bluuebunny/crossref_metadata_2025_split huggingface dataset:
Corrosion Modeling Within an Integrated Corrosion Prediction Approach
Authors: Sun Wei , Geurts Kevin R. , Pugh Dylan , Pacheco Jorge Luis , Monahan Craig C. , Franco Robert J. , Norman David 
Published: March 2015

Abstract
This paper describes an integrated approach, based on corrosion modeling and laboratory testing, to optimize the use of carbon steel in corrosive service for applications such as downhole tubulars, pipelines, and facilities. This approach presents economic advantages, such as reducing the use of expensive corrosion resistant alloys, while ensuring the operational integrity of equipment and facilities. A key part of this integrated approach is to apply reliable corrosion models underpinned with laboratory data. To be most effective, the models should account for the relevant chemistry and physics of the corrosion process, including the effects of detailed water chemistry, liquid hydrocarbons, and the degree of protection from iron carbonate or iron sulfide scales. Ideally, models should account for variations in conditions and flow characteristics along the length of a wellbore or pipeline. Case studies are presented that demonstrate how corrosion modeling in conjunction with laboratory testing may be used to the selection of validate carbon steel for challenging applications.

Introduction
Although high cost corrosion resistance alloys (CRAs) were developed to resist internal corrosion, carbon steel is still the most cost effective material used in oil and gas production. It is very important to develop an integrated corrosion prediction approach for optimizing the use of carbon steel in corrosive service while ensuring the operational integrity of equipment and facilities.
Both corrosion models and laboratory testing are frequently used in this industry to make lifetime predictions of facilities using carbon steel and further to make decisions on materials selection. Corrosion models, including empirical, semi-empirical, and mechanistic ones, have been developed over the past several decades to predict corrosion of carbon steel 1–6. These corrosion models can provide engineers quick and economical corrosion predictions. Most of the models were validated by laboratory data and/or field data. Empirical and semi-empirical models usually provide reasonable predictions inside of their validation range but poor predictions outside of their range. Mechanistic models generally can extrapolate to conditions outside of their validation range and remain accurate to a certain degree. Consequently, one should always understand the validation range and limitations of the models to apply these correctly. Moreover, although part of corrosion mechanisms are well understood in lab investigations, due to the complexity in production operations, it is still challenging to apply lab short-term testing results and corrosion models to predict corrosion of facilities for twenty to thirty years of service. An integrated approach was therefore developed by ExxonMobil1 to apply a reliable corrosion model in conjunction with laboratory testing for predicting corrosion in oil and gas production.
Optimizing Electroosmotic Flow Potential for Electrically Enhanced Oil Recovery (EEORTM) in Carbonate Rock formations of Abu Dhabi Based on Rock Properties and Composition
Authors: Haroun Muhammad Raeef , Chilingar George V. , Pamukcu Sibel , Wittle J.K. , Belhaj Hadi , Al Bloushi Mariam N. 
Published: March 2015

Abstract
Among the leading emerging technologies for in-situ oil recovery is the use of an electrokinetic technology known as electrically enhanced oil recovery (EEORTM)i. Electrokinetic methods are continually tested and improved both in the laboratory and in the field to render them highly feasible for increased oil recovery. The effectiveness of the process to enhance the flow and production of both light and heavy crude oil from sandstone reservoirs have been demonstrated in the laboratory by researchers for the last four decades. Successful but limited field applications, both in-situ and ex-situ have also been reported for the same duration of time. There has been little work done on the applicability of the technology to carbonate rock reservoirs, owing to predicted high energy consumption due to low clay content formations and high salinity environments. Yet, compared to currently incurred high costs of conventional electrical oil recovery which depends on joule heating of the formation, electroosmotic mass transport may offer a feasible option to augment the flow of these large volumes of crude oil both onshore and offshore.
A great additional incentive is that EEORTM can be engineered as a truly green technology, where there is no water consumption, and no air, water, and formation pollution. The technology can be applied with no depth limitation in-situ rendering it even more attractive in remote operating locations as well as the environmentally challenging ones. This paper addresses the first attempt undertaken at the newly-established Electrokinetic Laboratory of the Petroleum Institute in Abu Dhabi, U.A.E. to determine the efficacy of electrokinetic technology in EEORTM tested on field collected data samples of Abu Dhabi. The results of the initial tests conducted on field retrieved specimens of Abu Dhabi on-shore carbonate reservoir rock candidates from several formations in high salinity environments that contained various crude types are reported.
Production Of Heavy Lubricating Oil Base Stocks And Analyses By Using A New Method HPLC
Authors: Aboul-fotouh Tarek Mohamed , El-Shafie Masoud , Mohamed Soad 
Published: March 2015

Abstract
The main objective of the present investigative work is the experimental production of heavy lubricating oil base stocks and the study of the effect of chemical composition on physico-chemical characteristics of the prepared lube oil samples. In the first process, solvent dewaxing, the mixture of methyl ethyl ketone and methyl isobutyl ketone (MEK/MIBK) is used as a recent solvent in the dewaxing process to obtain a significant yield of low pour point products and to compare this mixture with MEK/toluene which is used in the industry process. Solvent dewaxing process is carried out at - 10°C using the mixture of MEK and MIBK (40/60 by wt.) with solvent oil ratio of 3:1 for the selected raffinates, heavy refined oils, from furfural and NMP extraction processes. The dewaxed oil samples were analysed to evaluate their physico-chemical characteristics by the standard methods outlined in ASTM, IP and UOP books such as the standard methods for wax content, pour point, sulfur content and structural group analysis by n-d-M method. The results show that the use of MEK/MIBK mixture instead of MEK/toluene at -10°C achieves an increase in filtration temperature with about 5°C with subsequent a reduction in the cooling rate of process.
In the second process, clay-alumina finishing process as a percolation process, the dewaxed oil samples are treated to reduce the sulfur content and remove the nitrogen, oxygen and other undesirable compounds completely. The local natural clay (fuller's earth) with the particle size of 30–60 mesh and aluminum oxide 90 active neutral (Merck) with the particle size of 70–230 mesh are used as a mixture in this process. The finished lube oil samples are analysed to evaluate their physico-chemical characteristics by the standard methods outlined in ASTM, IP and UOP books. In addition, heavy grades are analysed by the high performance liquid chromatography (HPLC) after the solvent extraction and clay-alumina finishing processes. The chromatograms reveal the reduction in aromatic peaks after clayalumina finishing process and the reduction in saturate humps after the dewaxing process. Finally, the results show that high quality lube oils with good thermal and oxidation stabilities are produced.
An Original Technique to Characterize Naturally Fractured Reservoirs from Pressure Transient Analyses
Authors: Elkewidy Tarek Ibrahim 
Published: March 2015

Abstract
This new technique is introduced to characterize all kinds of naturally fractured (secondary porosity) reservoirs, including carbonates, basements, and clastics on the Megascopic scale of well testing delineation. The technique is based on an original view of pressure transient data (buildup). In fact, this technique bridges between the Macro, Meso, and Megascopic scales of reservoir characterizations.
Conventional well testing analysis techniques, e.g. Horner method, do not often work for naturally fractured reservoirs since they are based on a homogeneous reservoir model. In addition, all available techniques to characterize naturally fractured reservoirs from pressure transient analyses are very much theoretical models based on unrealistic geometrical assumptions. They lack practical applications and produce limited information.
The new technique has the merit of working on real reservoir data. It utilizes pressure buildup data through the fact that formation fluids travel across different systems in heterogeneous naturally fractured reservoirs; matrix, fractures and the damaged area. A unique graphical characterization of shut-in well pressure versus time will illustrate the effect of fluid movements from the matrix system (or the tiny fractured system) through the main fracture system and across the damage area, if any, into the well. Fluid movements through each system are represented graphically. The technique is further optimized through application of pressure derivative methods to yield a very characteristic graphical representation (triangle)of each hydraulic "flow" unit in the reservoir.
The presence of the triangle sides can be used to confirm the existence of a secondary porosity system (fractures) and/or damaged area. The slopes and intersection values of the straight lines are utilized into exclusive formulas to yield the most important petrophysical and engineering parameters about the heterogeneous naturally fractured reservoir (and, in many cases, other kinds of reservoirs) including: effective fractures, matrix and skin systems volumes, partitioning coefficient, fracture intensity index, formation resistivity factor, formation tortuosity, effective drainage radius, damage radius, effective cementation exponent, fracture porosity, matrix porosity, storativity ratio, in addition to fracture permeability, matrix permeability, damaged (skin) permeability, average permeability, pressure drop across the damage area, skin factor, damage permeability, average/dimensionless diffusivity factor, flow efficiency, damage ratio/factor, economic implication of formation damage, average hydraulic "flow" unit quality index. This document and presentation will cover the theory behind the technique and present actual field application examples.
Enhancing the Interpretation of Rift Structures in Sudan Using AVO Analysis and Seismic Inversion
Authors: Mahgoub Mohamed Ibrahim , Padmanabhan Eswaran 
Published: March 2015

Abstract
Uncertainty in structural complexities and rock heterogeneities is a major challenge that controls oil exploration and drilling operations in the rift basins of Sudan.
Wide ranges of depositional environments developed within these reservoirs: e.g., fluvial, shallow and deep lacustrine, fluvio-deltaic systems. Multi-phase rift development from rift initiation to late post-rift introduced good oil traps and very heterogeneous reservoir rocks situations.
Advances in seismic inversion techniques and AVO analysis maximize the probabilities of valid interpretation and lithology delineation in such rift structures thereby reducing the associated uncertainty limit. Accuracy of interpretation depends on the quality of seismic data. Therefore, there is an urgent need to introduce innovative techniques in seismic processing to improve seismic resolution prior to any inversion work.
This paper explains an-integrated workflow using seismic data conditioning and inversion methods applied for detailed interpretation and advanced reservoir characterization applications in these rift basins. The seismic data conditioning and inversion workflow implementation comprises three main steps: beginning with data conditioning (seismic and logs), wavelet estimation, and relative acoustic impedance inversion.
The conditioned seismic and relative acoustic impedance volumes are used to improve horizons and faults. This interpretation can be used further to build a low-frequency models for absolute acoustic impedance inversion and porosity transformation.
Sinphuhorm, Thailand Pipeline Integrity Management Utilizing Advanced Monitoring Techniques
Authors: Cenegy Lawrence Michael , McAfee Clyde Alan , Engchanil Rachan , Thatsana Apisith 
Published: March 2015

Abstract
As a primary energy source, natural gas continues to play a major role in meeting Thailand's energy requirements and is preferred for generating the country's electricity. As energy demand increases, a fully integrated pipeline integrity program for wet gas pipelines becomes necessary to ensure safe production from Thailand's gas fields. This paper presents an overview of the corrosion mitigation and monitoring strategies implemented on a 63.5 km (40 mile) long, 385 mm (15.2 in) maximum internal diameter, carbon steel wet gas pipeline. The pipeline is in Khon Kaen Province, located northeast of central Thailand.
Extensive pre-startup analysis was conducted, such as pipeline dynamic flow modeling and corrosion prediction modeling, from which the final corrosion management strategy was derived. Advanced corrosion measurement tools developed for continuous data collection, such as high-resolution metal loss probes and high-sensitivity ultrasonic wall thickness transducers, are discussed, and performance data included. Key performance indicators for corrosion control, including hydrogen sulfide measurements, iron counts, corrosion inhibitor residuals, and sulfate reducing bacteria, along with pipe wall corrosion measurements and cathodic protection potentials, are also considered in the paper.
Recent in-line inspection data was used to correlate the continuous monitoring data collected over the last several years with the recorded pipeline condition to evaluate the effectiveness of the corrosion management program. The evaluation of the overall success of the management program is discussed, along with lessons learned for future reference.

Introduction
Because Thailand has limited domestic oil reserves of around 183 million barrels, imports make up a large portion of the country's oil requirements. Thailand does, however, have large proven reserves of natural gas (12 trillion cubic feet estimated as of 2007) located both offshore in the Gulf of Thailand and onshore. As a result, natural gas plays a major role in meeting Thailand's energy requirements, both as a primary energy source as well as the preferred fuel for generating the country's electricity.
Although annual gas production has risen over the last few years to 882 billion cubic feet, the increased production has not been sufficient to meet domestic needs, and the country remains a net importer of gas (APEC 2010).
As energy demand increases, the need for a fully integrated pipeline integrity program for wet gas pipelines becomes necessary to ensure safe production from Thailand's gas fields.

The Sinphuhorm Facility—Background
In 2006, an operator in Thailand constructed the Sinphuhorm Gas Processing Plant (GPP) and associated facilities at Orbortor-Kudnam Sai District in northern Thailand, about 90 km south of Udon Thani and 30 km from the city of Khon Kaen, shown in Fig. 1.
Ranking Production Potential Based on Key Geological Drivers - Bakken Case Study
Authors: Pilcher Robin S. , McDonough Ciosek Jessica , McArthur Kelsey , Hohman John C. , Schmitz Peter 
Published: March 2015

Abstract
The Bakken Play is a lithologically complex, mixed carbonate-clastic and low porosity-permeability petroleum system comprised of juxtaposed source rocks and reservoir intervals. The play spans variable source maturity, reservoir pressure and temperature, and fluid type. The target reservoirs are thin (below seismic resolution), gently-dipping and variably affected by subtle structure, faults or natural fractures.
As a continuous oil accumulation with an unconventional development model, numerous horizontal wells with multi-stage completions will be required to develop the Bakken Play. Ranking future drilling locations is a critical step in planning the development strategy and optimizing the economics of the play. Ranking methods are typically based on prior well performance; however, in the Bakken Play we recognize that numerous non-geological parameters associated with drilling, completions, and production operations contribute to well performance. In this paper we describe a methodology to assess the underlying productivity potential of the reservoirs based on key geological drivers.
With an extensive well log database, petrophysical uncertainty can be addressed and stock-tank oil originally in place (STOOIP) calculated and mapped.
Nevertheless, the relationship of STOOIP to production performance remains weak due to drilling, completion, and production variables. In this study we apply geological modifiers to the calculated in-place resource to better represent the productivity potential. Geological modifiers include source maturity and charge access, reservoir facies and properties, structure (trap and natural fractures), overpressure, and fluid properties.
Successful Application Of Ultrasound Technology To Detect Sand Producing Intervals In The Wellbore
Authors: Mohd Daud Farik , Jusoh Hasni , Mohamed Azhan , Then Eii Feng , Batumelai Sathish Kumar 
Published: March 2015

Abstract
Sand production in oil and gas wells not only poses a serious threat to hydrocarbon production, but can also cause extensive damage to equipment, such as subsurface tubing, surface valves and pipelines. Produced sand is also an environmental hazard, and needs to be disposed of in an environmentally safe way. Effective sand management is therefore a major concern in the oil and gas industry.
The key challenge is to optimize hydrocarbon production by minimizing the production of sand and in doing so reduce the damage caused to well completions and surface equipment. On a sand-prone well, this is typically done by identifying a maximum sand free rate (MSFR), and then limiting production to this level. Conventional sand detection methods rely on surface measurements. However, these methods do not provide a complete picture of the sand production down hole. To gain a more comprehensive understanding of the problem, sand needs to be detected at its point of entry into the well bore. In this way, the best remedial treatment can be designed.
To answer this requirement, an ultrasonic sand detection tool has been developed. The tool detects ultrasound energy generated by sand grains as they enter the well bore and strike the tool in a radial manner. Sand moving parallel to the well bore axis is not detected, thus the tool can indicate the exact entry point of sand, anywhere along the producing interval. The operator can then specify the most appropriate and cost effective remedial action, such as installing sand screens or applying chemical treatments. By employing such a tool, the cost of remedial action can be minimized and hydrocarbon rates can be optimized to achieve sand-free production. The tool can also be used to evaluate the performance of sand screens and other control devices, and if run in tandem with production logging tools, can monitor sand production in conjunction with well performance.
This paper presents the results of a case study where a downhole ultrasonic sand detector was used to monitor sand production in five gas-producing wells from the Northern Malay Basin. The methods behind this "sand survey" are presented, along with a description of the tool.

Introduction and Background
Carigali Hess Operating Company Sdn. Bhd. (Carigali Hess) operates the Cakerawala, Bumi, Suriya and Bulan gas fields in Block A-18 of the Malaysia-Thailand Joint Development Area (MTJDA). Figure 1A shows the geographical location of the MTJDA in relation to Malaysia and Thailand, while Figure 1B illustrates the current arrangement of platforms and pipelines operated by Carigali Hess in the block.
Review of Ultrashort-Radius Radial System (URRS)
Authors: Marbun Bonar Tua Halomoan , Zulkhifly Samuel , Arliyando L. , Putra Syatria Kumala 
Published: March 2015

Abstract
The objective for the Ultrashort-radius radial system is to provide an extended wellbore radius by means of multiple radials from a vertical wellbore (i.e., to effect an extended completion or extended pipe perforations). It can be applied both in new and old wells. Its main technique is to use high pressure jet flow energy, given by a special high pressure jet tube, to penetrate and elongate a number of lateral well bores radiated from the main well bore in the same layer or different layer so as to expose the pay zone as much as possible and increases the Enhanced Oil Recovery. The choice of radial length, number of radials, and radial array is a function of the reservoir properties.
The research reported herein discusses the application of the URRS. The specific variables like reservoir thickness, vertical and horizontal permeabilities, oil properties, well spacing, outer-boundary reservoir pressure, gravity drainage, thermal and non-thermal processes and impermeable partings within the reservoir has been studied together with drilling operation parameter like casing design, drilling fluid design, radial drilling equipment, Bottom Hole Assembly to optimize the drilling process and completion of the URRS at field. This paper also briefly describes the next development and its problems that must be economically and feasibility resolved later.

Introduction
The increasing of energy demand, especially in oil and gas term, has driven the invention of new technology and improvement in field developing. Horizontal drilling technology has emerging since a few decades ago. In many brownfields, horizontal drilling is used to increase hydrocarbon production by increase footage of the production zone contacted by the borehole. Horizontal drilling increases the production rate and ultimate reserves recovered. There are several types of horizontal drilling (The detail of horizontal drilling and well classifications can be seen in Tab.1 and Fig.1)1:Long Radius (LRH) = less than 6o/30m.Medium Radius (MRH) = less than 6o/30m - 40o/30m.Short Radius (SRH) = greater than 40o/30m, quite often build rates of 100o/30m.