive material.
Modified scale dissolvers have been applied in the R/3 field to dissolve the scale and keep the Naturally Occurring Radioactive material (NORM) in a highly diluted solution.
An Investigation of the Feasibility of Air Injection into a Waterflooded Light Oil Reservoir
Authors: Sakthikumar S. , Madaoui K. , Chastang J. 
Published: December 2007

Abstract
Insitu combustion or fireflooding has been extensively investigated and field tested in particular for heavy oil reservoirs. Despite many successfull projects of air injection into heavy oil reservoirs and the higher energy efficiency of insitu combustion process, application of the process has not increased due to high capital costs and complicated nature of the process compared with steam injection.
In heavy oil operations air injection has been used primarily as a viscosity reducing agent. In this paper we address the problem of air injection into light oil reservoirs.
Air injection / insitu combustion has been shown to be technically feasible in light oil reservoirs following waterflooding, but wide economic viability under tertiary conditions has not been firmly established. Air is a low cost injectant and unlike in the case of heavy oils the primary factor responsible for improved oil recovery is not just the viscosity reduction. In fact depending on the circumstances air injection into a light reservoir can serve a multiplicity of functions. Air injection at high temperature and pressure (deep reservoirs) could lead to unique economic and technical opportunities for improved oil recovery in many candidate reservoirs under both secondary and tertiary conditions, well beyond the traditional combustion applications.
This paper describes the experimental and numerical work performed and the design of a suitable pilot to assess the feasability of air injection into a waterflooded light oil reservoir. Some of the advantages leading to improved oil recovery and the specific operational problems are discussed.
Water Coning in Fractured Basement Reservoirs
Authors: Saad Saad El-Din M. , Darwich Tarek D. , Asaad Yousri 
Published: December 2007

ABSTRACT
The problem of water coning in fractured basement reservoirs has been addressed in this Work. The outcome of experimental and theoretical investigation to determine the critical production rate for single- and multi-fractured system, the capillary pressure effect, and the break-through time is presented.
The results of the experimental work verify the presented theoretical relationship for different fluid viscosities, fracture angles, oil-Water contacts (OWC), and rates for the case of a single fracture system. The results also indicate that the capillary pressure effect may be generally neglected if the distance between the OWC and the fluid entry is sufficiently large compared to the capillary, rise. The extension of the critical rate determination for a multi-fractured reservoir is also discussed. Finally, the main factors influencing the break-through time were investigated. The difference in viscosity between the oil and water phases has been found to be the main factor affecting the breakthrough time.
Successful Field Evaluation of the Efficiency of a Gas Gravity Drainage Process by Applying Recent Developments in Sponge Coring Technique in a Major Oil Field
Authors: Durandeau Marc , El-Emam Medhat , Anis Abdel-Hamid , Fanti Gianni 
Published: December 2007

ABSTRACT
This paper describes the application and integration of new technologies and recent developments in Sponge coring and presents the methodology used to carry out successfully the various phases of well designed Sponge coring project, including the coring phase, the on-site measurements and the full evaluation of the Sponge core samples. A field case is presented where a Sponge coring project was accomplished to obtain accurate fluids distribution and evaluate the gas gravity drainage efficiency in one of the Arab D sub-reservoirs of a major oil field offshore Abu Dhabi.
A Sponge coring technology team was created to optimize the methodology used during Sponge coring and minimize the uncertainties which persisted on some of the previous operations. The effectiveness of the technique is discussed, with comparison to open hole logs and SCAL data.
Realistic petrophysical parameters were obtained from non-invaded, native-state core samples. The effective oil saturation obtained from the Sponge core analysis results showed that the gravity segregation mechanism has been very active and efficient to recover the oil in the reservoir.
Modelling of Multiple Horizontal Wells in Full Field Models Using Local Grid Refinements
Authors: Mohammed Sabry Abdel-Alim , Al-Ansari Faisal 
Published: December 2007

ABSTRACT
This paper investigates different techniques of modelling horizontal wells in full field simulation models. Two distinctive approaches were followed in this regard: (1) Approximating each horizontal well by a few vertical wells, and (2) Rigorous modelling of the horizontal well by implementing Local Grid Refinement (LGR). These techniques were applied on a full field model of one of Upper Zakum reservoirs to evaluate its new development plan Which optimized number and location of the infill wells with the application of horizontal wells.
Horizontal well completion profiles have been studied to investigate their effect on the sweep efficiency and oil recovery. Pressure drop ih the horizontal wellbore due to friction losses has also been studied. The results of this study were in agreement with actual field performance.
New Fullbore Production Logging Sensor Improves the Evaluation of Production in Deviated and Horizontal Wells
Authors: Kessler Calvin , Frisch Gary 
Published: December 2007

Abstract
A new-generation, production logging toolstring is being introduced with a sensor that can measure fullbore gas holdup. Unlike previous center-sampling holdup sensors (whether radioactive fluid-density or capacitance holdup), this new sensor responds to the entire cross-sectional area of the production tubulars (casing, tubing, or slotted liner) occupied by gas and liquid. From this response, the holdup fractions for liquid and gas (Yl and Yg) can be determined.
The fullbore measurement eliminates previous uncertainties in holdup fractions that can occur when flowing conditions are nonuniform or when water cut is high. This new capability is shown by flow loop comparisons between measurements taken with the fullbore gas-holdup tool and those taken with previous center-sampling holdup sensors in horizontal stratified flowing conditions.
The new production logging toolstring includes a high-speed, bidirectional, monocable digital telemetry system. This system permits simultaneous logging with additional tools such as pulsed neutron tools, oxygen-activation water-flow tools, or other radioactive fluid-velocity tools. The combination of production logging sensors with oxygen activation measurements are important for the evaluation in complex well completions where there are flow paths both inside and outside of the production tublars, such as with slotted liners.
An interactive wellsite production logging analysis package has been developed to utilize the improved data. Both flow-loop-based and conventional slip-velocity interpretation methods are available for determining the flow rates of the individual phases. A new method for determining the downhole flow regime is presented which utilizes both the center-sample holdup and the fullbore holdup measurements.
Water Shutoff Results in High Permeability Zones in Saudi Arabia
Authors: Al-Khawajah M. A. , MacDonald H. W. 
Published: December 2007

Abstract
Wells in one of Saudi Aramco’s oil fields produce under flowing conditions with pressure support provided by a peripheral waterflood. As the waterflood matures, water breakthrough occurs in the lower zones of the oil wells and production rates decline due to increased flowing pressure gradients. This paper details work done by Saudi Aramco to reduce water cycling and increase oil rates in one area of the field. The field results from 49 bottom water shutoff jobs during the last 6 years are presented. The techniques used include workover rig jobs and jobs using coiled tubing and through tubing bridge plug technology. Success in reducing water production and increasing oil rates by the different methods is compared.
Selective Stimulation of Varying Characteristic Carbonate Reservoir Using Acid Activated Gel Diverter
Authors: Mirza A. , Turton S. 
Published: December 2007

Abstract
An off-shore field in Abu-Dhabi has water injectors with dual completions injecting into 3 carbonate subzones A, B and C, separated by dense carbonate layers which act as impermeable barriers. Each completion has one of the two strings completed into two consecutive subzones. The irony is that subzone B is the most permeable and robs the other two of their injection quotas.
This was occurring as the low permeability zones could not be acidized properly due to inefficient diversion. Repeated acidization of the coπimingled zones with benzoic acid diversion had not yielded desired results. In the on going inquest to select a positive diverter, a polymer based system was investigated as a diverting agent.
This paper discusses the use of this polymer based acid activated diverting agent in staged stimulation’s performed in injector wells in an off-shore field, Abu-Dhabi.
The diversion mechanism is explained including how it compares with the other techniques. Polymer properties and characteristics are also explained.
Review of Horizontal Completion Practices Offshore Abu Dhabi
Authors: Hassan M. M. , Abu-Sharkh AF. 
Published: December 2007

Abstract
Horizontal drilling and completion technology has been advanced to the point that oil companies are obtaining a maximum return on their investment due to improvement in the oil recovery as well as maintaining better development plans for their fields.
This paper highlights the different types of well completion, the use of slotted liner completion utilizing 7" cement-off bottom, tapered 7" solid x 4½" slotted and 3½" simple slotted liner. Also, it describes the new advanced completion techniques such as:- –Single overshot completion.–Deviated horizontal dual completion with the elimination of 7" liner.–Dual lateral dual completion.–Selective dual completion with cement inflated formation packers.
Horizontal Completion Options in Reservoirs With Sand Problems
Authors: Restarick Henry 
Published: December 2007

Abstract
Economic efficiency in today’s oil and gas industry requires careful consideration of all horizontal openhole completion criteria during the completion design stage. This paper will review the scenarios that can limit the success of openhole horizontal completions and will focus on problems inherent to sand-producing reservoirs and their management using 1) prepack screens available today and new screen design innovations, 2) recent 90-degree short- and long-radius screen bend tests that determine flexibility characteristics, 3) mechanical fluid-loss control systems, 4) circulation options available to the operator for openhole cleaning 5) and new innovations in zonal isolation with sliding sleeve circulation devices that address sanding problems.
Case histories of several unique completions that proved to be successful in controlling premature water breakthrough and sand problems in fractured reservoirs will be presented, followed by a summary of the important considerations for openhole horizontal completion design.
Determination of Horizontal and Vertical Permeabilities Using Multiprobe Wireline Formation Tester in Layered Formations
Authors: Ayan Cosan , Kuchuk Fikri J. 
Published: December 2007

Abstract
A new interpretation technique is described for determining the horizontal and vertical permeabilities and the porosity-total compressibility product using a multiprobe wireline formation tester. The multiprobe tester (tool) provides the capability to conduct controlled local production and interference tests along an openhole. It also permits flexible configuration. In this paper, we describe a three-probe configuration that consists of a sink, a diametrically opposite horizontal observation probe, and one vertically displaced observation probe. Pressure measurements from two observation probes are used for the estimation of unknown formation parameters. In layered and heterogeneous formations, this configuration allows one to test interlayer communication and to determine individual layer properties. The interpretation technique is applied for the estimation of the layer horizontal and vertical permeabilities and the porosity and total compressibility product for a carbonate formation in an offshore field in Abu Dhabi.
Applications of a New Multi-Resistivity & Imaging Tool in The Middle East.
Authors: Chardac Jean-Louis , El-Sayed Hussein 
Published: December 2007

ABSTRACT
A new measurement-while-drilling (MWD) multi-resistivity tool has been introduced in the Middle East. It measures five resistivities, four of them focused, and a gamma ray.
The four focused resistivities all have the same very high vertical resolution, and different depths of investigation. The deepest measurement uses a ring electrode which measures resistivity all around the borehole, allowing a measurement even when the tool is sliding. The other three focused measurements are made with button electrodes which are azimuthally sensitive.
The true formation resistivity is recorded by the deepest measurement before invasion becomes severe. Button resistivities, thanks to their different depths of investigation, identify zones where invasion starts, and allow invasion diameter computations in favorable conditions.
Images of the formation resistivity at three different depths of investigation are produced. This enables geological features, including dips, fractures and their orientation to be studied. The combination of resistivities with three depths of investigations produces an image of the invasion profile around the borehole.
Effect of Microporosity in Carbonates: Introduction of a Versatile Saturation Equation
Authors: Petricola M. J. C. , Watfa M. 
Published: December 2007

Summary
The giant carbonate reservoirs in the Middle East are free of clays (e.g. Mishrif, Thamama and Arab reservoirs to mention but a few). This blessing for the interpreters is more than counter-balanced by a host of other parameters that make shaly-sand interpretation look like child play.
The pore geometry in carbonates introduces variations in the cementation factor m (porosity exponent) and the saturation exponent n. It is also believed that most of the carbonates exhibit mixed wettabilities, with the micropores, which retain the original formation water, being water wet, and the macropores, which are invaded by the migrating oil in the majority of cases, being oil wet. There are ample log evidence to suggest that in some cases the presence of microporosity dominates the resistivity measurements, giving apparent saturation computations that are inconsistent with the production data(e.g. dry oil production from zones with computed Sw greater than 70%). At the least, a dual porosity model would be needed to describe the system in full. However, in the absence of data to solve for a dual porosity system, the parameters m and n are normally manipulated to obtain saturation values that are closer to the observed test results.
This study simulates the effects of microporosity on the computed values of saturations. A dual porosity system is assumed, with a range of parameters for the two pore systems. The interaction between the macro and micro pore systems was also varied using different mixing laws. The results demonstrate that the presence of micropores can have a large effect on the computed values of saturation. A tool that measures microporosity will be invaluable in carbonates, with such a measurement becoming a standard service like the density-neutron combination.
Intelligent Scraping Experience Using Ultrasonics in Two 60"/56" Dual Diameter 100 km. Seawater Transmission Pipelines in Saudi Arabia.
Authors: Bird A. F. , Chu K. S. 
Published: December 2007

SUMMARY
Saudi ARAMCO’s two 60"/56" (1524/1422 mm.) diameter Seawater Injection Pipelines used for secondary oil recovery stretch from the Seawater Treatment Plant across the Arabian Desert for a distance of approximately 100 kilometers.
Both lines were put into operationin mid 1978 using over the ditch Plicoflex tape wrap as a means of protection against external corrosion. A significant portion of both pipelines (32 km. of each line) runs through Subkha (salty moist) areas. A series of test hole evaluations in 1989 indicated moderate to severe external corrosion particularly in Subkha which necessitated sleeving and external coating application.
In 1991 a series of leaks, four (4) in total over a period of two (2) months occurred in Pipeline #2 due to external corrosion. This suggested that the line(s) were in urgent need of at least partial replacement or major rehabilitation. Prior to making a final decision on partial replacement it was decided to run an Intelligent Scraper in both pipelines to ascertain both internal and external pipeline conditions. An Ultrasonic Scraper the largest of it’s kind in the world, similar to what was used in the Alyeska Pipeline was developed and successfully run in both pipelines in February 1993.
This paper discusses the pipeline history, test hole evaluations, Intelligent Scraping experiences, field evaluation for anomaly verification, and repair of approximately 120 locations as identified by the Intelligent Scraping run. The Intelligent Scraping evaluation played a major role in the cancellation of partial pipeline replacement with cost savings estimated at $30 MM.