bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improving Sulphur Plant Reliability and Efficiency
Authors: Liu Zhenhai , Agung Margono Kuntadi , Kiebert Jan 
Published: November 2019

Abstract
ADNOC LNG on Das Island facility consists of three process trains. Each train contains one Sulphur Recovery Unit (SRU) which comprises a three-stage Claus unit followed by a SUPERCLAUS® unit. In the past 5 years, average Reliability of these SRUs is 85.7%, much below 98% of the LNG group benchmark value. The calculated Sulphur recovery efficiency in Clause mode is between 92% to 96% which is well below the target value of 97.5%. The SRU reliability and efficiency continue to have a negative impact on Sulphur production loss as well as flaring and emissions.
This paper describes corrective actions taken by ADNOC LNG to address these issues in order to improve SRU reliability and efficiency and to minimize production losses and flaring. The implementation of these corrective actions has resulted in 8% improvement on SRU reliability. Sulphur recovery efficiency under Clause mode increased by 3.1%, leading to a significant reduction on flaring and emission, as well as increase on Sulphur production.
Corrosion Resistant Alloy Pipeline Installation for High Pressure High Temperature Requirement
Authors: Kassim Khairan Syuhada 
Published: November 2019

Abstract
This paper discusses on the methods of the installation of Corrosion Resistant Alloy (CRA) pipeline for High Pressure High Temperature (HPHT) including its challenges and the subsequent mitigations.
The experience is based on the successful installation of Anjung Gas Development Project which consists of 18" diameter X 8km length of CRA Full Well Stream (FWS) pipeline installed utilizing the (Dynamic Positioning) DP-2 pipelay vessel. The methodology applied in the installation is via typical S-lay utilizing automatic welding system (for the pipelaying) and stalk-on (for the risers at both sides of the platforms). Additionally, Zero Radius Lay (ZRL) method was utilized at buckle triggers. On the existing KAKG-A platform, the riser installation is via suck-in method to avoid removal and reinstatement of the existing riser guard. Two (2) numbers of anode sleds were utilized for cathodic protection. The scope for pre-commissioning performed was flooding the pipeline with fresh water, cleaning, gauging, hydrotesting, air drying, nitrogen purging and packing.
Multiple Concrete Weight Coating (CWC) thicknesses was used to cater for anchoring of pipeline walking. One (1) set of tensioner shoe pads was moulded to suit all CWC thicknesses in order to mitigate the issue of maintaining two (2) tensioners holding the pipeline during pipelaying. The other two (2) tensioners onboard the Main Work Barge (MWB) were installed with sets of tensioner shoe pads suitable for different thickness of CWC. Although with various weld defects experienced, mitigations that were executed proved that the layrate could be improved and finally achieved the target layrate. A wet buckle procedure including its equipments was prepared as a contingency plan. However, due to no wet or dry buckle, this procedure and equipment were not utilized. The project completed successfully with zero Loss Time Injury (LTI) and no major issues. Hence, it is an achievement for PETRONAS. It sets as a standard in moving forward in any new technologies that is developing.
The overall schedule was improved by approximately 20% and cost was reduced by approximately 15% due to the above mitigations. The impact of the successfulness of this pipeline installation is a basis for PETRONAS future CRA pipeline installation as this is the first HPHT CRA pipeline installed by PETRONAS Carigali Sdn. Bhd. (PCSB). This proves one of PETRONAS' 5 Quality Principles, Right Things Right Every Time. The challenges including the mitigations are a good lesson learnt for any future CRA pipeline installation projects that the industry will be undertaking.
In this project, the PETRONAS Technical Standard (PTS) 193004 Installation of Offshore Pipelines and Risers (Amendments/Supplements to ASME B31.8, ASME 31.4 AND DNV OS F101) and API 5LD is the basis for the installation.
Reservoir-Scale Characterisation and Prediction of Microporous Limestones. Example the Arab Formation Upper Jurassic, Onshore United Arab Emirates.
Authors: Bin Ishaq Wala , Al Darmaki Fatima , Lucas Noel , Al Mansoori Mohamed , Deville De Periere Matthieu , Foote Alexander , Bertouche Meriem , Durlet Christophe 
Published: November 2019

Abstract
In the onshore sector of the United Arab Emirates, the Lower Arab D Member (Kimmeridgian) typically encompasses a thick succession of rather homogeneous low-energy mid-ramp carbonate mudstones interbedded with minor storm-induced cm-scale skeletal-rich floatstones. Within these deposits, the pore volume is dominated by locally abundant matrix-hosted micropores, along with variably abundant open to partially cemented fractures, primary intraparticle macropores and rare moulds and vugs. As a result of this variably developed pore system, measured porosity varies from poor to very good, while permeability changes from extremely poor to rarely good. Detailed petrographic observations (thin-sections, SEM) carried out within six cored wells in a sour gas reservoir highlight that the variations in reservoir properties are primarily linked to the micron-scale variations in the micritic fabric. Indeed, anhedral compact micrites with coalescent intercrystalline contacts are associated with very small and poorly connected micropores, while polyhedral to subrounded micrites with facial to subpunctic intercrystalline contacts show locally well-developed micropores and therefore better reservoir potential. δ18O and δ13C isotope measurements do not discriminate both micritic fabrics, indicating a recrystallisation of the matrix within shallow burial conditions. However, bulk XRF measurements, and especially SiO2, Al2O3 and Fe2O3 content indicate that poorly porous anhedral compact micrite host more insoluble material and have been prone to a greater compaction compared to porous polyhedral micrites. Log-derived elastic properties, including Young's Modulus (YME) along with porosity data, have been used in two wells to explore the potential relationship between micritic fabric, porosity, permeability and elastic properties. With the evolution of micritic fabric from anhedral compact to polyhedral / subrounded, Young's Modulus decreases with increasing porosity, indicating a decrease in the overall stiffness of the rock. Based on these two learning wells, specific porosity and YME cut-offs have been identified to discriminate the various micrite fabrics. Those cut-offs have been successfully tested in four other wells used as a blind test for the vertical prediction of the micritic fabrics, in which accurate predictions reached up to 90%. Following these results, porosity and YME cut-offs have been used to produce the first model of the distribution of the various micritic fabrics at the field-scale. These results have a fundamental impact on how sedimentologically homogenous microporous limestones can be described and predicted at the well and field-scales, especially in the context of exploring tight carbonate plays associated with intrashelf basins.
Smart and Innovative Approach that Makes Multilateral Well Construction Efficient and Economical for Worldwide Application
Authors: Kashlev Alexander , Fedotov Andrey , Philippov Alexander , Sayapov Ernest , Moiseyenkov Alexey 
Published: November 2019

Abstract
Global depression in the oil market has recently been the main driver in forcing oil companies to discover more efficient solutions to produce hydrocarbons, as well as to optimize existing strategies and practices, whereas multilateral and branched well completion technologies act as a tool for improving performance of both new and existing well stocks.
These services have been among the premium products offered by oilfield service majors. High cost of this service derives from a limited number of players that are capable of offering and executing such high technology operations, as well as from insufficient field exposure making each implementation very unique and therefore expensive.
The advantages of multilateral wells are well-known in the industry. The most obvious ones are: CAPEX savings on upper completion.Step increase of the drainage area.Wells infill drilling without expanding surface infrastructure.
Rock Type Prediction Using Democratic Neural Networks Association DNNA: An Alternative Method to Describe Clastic Fillings in Ordovician Karsted Carbonates within a Region of the Tahe Oilfield, China
Authors: Mendez Jose Nicanor , Jin Qiang , Gonzalez Maria , Zhang Xudong 
Published: November 2019

Abstract
This study outlines a probabilistic model based on artificial neural networks applied to the very deep karsted carbonates of the Ordovician Yingshan Formation, which represent significanct reservoirs within a region of the Tahe oilfield, Tarim Basin, China. The complexity of rock type prediction and distribution of paleokarst fillings hosted in cavities, drives the need to apply new techniques for identifying more plays. This investigation focuses on a karsted interval located between the reflections of unconformities T74 and 76. The analysis was conducted using acoustic impedance (P-wave) and amplitude seismic attributes, processed from a 32-bit seismic dataset (Poststack). The methodology also includes conventional wireline logs from 28 wells adjusted to lithological descriptions of cores. Democratic Neural Networks Association (DNNA) is the proposed method for rock type prediction in karsted carbonates that simultaneity utilizes 3-D seismic data and well data. Based on sedimentological descriptions, the karst facies are classified in six types of lithofacies: mixed siliciclastic and carbonate (e.g., calcarenite and conglomerate), limestone, very fine-grained sandstone, mudstone, breccia, and unfilled. According to identified lithofacies, a clustering analysis is performed using the followings logs: Gamma Ray (GR), Deep Resistivity (RD), Neutron (CNL), Density (DEN), Sonic (AC), Potassium (K) and Thorium (TH) from Spectral Gamma Ray. Subsequently, the outputs are simplified for selecting the model most representative of lithofacies. Once adjusted data in commercial package, a training set and stabilization geometry involving seismic attributes constrained by interpreted seismic horizons are processed. The extracted seismic traces along borehole trajectory after processing demonstrate a good match with analyzed data, where the predicted maximum probability and class probability tracks vary with respect to lithofacies. Making time slices on the computed volume are observed to estimate effectively the probability of karst facies away from the wells. The outcome of this workflow is a probabilistic facies volume that provides appropiate description of clastic rocks that cover paleokarst fillings essentially in the run-off subzone. The model indicates that mudstone facies are the most prevailing and better proportions of siltstones or sandstones facies are distributed to southeast of area. This study concludes that in determining clastic lithofacies distribution, employing several neural networks running in parallel that simultaneously learn from the same dataset through different strategies is an effective tool. To date, there has not been any study on rock type prediction using DNNA in karsted carbonates. The results represent a significant contribution to the collection of geosciences on characterizing this type of reservoir.
Successful Discoveries Using Novel DHI Technology Based on Seismic Resonance and Dispersion
Authors: Skantze Kristofer 
Published: November 2019

Abstract
A new technology that analyses dispersion events in seismic data is presented. The technology aims at identifying both reservoirs and also the likelihood of any presence of liquid hydrocarbons within them. This paper details the science on which the technology is based and empirical results from usage of the technology.
Presence of strong wave dispersion in seismic data has analytically and in tests been seen to correlate with high porosity and permeability formations. A lack of dispersion has conversely been seen to correlate with low porosity systems. Furthermore, a high viscosity fluid in a poro-elastic system has been seen to cause higher dispersion effects compared to brine. This permits derisking of reservoirs to identify locations with high chance of liquid hydrocarbon.
Resonance wave systems are abundant in sedimentary rock. The measurement of resonance waves permits the study of otherwise weak frequency shifts in seismic data, which can then be used to search for reservoir rock and liquid hydrocarbon.
Velocity dispersion and resonance wave analysis of seismic data requires carefully selected wavelet based spectral decomposition methods. Results from a commercially available technology presented in this paper have shown a need to prioritize high accuracy spectral decomposition methods that are able to identify minute dispersion events. These methods are often very computationally demanding. Therefore, those methods need to be selected that ensure highest accuracy while optimizing for speed.
A dispersive event occurs when an incoming P-wave propagates through a heterogeneous porous media due to mesoscopic flow. Dispersivity contributions may also stem from localized effects such as Krauklis waves. The level of dispersivity has in models and field tests been identified as a function of the reservoir porosity, permeability and fluid viscosity. Empirical results from the technology presented here, suggest the ability to identify reservoirs and frequently also their fluid content using dispersion analysis of seismic data.
Case study results using the commercial technology are presented over both discovery and dry wells in Norway and Oman. The results show how new insights into poro-elastic lithology can be provided and also the technology's potential to contribute to an improved overall prospect derisking and field delineation with respect to fluid content.
The technology demonstrates the ability to extract additional information from seismic data sets and thereby further the geological and geophysical subsurface interpretation and modelling.
Enabling Production Logging in Commingled Flow During HPHT DSTs Allows Critical Dynamic Data Integration for the Khuff Formation in the UAE
Authors: Sookram Neil , Steiner Stefan , Basioni Mahmoud , Menon Pradeep , Noble Reed , Al Afeefi Baraka , Jabbour George , Yaacoub Michel 
Published: November 2019

Abstract
The United Arab Emirates’ strategy to increase gas production, reduce dependence on pipeline imports and become a net exporter of this commodity has led to various important reserve discoveries. Appraisal wells drilled in gas formations such as the Khuff require both static characterization as well as dynamic data integration to improve the overall reservoir modelling in these complex tight reservoirs.
Drill Stem Tests (DST) performed on Khuff appraisal wells provide important dynamic data, however in commingled flow tests more detailed information than that obtained from downhole pressure measurements and surface flow rates is required for a representative dynamic downhole characterization. Production logs (PLTs) can provide the required downhole fluid and flow profiles to differentiate inflow from different reservoirs or individual perforation zones. Such operations can become more complicated in the deep and high temperature Khuff reservoirs, especially when running through the small internal diameters in the DST bottom hole assemblies.
The importance of PLT flow profile data for Khuff appraisal wells was recognized early on as a means to help investigate the formation heterogeneity, and the possible influence of natural fracture networks on reservoir productivity. PLTs were included in the DST programs for the appraisal wells, with the next step being preparing logging procedures and equipment to undertake operations as efficiently as possible. This preparation resulted in multiple production logs being successfully acquired in both vertical and deviated wells, along with logs prior to and after acid stimulation, providing invaluable and often surprising insight into the reservoir behavior and feedback for the static reservoir characterization. Along the way various important lessons were learnt that required modifications in some procedures to increase efficiency or reduce operational risks in the difficult downhole conditions.
This paper will review some of the production log results and discuss the lessons learnt with the objective of making this type of dynamic data acquisition more visible as a very feasible activity to help improve reservoir characterization even under difficult conditions of logging through drill stem test strings into deep, high temperature reservoirs.
An Accurate and Reliable Correlation to Determine CO2/Crude Oil MMP for High-Temperature Reservoirs in Abu Dhabi
Authors: Alshuaibi Muataz , Farzaneh Seyed Amir , Sohrabi Mehran , Mogensen Kristian 
Published: November 2019

Abstract
Minimum miscibility pressure (MMP) is an important parameter in the design of a successful miscible gas injection project. It is common industry-practice to infer MMP from a series of carefully designed slimtube tests, but there are cases where a quick and rough estimate of MMP is required to screen for potential application of miscible gas injection.
Mathematical correlations are attractive because they require few input parameters, little information about the fluids, and are quick and easy to use. Whereas MMP using hydrocarbon gas or nitrogen can be predicted with relative confidence using standard correlations, the same level of accuracy is not found for correlations predicting CO2 MMP, in part because of a more complicated temperature-dependent mass transfer.
This study is part of an ongoing effort to evaluate miscibility conditions using a variety of injection gases across the ADNOC reservoir fluid portfolio. We have tested the most common existing CO2 MMP correlations against measured MMP data from slimtube tests for a large number of Abu Dhabi reservoir fluids. The results show that none of the existing correlations can accurately predict MMP for these crude oils and we believe that this is attributed to the fact that most available correlations were established based on reservoir temperatures much lower than the typical temperature conditions of 250 °F found in many Abu Dhabi reservoirs.
We therefore propose a new correlation for estimating CO2 MMP with particular emphasis on high-temperature fluid systems. The new formulation has been developed based on multiple-parameter regression of measured data as a function of temperature, saturation pressure and reservoir fluids composition. In addition to the existing data sets available in the literature, we performed 17 additional slimtube experiments on different Abu Dhabi reservoir fluids to enlarge the parameter envelope and increase robustness of the model. The proposed new correlation predicts CO2 MMP within 6.4%. To constrain the correlation, we performed a series of EOS-based MMP calculations for several fluids in the temperature range of 100 to 350 °F. These calculations confirm that MMP attains a maximum value around 320 °F.
Learn, Play and Compete: A Case Study of the Gamification of Professional Training
Authors: Al-Readean Muhammad 
Published: November 2019

Abstract
Gamification of professional training is a new trend that focuses on promoting motivation, engagement and competition among training participants by integrating game elements into professional training. The lack of widespread adoption of gamification in training in oil and gas industry in spite of technical and technological advancements in other areas requires careful consideration.
A new course gamification process has been adopted to map professional course learning requirements into game objectives, course modules into levels and policies into game rules. An individual scoring mechanism through the notation of experience gained (XP) with ranking leadership board has been used. In each course module or game level, the participants are challenged to solve timed scenario-based puzzles with increasing level of difficulty. The participant who solves a puzzle will score gained experience points that is recorded in the leadership board. These scenario-based puzzles are derived from real-world situations that participants may face doing their jobs. These puzzles or quests promote inductive and deductive reasoning and ensure effective interactive learning experience. In addition, the training participants, as decision makers, were given the opportunity to design the last stage or module of the course using a survey to collect their feedback.
The approach has been adopted in the material of one petrophysical software application training. The course participants showed a great engagement and interaction with more than 90% agreement about the effectiveness of the approach. Clearly, the gamification of the course must not interfere with linearly progressive delivery of the material. The courses adopted a balanced approach to avoid the deviation from the initial overall educational objective. This experience supports the introduction of more sophisticated and advanced gamification mechanisms such as in-application automatic grading mechanism and the use of Augmented Reality (AR).
Improving the Operation Performance Along With Production Profiles in Tight Basement Oil Reservoirs by Utilizing Ball Drop System of Multi Stage Hydraulic Fracturing
Authors: Kortam Mostafa , Zayed Samir , Conrad Joel , Ezeldin Saiff , Batmaz Taner 
Published: November 2019

Abstract
Increased production alongside low costs has always been a long-standing goal for operators in a time where the industry is thriving to increase their operational and economical efficiencies. For maturing fields, operators are constantly seeking innovative techniques to access large quantities of reserves found in low permeability formations.
The nature of the reservoir has resulted in an economical need to implement a hydraulic fracturing campaign. This would assist with increased production through wider contact area of the producing interval. After a campaign resulting in favorable results through hydraulic fracturing, additional efficiencies addressing the operational and cost concerns of cemented plug & perf were required. In order to maintain production increases while maintaining operational efficiency, the need for multi-stage hydraulic fracturing became evident.
Six candidate wells were selected for proppant fracturing utilizing a multi-stage completion technique that has been widely adopted in North America for the past 17 years and internationally for over a decade. The technique utilizes a series of hydraulic mechanical packers and fracturing ports that are shifted open sequentially across the applicable zones targeted for treatment. The ports have seats that are sized to respective balls, which are used to isolate the stimulated intervals. The system allows for increased efficiency through eliminating the risks associated with wireline operations for perforating, or coiled tubing operations to mill out bridge plugs. It also allows for immediate and simultaneous production from all stages as well as contingencies for shutting off water zones. From June 2016 to March 2017, six systems were installed consisting of 6 to 8 hydraulic fracturing stages, which were placed in cased-hole pre-perforated wells.
This paper investigates reservoir quality assessment as well as the stimulation efficiency and productivity enhancement of the Sidri Field. It investigates two different completion methodologies to investigate operational efficiency and productivity enhancement of the Sidri Field in the Sinai Peninsula. The comprehensive evaluation will involve discussions of candidate selection, pre-job design alongside comparisons of timeline, cost, zonal isolation, and productivity to help serve as a guideline for operators in the region looking to enhance their completion approach.