bluuebunny/crossref_metadata_2025_split huggingface dataset:
Core Data Preprocessing To Improve Permeability Log Estimation
Authors: Cozzi M. , Ruvo L. , Scaglioni P. , Lyne A. M. 
Published: December 2007

Abstract
Two techniques of preprocessing data from core plugs have been investigated to enhance the quality of synthetic permeability estimation from conventional logs using Artificial Neural Networks (ANNs). A first technique consists of ‘cleaning’ the core plug data set by removing the measurements deemed as log-incompatible, i.e. those from plugs corresponding to log measurements affected by shoulder-bed effect, and those from layers with thickness below the vertical log resolution. The second technique relies on building high-resolution digital models of cored intervals using a Process-Oriented Modeling (POM) approach: the core model is populated with permeability values from core plugs and then upscaled to a log-equivalent support volume.
Synthetic permeability curves estimated with the above techniques have been compared to synthetic permeability curves estimated without core-data preprocessing and to permeability estimated directly from core plugs and properly calibrated permeability curves from a Nuclear Magnetic Resonance log tool in a turbidite reservoir, the ground truth value being represented by actual dynamic data. Results highlight that core-to-log scale-effects play a major role in the permeability estimation from conventional logs and show that the proposed preprocessing techniques can be very effective in improving permeability prediction, as they significantly reduce cross-scaling problems related to the differences in support volumes.
Strengths and weaknesses of the two preprocessing approaches have also been compared. The first technique is faster, but its application can be strongly constrained by statistical and geological representativeness of the selected data set, in the sense that some lithologies could go under-represented so as to question the use of estimation tools like ANNs. Conversely, the POM preprocessing technique is more time-consuming and needs detailed core descriptions, but has the great advantage to supply – starting from core data only – a reliable permeability curve that can be retained valid at the log scale.
Swell Packers: Enabling Openhole Intelligent and Multilateral Well Completions for Enhanced Oil Recovery
Authors: Hembling Drew , Salamy Salam , Qahtami Abdullah , Carter Neale , Jacob Suresh 
Published: December 2007

Abstract
Intelligent and multi laterals wells are evolving as key completion technologies to enhance and maximize hydrocarbon recovery. A pre-requisite for the successful application of multi lateral and intelligent well systems is zonal isolation and compartmentalization of the reservoir. Current Techniques either involve the cementing of the mother-bore and/or the use of complex mechanical systems and packers to isolate individual zones. Both techniques increase the complexity of the operation and result in reduced ID from the additional casing string. In addition with intelligent well systems, a feed through system for the hydraulic, eleictrical or fiber optic cable must be used across the isolation device. This join or break represents another weak link or potential failure point in the system.
An isolation device has been developed which uses a rubber elastomer bonded onto a base pipe. The rubber swells in hydrocarbon and provides an effective seal down hole between the base pipe and the openhole to maintain zonal isolation in even the most complex environments. Any number of packers can be made up in the completion string to provide the zonal isolation required and are run as an integral part of the completion string in a single trip.
The swell packer offers many advantages over conventional techniques, besides it simplicity it is able to conform to irregular wellbores, the system can seal in open hole eliminating the need for a completion liner for zonal isolation. This saves rig time and money in the completions and allows for larger ICV’s to be run. In addition, the use of a unique feed through system allows control lines and fiber optic cables to be run through the packer without a connection or splice at the packer. This paper will describe recent case histories and planned operations in Saudi Aramco where the swell packer has enabled intelligent completions, multi lateral, and reservoir compartmentalization for equalizer completions and simplified the process of cable feed through on intelligent completions.
Application of a Maximum Reservoir Contact (MRC) Well in a Thin, Carbonate Reservoir in Kuwait
Authors: Kabir M. , Ingham S. , Sibley D. , Osman K. , Ambastha A. K. , Anderson M. , Rahman B. 
Published: December 2007

Abstract
Mauddud reservoir in the Greater Burgan field is a thin, carbonate reservoir containing light oil in a 10-20 ft target zone with "good" porosity. Matrix permeability is low and natural fracture density can be quite variable in this reservoir. Thus, this reservoir must be exploited using horizontal wells in all areas. In areas where fractures may not be dominant, it is crucial to achieve maximum reservoir contact (MRC) through the well architecture. To this end, a tri-lateral MRC well with a mother bore and two laterals has been recently drilled in this reservoir achieving about 5,000 ft of reservoir contact. This paper details the process followed to achieve this milestone for the first time in Kuwait.
A multi-disciplinary team consisting of Geology, Petrophysics, Geophysics, Drilling, and Service Company was instrumental in utilizing state-of-the-art 3D seismic interpretation, LWD resistivity at bit, real-time imaging, and distance to boundary measurements to place this first MRC well for the Kuwait Oil Company (KOC) entirely within the thin target zone. Real-time decision-making was possible due to seamless integration of all data and interpretation from various disciplines. Internet-based platform was extensively used in this project. Local formation dip changes were computed and well trajectory revised in real time due to such integration.
The process used in this project to place a complex well entirely in a thin target would be applicable to all thin reservoirs that must be exploited through horizontal wells.
Technical contributions discussed in this paper include effective utilization of LWD data to make real-time geo-steering decisions in a thin target, process for real-time calculation of distance to the top (or bottom) and dip changes based on LWD data, and effectiveness of Internet-based platform for communication and decision-making process.
Improving the Value-Risk Management on Revitalizing Mature Oil Fields in One Company's Operating Area
Authors: Aprilian S. S. , Kurnely K. 
Published: December 2007

Abstract
PERTAMINA's mature oil and gas fields in Indonesia have a typical problem related to the following conditions, e.g.: limited data quantity and quality, depleted reservoir with a high watercut, sand/scale problems, small fields in different area (scattered), and mostly having an old infrastructure. However, PERTAMINA has strengths on experienced engineers (local knowledge), high asset value (reserves, operation area, production facilities, and existing infrastructure), committed gas markets, mostly onshore fields, and the fields still under primary recovery. Moreover, there are some unexplored "upside potentials" (deep zones, shallow prospects, adjacent area) surrounding the existing fields.
This paper introduces and discusses the efforts of Management of PERTAMINA Indonesia on managing the values and the risks of the mature fields through a spirit of maximizing their economic recovery. It covers all the potentials by valuation of the assets and making their portfolio investment, applying a new selected technology and approach for focused area, creating a new interpretation for old available data, and optimizing the method of existing production.
Assessing the assets (from reserves to surface infrastructures and company strengths) becomes a primary and critical step before prioritizing and focusing the objective area. Then a reserves evaluation is the further step that maps a new business opportunity. One of the conclusions of reserves evaluation is that the unrecoverable reserves of PERTAMINA's mature fields are still huge and possibly recovered by enhanced oil recovery methods.
By taking the experiences on rejuvenating the South Sumatra, East Java, and Kalimantan mature fields, and the partnership of TAC, JOB, and BOB in managing the mature fields, management of PERTAMINA has self-assurance on further development of their mature fields spread on the eleven operation areas in Indonesia. PERTAMINA puts a great hope on creating the values of their mature fields in the near future
Experience With Rotary Steerable System for Reservoir Drilling in Iranian Offshore Oilfields
Authors: Molayee A. , Teymoori A. 
Published: December 2007

Abstract
The majority of the wells which have been drilled in Iranian oilfields in Persian golf include a horizontal section through the reservoir and the most of them have been drilled by the conventional steerable mud notor assemblies.
Steerable motor drilling is a relatively inefficient process with associated problems, ranging from trajectory control in unstable shales, pipe sticking in lost circulation zones and slide drilling in carbonate reservoirs.
In order to minimize the effect of these issues, rotary steerable system has been deployed in a number of wells for reservoir lateral drilling over the past year.
This paper looks at a range of specific applications where the change from steerable motor to rotary steerable system has been both technically and commercially successful in offshore Iranian oilfields. Through the case histories, this paper will demonstrate both tangible and intangible benefits resulting from the use of rotary steerable systems that have led to a step change in overall drilling performance.
Development and Field Use of a Novel Solvent-Water Emulsion for the Removal of Asphaltene Deposits in Fractured Carbonate Formations
Authors: Lightford S. , Pitoni E. , Armesi F. , Mauri L. 
Published: December 2007

Abstract
The formation of asphaltene scale inside the tubing or in the reservoir is a common problem associated with crude oils in many parts of Italy and common to the industry as whole. In Italy regular treatments using coiled tubing or washing by bullheading are performed to re-establish production. While asphaltene inhibitors can be injected into the tubing string, asphaltenes can still create problems below the injection point and plug the perforations, formation pores, and/or natural fracture network systems.
There is a wide range of hydrocarbon-based solvents that have been used in the industry to remove asphaltenes. The more effective solvents have a low flash-point temperature, making them expensive and hazardous. In addition these hydrocarbon-based solvents leave the formation in an oil-wet state after asphaltene removal instead of re-establishing the water-wet condition that acts as barrier to slow down the deposition of the asphaltene on the formation. This effect accelerates the re-disposition of the asphaltene in the formation and increases the speed of the production decline, increasing the frequency of remedial treatments.
This paper describes the laboratory development and field application of a water/aromatic solvent emulsion system that has been successfully used to clean/dissolve asphaltene and leave the carbonate fractured formation in a water-wet state to delay the production decline. Other advantages when using this type of emulsion are cost reduction and improved effectiveness in removing asphaltene deposits, when compared to alternative solvents that have been employed. This is of particular significance to these wells where large volumes of a washing phase have to be pumped downhole. Hazards have also been reduced by using relatively high flash-point aromatics. Continuous mixing of the emulsion when pumping reduces waste and improves the logistics involved in pumping the large volumes needed to treat long, openhole sections and/or to treat the fractures deeper in the near-wellbore region.
Two successful field applications in south Italy will be discussed in detail, describing the placement technique employed and the results achieved with this new system. These treatments will be compared to previous treatments using a hydrocarbon-based solvent. In the first well, where previous treatments had failed to make significant improvements, following the application of this emulsion the production was practically fully restored and the production decline was significantly slower than previous treatments. The second well treated was a long, horizontal wellbore; again the emulsion and technique proved successful in returning the production to previous levels and sustaining the new level for an extended period of time.
A Case Study for Comparison of Different Real Option Approaches in Petroleum Investments
Authors: Yao Y. H. , Begg S. , van der Hoek J. , Behrenbruch P. , Bratvold R. B. 
Published: December 2007

Abstract
Many oil companies struggle with how to value investment decisions that carry a large amount of risk due to uncertainty. There are two key questions. How should value be adjusted to account for risk? And, what is the value of flexibility (or options) in managing uncertainty?
Traditional project valuation techniques and metrics (Net Present Value based on Cash Flows that are discounted at the WACC, which is sometimes inflated for "risk") are incapable of answering these questions to the degree of accuracy required for many investment decisions.
Real Options Valuation (ROV) is the extension and application to real assets of option-pricing tools that were developed to answer the same two questions in the finance sector. However, due to the differences between real and financial assets, the evolution of this "extension and application" has resulted in a number of variations of approach. These variations are the subject of considerable debate within the petroleum industry. In this paper we describe four approaches, and compare their results using a case study that is dominated by price uncertainty.
Remote Sensing, Fuzzy Logic and GIS in Petroleum Exploration
Authors: Taheri S. R. 
Published: December 2007

Abstract
Despite the known practical applications of remote sensing in a wide range of industries and situations, it has not been used extensively in petroleum exploration, which has relied mostly on geological and / or geophysical surveys. With the advances made in sensing equipment since the Advanced Spaceborne Thermal Emission and Reflection Radiometer (ASTER) became operational, extraction of potential indicators such as: surface emissivity, surface kinetic temperature, brightness temperature and surface radiance needs to be re-evaluated in the context of petroleum exploration. This research will mainly investigate the application of remote sensing techniques to existing petroleum reservoirs with the objective of uncovering diagnostic patterns that could ultimately be used for evaluating virgin territory. Although oil and gas reservoirs are deep below the surface, they have some indicators, which can be detected on the ground. Hazy patches on Landsat MSS images were considered by Collins (1973) as a clue to explore for oil due to their high correlation with existing oil and gas fields, but since the phenomenon was never explained it fell out of favor[1]. This research will try to identify more of these surface phenomena (e.g. surface temperature (TIR) derived from satellite data, vegetation cover, alteration zones, geochemical surface characteristics and any other available surface data) and study their correlation with the presence of oil and gas regardless of whether they can be explained or not. By employing GIS and fuzzy logic a dynamic model will be developed which can be applied to any new petroleum exploration target using the variable input data from that particular exploration target. The selected study area consists of almost 50 existing petroleum oil fields onshore Iran. Following fieldwork in the project area, various valuable layers of information were collected. 20 ASTER scenes over the study area have been received from NASA and data have been retrieved from these satellite images. These data was finally integrated with all the other available data layers to produce the dynamic model. The study is highly significant due to its capability of minimizing exploration costs when remote sensing is combined with other current conventional exploration techniques during the reconnaissance stage. During the course of research quite a good correlation has been observed so far between the analysis results and the presence of oil as a positive indication of the applicability of the proposed model for hydrocarbon exploration.
Recapturing the Value of Fractional Flow Analysis in a Modern Day Water Flood
Authors: Millán H. , Parker A. 
Published: December 2007

Abstract
The Champion Field is located 40 km offshore Brunei, Northern Borneo, in a water depth of 10 – 45 m. It has been on production since 1972 and secondary recovery by treated seawater injection commenced in some reservoirs in 1984.
In this paper we present an analytical approach for estimating relative permeability end-points from production/injection data as a starting point for sensitivity studies on the applicability and value of expanding water flooding to the rest of the Champion field.
A significant volume of special core analysis data is available, however, the representativeness of this data is limited due to differences between reservoir and laboratory conditions. The cores might also have changed properties such as wettability, depending upon coring method, cleaning etc.
In order to screen the value of expanded water flooding a performance review of the Champion water flood reservoirs was carried out using reservoir engineering analytical techniques to generate reservoir fractional flow. The field's performance to fractional flow was matched using a set of Water-Oil relative permeability curves generated by Corey exponents and Buckley-Leverett / Welge theory. This match leading to an estimation of the likely uncertainty range in end point relative permeabilites of Water-Oil curves, mobility ratio and to calculate the expected production profile and ultimate oil recovery. Combined with the available SCAL data and a good understanding of past flood performance an ability to forecast future production was obtained. The work presented forms the first phase in the assessment of the value in expanding water flooding throughout the Field.
In essence the work recaptures the value of analytical methods within the workflow of present-day project developments.
The First Horizontal Underbalanced Well Drilled in Libya: A Case Study
Authors: Safar Husein A. , Majdoub Abdul-Hamid A. , Azhary Sadek A. , Qutob Hani , Chopty James , Obeidat Hassan 
Published: December 2007

Abstract
The National Oil Corporation (NOC) of Libya is considering adapting new technologies to ensure that strategic resources are optimally explored, developed and produced during the life cycle of their oil and gas fields. Among the various options available to achieve these objectives, Underbalanced Drilling (UBD) technology is considered one of the most effective methods.
Zueitina Oil Company, one of Libya's NOC affiliated companies, decided to pioneer the introduction of a new way of drilling horizontal wells in the depleted Sabah Field. Accordingly, UBD technology was utilized to drill the Zueitina Sabah G-55 well in the main Sabah field.
The main objective was to drill the horizontal reservoir section to TD @ 7628 ft MD eliminating/minimizing lost circulation such that no drilling time would be lost due to the need to cure losses or to mitigate other conventional overbalanced drilling problems.
The Sabah G55 well was the first underbalanced horizontal well to be drilled in Libya. The targeted formation is a mature reservoir that has been substantially depleted to a current estimated pressure of 1050 psi. The producing formation consists of two main reservoir zones; Zone I and Zone II, separated by a low porosity tight zone layer. Zone I is made up of dolomite and Zone II of limestone with good porosity development often up to 35%. Abundant fracturing is evidenced by mud losses while drilling, FMI, dip-meter, core description, pressure transient analysis, production performance and others.
This paper discusses the objectives, the planning, the drilling technology used, the performance of the horizontal UBD well compared to offset conventionally drilled wells, problems encountered and lessons learned during the first application of Underbalanced Drilling in Zueitina Oil Company, Libya.
A New Real-Time Monitoring Method for Sandstone Reservoirs' Acidizing
Authors: Zou Jianbo , Li Min , Zhao Liqiang , Wang Qiang 
Published: December 2007

Abstract
Real-Time monitoring of the acidizing process has been shown to be an effective method to improve matrix acidizing treatment and acid volume should be used, and to evaluate the effect of acidizing. As is well known, the basic principle of Real-Time monitoring is monitoring the change of skin factor. However, conventional Real-Time monitoring technique is based upon the measurement of the injection rate and pressure(either surface or bottomhole) during an acid treatment to estimate the change of the skin factor and evaluate the effect of acidizing. While, based on existing techniques, this paper presents a new Real-Time monitoring method which can obtain the change of skin factor by calculating the evolution of permeability and the acid effective penetration diatance during acidizing treatment. The paper also chooses an appropriate Mathematical Model fitting sandstone reservoirs, and then illustrates how to calculate the change of permeability, the acid effective penetration distance and the skin factor. Additionally, this paper develops corresponding program and performs an actual calculation. Results from this calculation agree well with the real case and demonstrate that this method is also an effective Real-Time monitoring technique. Conclusions drawed from this paper suggest this new technique is feasible.
Changes in Completion Strategy Unlocks Massive Jurassic Coalbed Methane Resource Base in the Surat Basin, Australia
Authors: Johnson R. L. , Scott S. , Herrington M. 
Published: December 2007

abstract
Since the late 1990's, operators have drilled a number of coalbed methane (CBM) core and exploration wells to definethe gas resource potential of the vast and relatively unexplored Jurassic Walloon Subgroup (SG) in the Surat Basin. Unfortunately, early pilots used completion techniques that failed to fully assess the true potential of this reservoir. Firstly, openhole completions were trialed but had limited success because of fines influx and well collapse. Next, cased and cemented wellbores incorporating hydraulic fracturing stimulation treatments were attempted to improve wellbore stability, reduce fines influx and increase gas production; these wells were ineffective and many experienced problematic casing failures. Finally, an isolated, openhole, under-reamed completion technique was trialed and achieved commercial flow rates representative of the drill-stem testing data indicated from earlier exploratory drilling.
This paper describes the process, experiences and results leading to the present completion strategy. We note production, permeability and skin factors associated with early completions, as well as results obtained from large-scale implementation of this more effective completion method. As a result of this change, the resource potential of the Walloon SG has grown significantly and the operator has proven 3,712 Bcf of reserves from a previously undeveloped resource area.