bluuebunny/crossref_metadata_2025_split huggingface dataset:
Performance Evaluation in Data Rich Fayetteville Shale Gas Plays - Integrating Physics-based Reservoir Simulations with Data Driven Approaches for Uncertainty Reduction
Authors: Xiao Yitian , Van Den Bosch Rainer H. , Liu Faye , Steffen Kurt 
Published: May 2016

Abstract
This joint study combines physics-based reservoir simulations with automated screening including data mining and pattern recognition to evaluate the key controls on shale gas performance in Fayetteville, USA based on publicly available data comprising approximately 2000 wells.
For data screening automated tools were developed to efficiently process large and rapidly growing data volumes. Workflows include probabilistic prediction of Estimated Ultimate Recovery (EUR) from decline curve analysis, diagnostic mapping, and multi-variate cross correlations. Key data utilized were gas production, well location, reservoir depth, well design and completion detail.
Numerical simulations were conducted on 6 selected wells with 2.5 - 3.5 years of production data for history matching, model calibration and sensitivity tests. The models comprise a dual-porosity, dual-permeability approach incorporating multistage hydraulic fractures, Darcy's flow, diffusion and gas adsorption/desorption to predict gas rate and EUR.
Key results include:• Average EUR per well has increased more than 5 fold from 2005 to 2009 suggesting a steep learning curve in identification of sweet spots coupled with improved well drilling and completion techniques.• Top performing wells completed since 2009 have an average completion length of ~4,100 ft and comprise 12–13 stimulation stages. However, longer wells, more completion stages and more proppant volumes do not always lead to higher well performance.• High performance wells are concentrated in two areas, providing evidence for geological control, although the performance (dynamic) sweet spots do not necessarily correlate with the resource density (static) sweet spots.• Despite improved drilling and completion techniques and improved subsurface illumination through 3D seismic and micro seismic, a significant number of completed wells still fall in low tier performance categories.• The reservoir simulation models require either the presence of natural fractures or higher matrix permeability (~several uD) in addition to hydraulic fractures and conventionally measured matrix permeability (~10s - 100s nD) to match production history.• Matrix permeability in the range of 10s to 100s nD appears to have limited impact on gas rate in the presence of natural fractures.• Gas desorption can contribute up to ~30% of gas production; desorption occurs early and increases with time.• Modeling results suggest an effective drainage area and an optimal well spacing of ~ 60 acres with current stimulation practices.• EUR predictions from reservoir simulations and automated decline curve analysis yield consistent results given the uncertainties from limited production data.
Novel Reciprocating Submersible Pumping Technology for Performance Improvements in Oil Production
Authors: Wang Zhigang 
Published: May 2016

Abstract
Submersible pumping technique with linear motor is crucial for oil production in low permeability reservoir, especially in China and South East Asia. However, how to improve the life, reliability and performance of the submersible linear motor and cut energy consumption is still a challenge for oil production engineers. To solve these issues, several novel designs on lubrication, hydraulic buffer, floating suction device and automatic motor driven and control methodologies are proposed.
The impact of these designs on performance improvements, computer work and field test results are analyzed in this paper.
The technology presented is convenient to implement, which can adapt to low production well, directional well and horizontal well to overcome local permeability reduction.
A large scale field application test was carried out and satisfactory results were achieved. The motor life was doubled, maintenance cost was greatly reduced and oil production was significantly increased. The power consumption was 40% less than conventional techniques.
The key contributions of the technology proposed are: First, a new motor driven method applied to directly connect pump plunger with motor mover greatly improves the pumper lifting force and reliability; Second, a full set of lubrication device is designed that involves an automatic pressure regulator, an unique spiral channel and the automatic valve control technology, which improves not only the motor lubrication but also the motor cooling; Third, an advanced hydraulic buffer device located at the lower end of the stator is designed to prevent shock and collision damage to the motor; a floating suction device is designed to prevent the deposition of sand and impurities into the motor and oil; Fourth, an automatic control of start-stop motor technology is developed to allow the motor automatic start-stop on variation of liquid level, preventing the motor no-load and increasing motor life to achieve the energy saving requirements. The structural application of these techniques has proven useful to improve the reliability, service life of the motor and reduce the energy consumption as well as maintenance costs. In addition, these techniques also contribute to partially arresting the declining production trend and more importantly improve oil recovery.
The Evolution of the Drill String Design on Sour Field (Puguang) to Improve Performance and Safety Margins in Sour Environments
Authors: Flores Vincent Pierre , El Bachiri Kamal , Fei Li , LI Yumin , Zhang Da 
Published: May 2016

Abstract
Puguang region is known for containing sour fields with significant amount of H2S. Since 1975, sour service wells have been drilled entailing critical drilling conditions. To optimize drilling efficiency without sacrificing security, drill string improvements have been always looked for, by carefully evaluating steel grades, drill pipe sizes and connections.
The evolution of drilling programs has driven the industry to develop more suitable solutions adapted to extreme and aggressive conditions such as Sour Service environments. High strength drill pipe is often necessary to achieve deeper drilling performance, even when Sulfide Stress Cracking susceptibility is observed in minimal concentrations of H2S in partial pressures. Due to the astringency of the sour environment, particular precautions have to be defined to select and characterize an adapted Sour Service steel grade.
This paper presents the evolution of choices in drill string design from basic API grades and connections to adapt and proprietary steel grades resistant to H2S with a high mechanical performance properties and high torque double shoulder connections.
Beam Pump - Installation without workover Technique
Authors: Nadoon Apiwat , Toempromaraj Wararrit , Sompopsart Suwin , Prayadsup Amnuay , Suwanmisara Adisak 
Published: May 2016

Abstract
In the Sirikit Oil Field (S1), a number of artificial lift techniques (ESP, PCP, GL, Beam Pump etc.) have been implemented to assist the depleted oil producers to flow the well fluid from underground to surface. The type of artificial lift in particular well is considered depended on the well conditions.
The gaslift is the main artificial lift which being typically used in the Sirikit oil field (S1). It is the technique that covers the wide range of well conditions. However in the well which has low reservoir pressure such as below 500–600 psi, the gaslift technique seems to be low efficient and not suitable for this well condition. Therefore the other artificial lifts are considered, and the beam pump is one which is more suitable than the gaslift. Because the most benefit of beam pump can effectively produce the oil when the reservoir pressure is very low such as 100 psi but the gaslift is unable to do.
Generally gaslift and beam pump artificial lifts selection will depend on the well conditions. In areas where the Water flood Project is planning in the future, the well conditions will be changed from the low pressure (depleted reservoir) to high pressure. The waterflood project will require the plenty of time on reservoir simulation, study work and the project implementation. The sub-surface and surface engineering to prepare the surface facilities and well completion for the waterflood project will take few more years and consequently resulted in oil deferments or oil leaving underground.
Since the challenges on well conditions to make a good business in short term winning on quick oil production meanwhile keeping a good on long-term oil recovery from waterflood project. The HYBRID completion of beam pump and gaslift is then invented, since the reservoir pressure response is the key driver for the artificial lift design. The depleted or low reservoir pressure is good for a beam pump technique however once the waterflood project implemented and the reservoir pressure get responded and be higher and higher, then the beam pump technique will idle the oil production and push to the limit by the downhole pump's capacity. The gaslift then will be suitable after the reservoir pressure's response however recompletion the well by the work-over will cost about 150–200 K USD so it would be better if we can provide the HYBRID artificial lift to the well since the beginning.
Enhancement of IFT Reduction in Surfactant Flooding by Branched Alcohols
Authors: Awang Mariyamni Bt , Dzulkarnani Iskander B. , Wahyudeen B. Zakaria Mohamed 
Published: May 2016

Abstract
Published research showed that alcohols are able to reduce the interfacial tension (IFT) between surfactant and oil when added even in small amounts. Much of the work had focused on primary alcohols. This paper presents our preliminary investigation on the effects of branched alcohols on interfacial tension changes in crude oil- sodium dodecyl sulphate mixtures. Branched alcohols are chosen because many forms of bio-waste contain a significant number of branched components and a cheaper product is expected if the natural structure of the feedstock can be exploited. Our results show that 0.5 wt% of branched alcohols result in similar amount of reduction caused by 1 wt% of sodium hydroxide. Sodium carbonate gives better performance than sodium hydroxide or the branched alcohols used, however its use is limited to low salinity conditions. More studies will be conducted with an emphasis on the effects of branching, solvation ratio and salinity.

Introduction
Chemical flooding is limited largely by the cost of chemicals such surfactants. However, literature has shown that several additives such as alcohols are able to further reduce the interfacial tension (IFT) between surfactant and oil when added even in small amounts. Consequently, the chemical cost is reduced by using a lower concentration of surfactant. Branched alcohols are chosen because many forms of bio-waste contain a significant number of branched components. A cheaper product is expected if the natural structure of the feedstock can be exploited in the production reactions. The oil palm industry in Malaysia generates a large amount of waste and a newly introduced crop, Jatropha oil is a potential feedstock. Alcohols such as ethanol and propanol have been used as additives in surfactant flooding. However, not much work has been conducted on branched alcohols. Interfacial tension directly affects the microscopic displacement efficiency in surfactant flooding and therefore, a low IFT system indicates good microscopic efficiency can be achieved. This ongoing research investigates interfacial tension change in a surfactant/crude oil system using branched alcohols as additives.
Experimental Investigation of Salt Precipitation during Gas Injection into a Depleted Gas Reservoir
Authors: Golghanddashti Hassan , Saadat Mohammad , Abbasi Saeed , Shahrabadi Abbas 
Published: May 2016

Abstract
Water vaporization and its induced damage around the wellbore are important issues with a wide application. This phenomenon could be observed wherever dry gas is injected into gas and oil reservoirs in presence of connate water. Gas injection for EOR, pressure maintenance or storage purposes and carbon dioxide sequestrations in aquifers are examples where it could happen. There are two counteracting factors existing in vaporization phenomenon, water saturation decrease and induced permeability impairment by salt precipitation in the porous medium. Water saturation decrease tends to raise injectivity or productivity by providing higher share of passage to gas. Salt precipitation tends to reduce them by the damages induced. The interaction of these two factors determines how productivity or injectivity will alter. It is a quite new subject finding its interest in application however limited researches are done on this up to now and many aspects are left unknown.
We conducted an experiment to investigate the impact of water vaporization on injectivity for core samples of an Iranian gas reservoir candidate for gas storage. According the results, the medium with higher permeability experiences an improved injectivity during gas injection while the medium with lower permeability experiencing an impaired injectivity. Now distribution of each medium around the wellbore dictates if a field application would face injectivity increase or decrease.
Finally, the interaction of two effective factors mentioned above differs for each porous medium and water system. Therefore, an experimental investigation for each system should be performed in lack of a general formulation for injectivity or productivity alteration because of water vaporization around the wellbore.
Well Integrity remediation - A Challenge for Swellable Technology
Authors: Durongwattana Nithipoom , Toempromraj Wararit , Jedsadawaranon Panit , Sompopsart Suwin 
Published: May 2016

Abstract
The word "integrity", is defined as: "the state of being whole, complete and entire, in an undiminished or unbroken condition". Well Integrity Remediation, therefore, is maintenance of well quality to insure such totality and undiminished condition.
Well integrity has received a significant attention these days, from well conception to well abandonment. The driving factors such as the high oil price along with new techniques for Enhanced Oil Recovery (EOR) make it feasible and profitable to prolong the field life beyond original design. However, an extended well life has led to a higher probability of well integrity related problems e.g. Fatigue, Erosion and Corrosion.
As case in point, PTTEP S1 - Sirikit Oilfield, experiences unavoidable well integrity problems, primarily relating to corroded casing due to water encroachment. In this respect, it is the sub-surface challenge to minimize the shut-in time and prolong overall well life. To address these problems, swelling elastomer was considered for a remediation work by isolating leak casing from production system, and thereby preventing further well integrity failure. Properties of inherent elastomeric substances is designed such that, when in contact with the wellbore fluid, will react and swell against the contacted surface providing long-term isolation with no mechanical intervention. The known product e.g. Swellable Packer has been proven for many years mainly for open-hole applications, until such a time as cased-hole remediation techniques are implemented by PTTEP.
This paper examines case histories and demonstrates the practicality of Swellable Packer in the cased hole application which aging casings wall were chronically corroded by water encroachment. Two different types of wells: producer and injector, which casing confirmed failure by Production Logging tool (PLT) and Ultra Sonic Imager tool (USIT), were selected as candidates. The background, operation sequence and performance evaluation methodology are detailed on the following sections in this paper.
Pilot Plant Test of a New Syngas Production Process for Floating GTL to Utilize Associated Gas
Authors: Suehiro Yoshifumi , Watanabe Yoshiyuki , Kawasaki Tsutomu , Yokoyama Kota , Ikeda Koichiro , Masuda Masataka 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
JGC Corporation, Osaka Gas Co., Ltd and Japan Oil, Gas and Metals National Corporation (JOGMEC) have been jointly developed a new syngas production process, Advanced Auto-Thermal Gasification (AATG) process, consisting of a new auto-thermal reforming catalyst with high-performance desulfurization of natural gas.
This paper includes the result and discussion of the applicability of AATG process for Floating GTL (FGTL). For application of FGTL, we verified stable syngas production performance of AATG process at a pilot plant of which capacity was 65 BPD-GTL equivalent by feeding several different concentration of oxygen mixed with nitrogen as an oxidizer during 200hrs at each test. In addition, we examined the effects that nitrogen gas and nitrogen compounds, which are generated by using oxygen mixed with nitrogen as an oxidizer in the AATG process of the pilot plant, have on the FT synthesis process. Moreover we identified technical problems to be solved in the application of the AATG Process to FGTL. Finally, we showed a result of the simplified feasibility study to apply AATG process to FGTL.
Detecting Hydrocarbon Reservoir through Inversion of Broadband Multicomponent CSEM Data and Joint Interpretation with Seismic Constraints
Authors: Rahim Mohamad Faizal Abd , Meju Maxwell Azuka , Bujang Awang Amirul Zakry Awang , Fuad M. Izzuljiad Ahmad , Majid Hani Noorashiqin A 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract

Description
The marine Controlled-Source Electromagnetic (CSEM) method uses electromagnetic waves to detect resistivity contrast in the subsurface which can be used to distinguish between commercial and non-commercial hydrocarbon or brine. One of the limitations of conventional CSEM is depth resolution of subsurface structures. Multicomponent data offers partial remedies to this problem while combining with seismic improves vertical resolution. A stable iterative inversion scheme that permits occam and model based inversions have been developed to investigate these problems.
In this paper, joint interpretation of a gas field offshore east Malaysia using CSEM, well bore and seismic data is presented. Firstly, we carried out synthetic studies of multifrequency and multicomponent 1D occam inversion using a model derived resistivity log to determine the improvement in resolution achievable through this approach. Secondly, the similar approach is applied to a field data acquired over a gas field in east Malaysia. A model based constrained inversion approach is applied to the field data to recover improved estimates of model resistivity, not obtainable through Occam inversion. Depth determined from seismic horizons are used as a priori information in the inversion while resistivities are free parameters.

Application
Establish a working model for the application of the CSEM method specifically in the eastern Malaysia offshore basins.

Results
The inversion results of CSEM synthetic and field data is presented in detail.
The results are validated using existing wellbore and seismic data. Previous work have been mostly concentrated on synthetic data, while some of the work that was presented using field data lack the validation part which requires well bore information.
The synthetic studies confirm previous work by Key (2009), that broadband multicomponent inversion significantly improves model resolution. Results from the inversion of field data agree with well log but are a smoothed version. The use of seismic depth control is found to yield resistivities closer to the ground truth and is recommended.
The effective sequence of operations is formulated into a workflow that can be used in deepwater exploration surveys.
Maintaining Of Ageing Storage Tanks
Authors: Henry Neil 
Published: May 2016

Abstract
There are tens of thousands of storage in service, many well beyond intended service life and commonly over 25 years of age. The passage of time does not treat them all equally. Owners and operators of tank storage need to recognise the indicators of age and deterioration and have an understanding of why this occurs and the likely rate. Knowledge of how these problems originate and how they may be controlled is an opportunity to improve plant safety performance, gives confidence in condition and helps assure reliability of operation.
There are financial benefits that arise from effective management of ageing; therefore it should not be considered a burden on operations and maintenance. The presentation uses examples from industrial experience to demonstrate how to manage integrity and the benefits that may be achieved.

Introduction
Following over 30 years of involvement in a process plant operating in many different environments, a deep understanding has been gained of how equipment deteriorates and the influences of operating regimes on life expectancy. It is the intention of this paper to illustrate how to improve understanding of the condition of storage tanks currently in service and required to operate into the future
This knowledge has been gained by both working on management of integrity and extensive forensic failure investigation, of process equipment including storage tanks. The investigation objectives have always been focussed on not simply specifying the mechanism of failure, but also identifying the true root cause(s).
The knowledge has been used to assist in preparation of the UK HSE Research Report 509 on Ageing Plant and to evaluate the condition of many items of process equipment, in a wide range of industries.

Why is age important?
In simple terms, there was a great deal of process plant built in the 1950's to 1980's, which had little definition of its expected service life.
Following this time there was a beneficial running and maximising cash generation. These assets still appear to be able to operate, but there is limited data to base judgements of how long is the optimum service life.