bluuebunny/crossref_metadata_2025_split huggingface dataset:
Assessing Reservoir Quality of the Diyab Source Rock in UAE
Authors: Baig Muhammad Zeeshan , Van Laer Pierre , Leyrer Karl , Makrachev Gennady , Al Marzooqi Hassan , Al Suwaidi Salama , Raina Ishan , Dasgupta Suvodip 
Published: November 2017

Abstract
Diyab has served as the source rock for various major Jurassic and Cretaceous oil & gas plays in Middle East, and a number of recent studies have indicated that the Diyab formation has potential to be explored as an unconventional source rock gas play. This assessment is mainly based on 1) the known facies distribution, 2) lithology and rock properties, 3) source rock TOC and maturity 4) mud gas, and 5) Stimulation results. The objective of this paper is to identify the resource potential of Diyab source rock as an unconventional gas play in UAE.
Integration of valuable measurements is of upmost importance to reduce the uncertainty in reservoir quality assessment of any exploration setting. Quantifying TOC and maturity are one of the most important aspects in evaluating the source rock potential of an unconventional play. Due to the complexities seen in several source rock plays, assessing quality through interpreting mineralogy, porosity and water saturation can also be quite challenging. To achieve that, a comprehensive mud logging analysis program was carried out in the well complemented with a comprehensive and modern logging program combined with a detailed unconventional core analysis to identify rock properties, fluid type and saturations with the scope to assess unconventional resource potential of the Diyab formation in UAE.
Initial petrophysical evaluation shows that Diyab source rocks have a good Shale Gas resource potential within three different zones of interest in the Diyab formation. These zones of interest are based on, 1) Total Organic Carbon, 2) Porosity and 3) Saturation. During the petrophysical evaluation advanced mud logging analysis was used as initial calibration for TOC and mineralogy, a multi-frequency dielectric tool was used for initial saturation estimation and nuclear magnetic resonance analysis was used for porosity estimation and characterization. In the final computation, unconventional core analysis was used to refine and further calibrate the results. The level of gas saturation exceeds common pay criteria which are known to produce economic volumes of gas in other basins around the world.
Diyab as a source rock and as unconventional gas play in UAE in terms of reservoir quality has never been studied in detail. This is the first time that this kind of a comprehensive evaluation program was carried out using advanced log acquisition, advanced mud logging and specific unconventional core analysis and through this paper important aspects of reservoir quality for Diyab formation will be discussed and will be of great help for future exploration plans in the Diyab unconventional gas play.
How the CORE Project is Helping Drive a Culture of Continuous Improvement
Authors: Al Saadi Israa , Khan Shahla 
Published: November 2017

Abstract

Objective/ Scope
A commitment to continuous improvement lies at the heart of Dolphin Energy's business and the company places much responsibility on its employees to maintain this commitment at all times.
The launch of the company's cost optimization program, The CORE Project (TCP), in February 2016 was undertaken in response to the challenging conditions in the oil and gas industry and provided new opportunities to improve the company's financial performance. This paper will explain how TCP supports the company's commitment to continuous improvement by creating a ‘bottom up’ approach to drive collaboration through education, the development and use of cost saving processes and procedures and by rewarding employees and celebrating their success. The result of which has led to significant cost savings for the company.

Methods, Procedures, Process
The objective of TCP was to deliver cost savings to the company and enhance a culture of cost consciousness. To achieve this the onus of responsibility has been placed on the company's employees, tasking them to collaborate to deliver sustainable results and drive efficiency improvements through a long-term commitment.
This ‘bottom up’ collaborative approach to improve financial performance has been supported through the development of the following aspects, which helped create the right conditions for success:

Results, Observations, Conclusions
In the past 18 months, employees have generated more than 1,300 ideas, of which more than 260 ideas have been converted into cost saving initiatives without jeopardizing the safety of staff or the integrity of the facilities. This collaborative approach has not only demonstrated the value placed on a commitment to continuous improvement but created renewed commitment from employees to continue supporting the program in 2017, as evidenced by the results of a perception survey conducted earlier in the year.

Novel / Additive Information
This paper will help highlight tangible benefits that can be produced by creating conditions that encourage employees to drive a culture of continuous improvement.
Middle-Jurassic Carbonate Velocity Models in Saudi Arabia: Development and Validation
Authors: Alabbad Abrar , Ayadiuno Chris 
Published: November 2017

Abstract
Carbonate reservoirs are complex and require care in choosing an appropriate velocity model (Rafavich et al, 1984; Wang et al, 1991). Saudi Aramco has recently conducted a study to understand the effect of saturation and pore structure on the velocity of a particular Middle Jurassic carbonate reservoir in Saudi Arabia (Ayadiuno et al, 2015). As part of the study, several velocity models were empirically developed as a function of pore fluid type, density, and porosity. The study results suggested that at low velocity values, the obtained brine saturated core model correlated with Pickett while oil saturated core model correlated with Castagna (Ayadiuno et al, 2015). However, at high velocity values, the obtained models didn’t correlate with the published models. In addition, the study suggests that rock’s compressibility is less dependent on pore fluid type when the aspect ratio of the pores is high (Ayadiuno et al, 2015).
In this paper, three core-derived velocity models, developed as part of the earlier study (Ayadiuno et al., 2015), at 100% water saturation were extended and validated on the Middle Jurassic carbonate reservoir across four fields in Saudi Arabia. These models are: (1) compressional velocity as a function of total porosity (Model A), (2) compressional velocity as a function of bulk density (Model B), and (3) shear velocity as a function of compressional velocity (Model C). A total of 11 wells from four fields were selected to validate the velocity models. Fluid substitution was performed using log data and water as in-situ fluid to reduce prediction uncertainty related to the differences in saturation fluid type. In addition, we addressed the difference in scale between data used to develop the models (core plugs) and data used to validate the models (well logs).
Our findings are summarized as follows: (1) Model A, velocity as a function of porosity, is less sensitive to changes in rock stiffness and thus, is more reliable than Model B, (2) Model C, which predicts shear velocity, shows an overall better estimation of shear velocity than publicly available carbonate models from Castagna et al, (1985) and Pickett (1963). Thus, velocity models obtained from the study are more applicable to the four fields than published (Castagna and Pickett) models. The evaluation of these internally-developed carbonate velocity models across different fields shows a promising result in decreasing the uncertainty of velocity estimation in the Middle-Jurassic carbonate reservoir in Saudi Arabia. This work emphasizes the importance of assessing factors that affect acoustic properties, as well as the importance of multi-scale integration between core-plug measurements and logs.
PFLNG1 - Completing the LNG Value Chain Through Technology
Authors: Yussoff Wan Mohd 
Published: November 2017

Abstract
PETRONAS has developed a Floating Liquefied Natural Gas (FLNG) to capitalize and monetize on the availability of the gas resulting from the development of several gas fields in Malaysia. FLNG is a concept where there is an integration of the floating production, storage and offloading unit with LNG production facilities on the deck. It refers to liquefied natural gas (LNG) operations employing technologies designed to enable the development of natural gas resources located offshore. Floating near to an offshore natural gas field, the FLNG facility will be able to produce, liquefy, store and carry out ship-to-ship transfer of LNG at sea before LNG carriers ship it directly to markets. Since everything is carried out at sea, there is no need to construct any jetty, breakwater ar even LNG tank farms.
PETRONAS has taken a bold decision to embark on the first of its kind offshore LNG liquefaction facility. FLNG signifies PETRONAS’ technology advancement solution which adds value to marginal and stranded offshore gas resources which otherwise would be uneconomical to be developed, hence becomes a benchmark for the execution of similar-scale FLNG facility.
PETRONAS Floating LNG concept was envisaged to monetise stranded gas resources. The two floaters namely PFLNG1 & PFLNG2 for offshore Sarawak and Sabah respectively will increase the country's LNG production capacity by approximately 8% (2.5 MTPA). This paper will highlight the first FLNG developed by PETRONAS; the PETRONAS Floating LNG Satu (PFLNG1).
The PFLNG1 is designed based on a new built vessel rated for 1.2 MTPA LNG production capacities. The facility will receive feed gas from an identified gas fields which is operated by PETRONAS through a subsea pipeline at the water depth of about 77 meters. The design is based on a new built vessel with LNG storage capacity of 177,000 m3, condensate storage capacity of 20,000 m3. The design life for both hull and topside is for 20 years without the requirement for dry-docking. The hull was design in the ship-shaped form and adopted relevant marine standards and techical requirements.
Earlier, the PFLNG1 was constructed at a shipyard located in South Korea. Upon the completion of the construction phase, the facility was towed to site before it was hooked up to the sea bed using the turret mooring system. The facility will have a weathervaning capability which allows it to rotate 360 degree around the turret to ensure right heading during its operation.
Evolution of Reservoir Management and Development Strategy of a Giant Offshore Field in Abu Dhabi
Authors: Khan Muhammad Navaid , Al Neaimi Ahmed , Al-Shehhi Omar , Channa Zohaib , Ahmed Fazeel , Al Feky Mohamed , Sarsekov Arlen 
Published: November 2017

Abstract
Reservoir management has been defined in many different ways, such as, "a sequence of resource–deployment decisions made to maintain optimum economic recovery of petroleum", "the application of available technology and knowledge to a reservoir system in order to control operations and maximize economic recovery within given management environment", "rely on use of financial, technological, and human resources, while minimizing capital investments and operating expenses to maximize economic recovery of oil and gas from a reservoir" (Thakur 1996) etc. Overall, the whole purpose of reservoir management is to help oil companies make the best decisions to meet specific objective using all the available resources.
Essentially a reservoir management & development strategy is comprised of various elements; however, the purpose of this work is to shed light at the key elements, which were recently revisited to tackle the evolving changes in reservoir conditions for a giant Abu Dhabi Field, with a development and production history of over 50 years. The intent on this paper is to share the unique methodology adopted to address the sector-based reservoir performance and to generate the relevant opportunities to tackle the pertaining issues.
Integrated Sand Control Technique Utilization of Thru Tubing Sand Screen and Wellhead De-Sander Technology
Authors: Malau Aldani , Sutarto Balok , Ghozali Farid , Istono Noviadi , Sukotrihadiyono Tejo 
Published: November 2017

Abstract
LN field is a gas field located in South Sumatra, Indonesia. The conversion trial from medium pressure to low pressure tested at the field in 2009 unfortunately led to sand carried out from formation. Wellhead de-sander and production rate control since then have been initially used as a preliminary effort to reduce the sand production. Due to depleted reservoir pressure and limited availability of formation core, down-hole sand control selection was very challenging. The condition initiated fluid losses during the well service and inability to conduct compatibility testing prior to applying sand control method such as resin coated sand, gravel packing or frac-packed. In addition to well head de-sander as to improve the sand control quality, thru tubing sand screen method has been selected as a unique alternative to face the sanding problem for LN field condition. Rig-less installation and flexibility of sand screen replacement were the main reason why this method was finally selected.
Thru Tubing Sand Screen was installed using regular slick-line unit. The sand screen was installed very close to end of tubing (EOT); it set just around 2 feet above EOT. Special tubing packer was set with a non-explosive setting tool technology with a battery-operated and time-based device.
Since the particle size distribution of sand for sieve analysis was taken from surface sampling, the possibility of sand passing thru the sand screen or sand plugging the screen was still high. But, the thru tubing method provided easy way to install or uninstall the sand screen while wellhead de-sander provided double protection to prevent sand travelling and damaging the surface facilities.
This paper will share on how the down-hole sand control study was conducted, how the sand screen and the wellhead de-sander designed, the installation and optimization process and the success story of the implementation at LN field before it is concluded as an integrated sand control technology,
A Step towards to Minimize Environmental Footprint: An Innovative System to Dispose Generated Cement Waste on a Zero Discharge Artificial Island
Authors: Singh Rudra Pratap , Khalid Al-Wahedi , Al Kindi Rashid , Bassam G Elatreche , Cesetti Maurizio , Jose Alzate , Benygzer Mhammed , Haddad Mohammed , Hassan Mohammed , Kirby Cliff , Paila Phalgun , Suleiman Ala , Ruzhnikov Alexey 
Published: November 2017

Abstract
Because environmental regulations are rapidly evolving towards stringent requirements, oil and gasoperators are confronted with a great challenge of disposing drilling waste, especially when operating on an artificial island located 120-km offshore and under a Zero Discharge Policy. The paper describes an innovative engineering solution that significantly reduces the time, cost and the associated safety hazards with disposing of the cement waste generated from primary cementing operations and drilled cement cuttings.
The earlier disposal process implemented on the island included collecting, storing, and shipping the cement waste to an onshore treatment facility. This process was proven to be cumbersome, time-consuming and extremely expensive. Additionally, external factors such as logistics constraints, weatherconditions, and storage skips availability had a direct negative impact on the process, resulting in a massive accumulation of waste on the island. On the other hand, the newly developed disposal process utilizes existing resources, with minor modification, within the artificial island. A step-by-step procedure was developed to dispose all excess cement and drilled cement cuttings generated without any negative HSE impact.
A pilot trial was performed successfully by injecting the cement waste into the shallow loss zone through the annulus, and therefore, the process was generalized to both island and found to be safe and efficient operationally and economically. The new innovative method simplifies the disposal process to a one-stage operation that is performed along with the primary cementing operation. By implementing the process, no cement handling on surface is needed, resulting in a 90-percent drop in the cost.. The number of people involved is reduced as well. Consequently, a reduction in the hazard exposure and the potential lost time incident (LTI) is achieved.
Asset Optimization Using Downhole Corrosion Sensor for Electrical Submersible Pumps
Authors: Chandran Ashwin , Liu Yi , Monteiro Othon , McClain Scott Thomas , Liu Zhengwei , Krueger Sven 
Published: November 2017

Abstract
Corrosion and related issues are a major contributor in failures of electrical submersible pumps (ESP). This paper describes the development and preliminary testing of a new downhole corrosion sensor to be integrated into ESPs for providing continuous monitoring. We will describe the development of a downhole sensor, testing and applications of such a sensor. In-situ corrosion monitoring provides valuable and actionable data that enables implementation of mitigation strategies before damages occur and allow for planned servicing. It ultimately allows operators to make informed decisions on corrosion control and ESP maintenance scheduling.
Bio-Derived Porous Graphitic Carbon as Highly Efficient Mercury Scavenger from Natural Gas Streams
Authors: Edathil Anjali Achazhiyath , Kumar Reddy K. Suresh , Pal Priyabrata , Srinivasakannan C. , Banat Fawzi 
Published: November 2017

Abstract
Remediation of toxic mercury emissions in the form of elemental mercury (Hg°) from the well head has become a dire necessity in the fast paced natural gas processing industries, as even low levels of mercury can damage the cryogenic aluminum heat exchangers and other plant equipment. Also, enforcing stringent measures to reduce the effect of elemental mercury is of great environmental concern owing to its high toxicity, volatility, chemical inertness and neurological health impact. Thus, synthesis of efficient and cost-effective porous carbon based sorbents having high selectivity and sorption capacity has attracted considerable interest, and is a widely used and industrially preferred technique. The present work focuses on the development of low cost and biomass derived graphitic carbon as a potential candidate for scavenging mercury from natural gas processing as well as refining operations. The bio-derived porous graphitic carbon (PGC) material was fabricated through a facile and sustainable method, from the natural biopolymer (calcium alginate) by pyrolyzing at 900°C under an inert atmosphere. The performance was examined by testing the graphitic carbon in a bench scale setup and using simulated environment mimicking the plant conditions. The adsorption results show evidence that accessible high pore volume, hierarchical pore structure, coupled with long range ordering enables the proposed PGC as an efficient low cost adsorbent for removing elemental mercury from natural gas. The high adsorption capacity of 626 μg/g exhibited by the graphitic carbon at an adsorption temperature of 50°C, outperformed the leading porous carbon currently used for gas phase mercury removal. Also, the increasing cost of conventional sorbents make these poly saccharide based biomaterials an attractive candidate. All these findings demonstrate the promising solutions offered by PGC for scavenging elemental mercury from natural gas.
Building Variable Saturation Height Functions with an Improved Rock Typing Scheme
Authors: Kundu Ashish , Voleti Deepak Kumar , Rebelle Michel , Al Housani Habeeba Ali 
Published: November 2017

Abstract
The studied lower Cretaceous carbonate ramp deposits are heterogeneous with pervasive diagenetic processes leading to complex pore network and rock texture. Before this study, field development was based on log based water saturation modeling. This saturation modeling was dependent on the hydraulic flow units and porosity classes, which was meant to be, but was not explicitly representative of the defined geologic facies. The assignment of the relative permeability data is also very challenging in the absence of proper Rock Type model. Often in carbonate reservoirs, there is no direct or linear relationship between Reservoir Rock Types (RRT), sedimentological facies assemblages and water saturation distribution across the field. Hence, accurate integration of the sedimentological, diagenetic, depositional environment information and petrophysical properties is essential in building a robust RRT model. This RRT model can then explain the rock-fluid interaction through a reliable saturation height model.
In the first part, the paper illustrates the workflow which involves integrating lithofacies, depositional packages, degree of cementation, pore-type from sedimentology and relating resultant pore-typing to core porosity–permeability data. This workflow resulted in a strong reservoir rock typing scheme, which was key in building a robust saturation height model. Precisely, this was achieved by assigning "most-of lithofacies and diagenetic indicators" to each rock type defined. In the second part, a Variable Saturation Height Function (VSHF) was developed using mercury injection capillary pressure (MICP) data. The function was made variable with depth by bringing one or both of the reservoir parameters (Phi and K) into the equation. Most importantly, VSHF explicitly scans the lower and upper Sw boundary of a particular rock type and helps in removing the skewness in the Sw difference histogram between model and log Sw. One of the important steps in the workflow was to normalize the MICP data to log derived Sw values, provided the confidence on the Sw calculation from logs is high. After stress and closure correction, the normalization of the reservoir Pc data was achieved through an independent correction factor.
Both of the workflows (rock typing and saturation height modeling) were built based on data from 30 cored wells. The workflows were tested on 15 cored wells and more than 600 non-cored wells. Rock type maps were found to be more correlatable with reservoir quality maps than lithofacies maps alone. This is a result of the diagenetic processes undergone by the rock during and after deposition modifying the original depositional controlled pore architecture. With this approach the water saturation distribution was more consistent with logs and core derived Sw data.
The workflows shown in this paper are reliable and can be extended to other carbonate fields’reservoir characterization.