bluuebunny/crossref_metadata_2025_split huggingface dataset:
Screening Study for an Optimal Horizontal Section Length of a Maximized Reservoir Contact Well
Authors: Virk Muhammad Muneeb , Al Hammadi Khaled Eissa , Recham Reda , Assreti Elamari 
Published: November 2020

Abstract
Reservoir development using Maximum Reservoir Contact (MRC) wells has taken significant leaps and bounds in the oil and gas industry in the last fifteen years with horizontal well length of more than 2500 meters. MRCs, a breakthrough in drilling technology, has enabled us to drill long horizontal producing or injecting sections, especially in low permeability or tight oil bearing layers. In such reservoirs, with the increased reservoir contact surface area, the wells are able to produce and inject at higher rates with lesser drawdowns. This increased productivity index helps to delay the gas and water breakthrough, reduce the conning and improve the GOR/Water-cut response. Hence, improving the sweep efficiency and the ultimate recoveries. On the other hand, MRC wells could potentially help to address the subsurface and surface congestion challenges especially in brown fields by reducing the overall development well count by 2 to 3 times.
The production gain from long horizontal section is limited by the pressure drop within the well bore from toe to heel. Therefore, there is a technical limit to the production gain that can be achieved by increasing the horizontal section length. Drilling beyond this limit will incur cost without any prominent production gains. Hence, there would be a techno-economic limit to the optimal MRC well length.
This paper present the screening study conducted to determine the optimal well length for an MRC well from a techno-economic point of view. A mechanistic fine gridded sector simulation model is used for this study. The MRC wells are segmented and considers the well bore hydraulic calculations for all the pressure loss elements. Different MRC well length scenarios are considered to compare the sweep efficiency and ultimate recoveries. The cost to benefit screening analysis is conducted for various MRC lengths, in relation with their associated costs and dynamic performance.
The techno-economic analysis indicates that the MRC well length of around 10K ft is the optimal. Beyond this length, there is a marginal increase in incremental NPV and the relative difference in reduction of UTC gets minimal.
The paper highlights the importance of a value assurance study conducted for the MRC well lengths that can potentially be considered for optimal field development/re-development. Each reservoir with its specific rock and fluid characteristics would worth this type of screening study with the help of numerical simulation tools. The choice of MRC well length would eventually have a great impact on the field development economics.
Deep Learning Approach to Predict Rheological Behavior of scCO2 Foam Fracturing Fluid Under Different Operating Conditions
Authors: Ahmed Shehzad , Alameri Waleed , Ahmed Waqas , Khan Sameer 
Published: November 2020

Abstract
CO2 foam as a fracturing fluid for unconventional reservoir has been of huge interest due to its potential in solving various challenges related to conventional water-based fracturing. The rheological property of CO2 foam is a key factor controlling the efficiency of fracturing process and it is strongly influenced by different parameters such as foam quality, temperature, pressure and shear rate. The quantification of these parameters under reservoir conditions leads to the design of optimum injection strategy. However, the traditional modeling approaches are unable to provide fast and accurate prediction while considering combined effect of all these parameters. Here, we proposed a data driven approach based on supervised deep learning to estimate rheological property of CO2 foam as a function of foam quality, temperature, pressure, and shear rate. We exploit deep neural networks (DNNs) that are trained to learn the complex nonlinear aspects of the data. For the data generation, we performed a series of experiments for CO2 foams by varying different process variables. CO2 foams at different qualities were generated using conventional surfactant in a flow loop system and foam viscosity measurements were performed at HPHT under wide range of shear rate. The architecture of DNN was optimized to accurately estimate the foam apparent viscosity for given foam quality, temperature, pressure, and shear rate. The predictive capability of designed network is found to be significantly high, analyzed by regression coefficient approaching unity, low mean squared error, and low average absolute relative deviation (≪ 2.5%). The designed neural network allows robust and accurate prediction of foam apparent viscosity at different foam qualities under various reservoir condition, which demonstrates its practicality for CO2 foam projects for fracturing unconventional reservoirs.
Mechanism of Water Imbibition in Organic Shale: An Experimental Study
Authors: Zhao Zhihong , Tao Liang , Zhao Yuhang , Halifu Mirinuer , Chen Chi 
Published: November 2020

Abstract
Organic shale is characteristics of multi-component and multiple pore, making flow mechanism of water imbibition in shale very complicated. In this study, firstly, the micro pore structure and pore size of shale were quantitatively characterized by scanning electron microscope. Secondly, a new experimental device for spontaneous imbibition of water under the conditions of formation temperature and confining pressure was designed. Finally, A new imbibition index was proposed to evaluate the contribution of multiscale pores to shale water imbibition. The experimental results of shale samples from the Longmaxi formation (LF) in the Sichuan Basin indicate that the water imbibition in shale was divided into three stages: diffusion stage, transition stage, and balance stage. The diffusion stage was the stage when most of the water imbibition takes place, and the transition stage was the time when the induced micro-fractures were generated. The water imbibition of shale was inhibited under the condition of temperature and pressure of shale reservoirs. Compared with the conventional spontaneous imbibition, the capillary pressure and osmotic pressure were the main imbibition forces in the transition stage. The micro-fractures induced by hydration provide a new channel for water imbibition and promote the further improvement of imbibition capacity. The research results provide effective guidance for the optimization of flowback system.
Optimal Production Offshore Satellite Platform
Authors: Rentel Gustavo 
Published: November 2020

Abstract
This document provides information on activities to develop an Optimal Production Offshore Satellite Platform (OPOSP). The objective of the OPOSP is to make the process more economical, safe, efficient and friendly to the marine environment.
The project is sub-divided into 8 sub-projects that are associated with research groups to create new products, as follows: Compact Valves (CV), Multi Way Selector Valve (MSV), Well testing (WT), Compact Cyclonic Separation (CCS), Multi Phase Pumps (MPP), Flare and relief, Treating waste and water management systems, non-Conventional Energy System.
All the previous sub projects go through a development process, which includes the definition of the objectives to be achieved, the study of the market and existing solutions, and the application of standards and specifications. Thereafter the process continues to develop one or more prototypes, which will be subjected to analysis, modelling, simulation, design, component level testing, manufacturing, and system-level testing and integration.
In this document we present the results obtained in each of the subprojects, beginning with the definitions and equipmet development; we then continue to presenting the data and results obtained, and finalize with the conclusions and recommendations.
Alternating N2 and CO2 Injection as Prospective Technique for Delaying CO2 Breakthrough During During Enhanced Gas Recovery in Consolidated Rocks.
Authors: Mohammed Nuhu , Abubakar Abbas Jibrin , Enyi Godpower Chimagwu 
Published: November 2020

Abstract
The use of carbon dioxide (CO2) for simultaneous methane recovery and CO2 storage is gaining recognition globally within the oil and gas industries. On the other hand, most of the residual natural gas recovered during the EGR process is highly contaminated with the injected CO2 due to their nascent miscibility nature, resulting in premature breakthrough. In this study, N2 gas was used as a buster to mitigate such early mixing between the CH4 and CO2. The experiment was administered at reservoir conditions of 40oC temperature, 1500 psig of pressure, the optimum injection rate of 0.4ml/min, and at varying N2 cushion volumes (8-36 cm3) using Bandera gray as the porous medium. Further experimental tests were administered to study the effect of this technique on connate water salinity with 5-20% water salinity been considered. The increase in buster gas volume was in direct proportion to delayed CO2 breakthrough, with the maximum at 36cm3 buster volume. This breakthrough occurred at 177 minutes which is 110min additional delayed than the conventional CO2 flooding with a breakthrough time of 67 minutes. This was due to the high shielding barrier inhibited by nitrogen, making it difficult for the CO2 to dispersed itself and mixed with the nascent natural gas resulting in delayed breakthrough as it plumes transverses into the CH4 during the displacement process. Furthermore, a poor performance was observed with the inclusion of the connate water salinity, especially at 20% wt. This was because the free pore spaces were already occupied by connate water molecules prior to the cushion gas injection which hinders its economic potential application.
Reduction of Solid Corrosion Product as the Main Component of Fouling on the Gas Compressor by Improving 3 Phase Corrosion Inhibitor Performance
Authors: Riza H.R Akhmad , Pribadi Mohammad 
Published: November 2020

Abstract
The two Field gas compressors are categorized as critical equipment. After 5 years of operation a serious fouling on the compressor’s impeller was identified and resulted in high vibrations. The dominant fouling component was solid corrosion particulate. The objective of this paper is to discuss the effectiveness of improved corrosion inhibition program to minimize the dominant fouling component and make the corrosion inhibitor to be carried over to the downstream of suction scrubber.
The effort to reduce corrosion product in the main gas line was done by optimizing 3 phase corrosion inhibitor performance injected upstream of the compressor suction scrubber. A series of laboratory tests on selective corrosion inhibitor products was undertaken to measure the effectiveness of some inhibitors to reduce the corrosion rate whilst also being carried over to downstream of the compressor suction scrubber. Some additives such as Iso-Propyl Alcohol (IPA), Glacial Acetic Acid (GAA) and Mono Ethylene Glycol (MEG) on the corrosion inhibitor were also included to improve some key parameters such as volatility, emulsion tendency and chemical stability.
Significant improvements were observed with the modified 3 phase corrosion inhibitor which was carried over to the downstream of suction scrubber and which did provide improved corrosion protection to the main gas line and ultimately did reduce the solid corrosion product which had been seen to be the main component of the fouling on the compressor’s impeller.
Improvement of corrosion inhibitor performance by adding some additives effectively can improve the key performance and the capability to be carried over to the downstream of the suction scrubber. The efforts to improve the corrosion inhibitor performance resulted in a reduction of the corrosion rate and solid corrosion product as the main component of fouling which directly contributed to improved compressor reliability.
The Potential of N2 as Cushion Gas on Dispersion Coefficient of SuperCritical CO2 in Sandstone Core Plug During Enhanced Gas Recovery by CO2 Injection
Authors: Mohammed Nuhu , Abubakar Abbas Jibrin , Enyi Godpower Chimagwu 
Published: November 2020

Abstract
Despite the several kinds of literature on the dispersion behaviour of supercritical CO2 in CH4 at conditions relevant to enhanced gas recovery (EGR), studies have so far limited in keeping this parameter as low as possible. This study aims to highlight, experimentally, to determine the effect of N2 as cushion gas on the dispersion coefficient in consolidated sandstones core plug under reservoir conditions applicable to EGR. A laboratory core flooding experiment was carried out to simulate a detailed process of an unsteady state methane displacement in Bandera gray and Bentheimer core plugs at reservoir conditions of 40oC temperature, 1500 psig of pressure, the optimum injection rate of 0.4ml/min, and at varying N2 cushion volumes (8-36 cm3). Further experimental runs were carried out to investigate the effect of high CO2 injection rates (0.6-1.2 ml/min) on the longitudinal coefficient of dispersion as it plumes transverses into the core plugs during the EGR process. The coefficient of longitudinal dispersion declines with raises in cushion gas volume, hence the higher the amount of N2 cushion volume the less the dispersion of CO2 into CH4. This is due to the high shielding barrier inhibited by nitrogen, making it difficult for the CO2 to dispersed itself and mixed with the nascent natural gas resulting in delayed breakthrough as it plumes transverses into the CH4 during the displacement process. The inclusion of N2 as cushion gas prior to CO2 injection recorded the highest decline at 36cm3 cushion volume, presenting a 48 and 28% reduction in longitudinal dispersion coefficient for Bandera and Bentheimer core samples respectively, compared to that of conventional/traditional CO2 injection (with zero cushion volume). Recording lower nascent CO2-CH4 mixing resulting in less natural gas contamination and more storage volumes. Also, a reverse phenomenon was observed when the CO2 injection rate was increased from 0.6-1.2 ml/min due to the high diffusion rate of CO2 at higher interstitial velocities, resulting in a rapid increase in dispersion coeffient and indirectly high widespread contamination of the remaining natural gas.
Slim Hole Multi-Zone Sand Control Completion in an Over-Pressured Gas Field: First Eni Worldwide Application
Authors: Andrea Salomone , Giovanni Ferrara , Emanuele Pederiva , Valeriano Gioia , Antonio Concas , Valerio Tomassetti , Hodcroft Kenneth , Sendel Honore , Roche Jonathan , Agee Daniel 
Published: November 2020

Abstract
This paper details a field application of a well-known technology for sand management (Inside Casing Gravel Pack - Frac&Pack), deployed for the first time in Eni for such a complex configuration, in a challenging environment with surface equipment limitation (jack up rig). The job has enabled exploitation of residual reserves in of a mature gas field in Adriatic Sea.
This was a dual completion with two 2 3/8" production strings, producing a total of six gas bearing zones. The topmost zone produces from the short string while the rest of the zones produce through the long string.
Some of the challenges were:
Narrow screen-casing clearance causing increased risk of bridging and early screen out Small ID tool and workstring resulting in high friction and requiring high horsepower Limited rig space for pumping equipment
All six zones were successfully executed using visco-elastic surfactant fluid formulated in 14.8ppg Calcium Bromide brine. The use of the high-density carrier fluid enabled using low horsepower equipment. The well was completed within the expected timeframe and cost with no service quality issues. The well's production has exceeded expectations.
Characteristics of the field, technical issues, results and analysis are presented.
Innovative Internal Inspection Using Robotic Inspection without Man Entry
Authors: Karuppan Kalimuthu , Al Tenaiji Abdulla , Al Maskari Juma 
Published: November 2020

Abstract
Pressure vessels used in the petrochemical industry inspected manually by people working inside the vessels, which is a very time consuming operation in a potentially hazardeous work environment. As per by Van Den Bos, Strand, Mallion et al (2016) "The PETROBOT project formed and funded by EU with the aim to bring together inspection methods and remote delivery to reduce risks and cost involved in inspection of pressure vessels and brought together the complete value chain, from robot and inspection technology providers to inspection service providers and end-users. In the PETROBOT project, robotic solutions developed for the internal inspection of pressure vessels (FAST platform, BIKE platform and Snake arm) and storage tanks (tank robot). Several aspects related to safe deployment and retrieval of the robots through side and top manway in horizontal and vertical vessels were tested. All the robots were able to enter in all types of vessels and demonstrated an acceptable level of operational readiness. The Robotic technology now sufficiently developed as a platform to perform the inspections using established techniques."
ADNOC CEO has launched Oil & Gas 4.0 in the year 2019 and stated that Oil and Gas 4.0 means rethinking how our industry adopts and applies technology, connects with non-traditional partners, shows environmental leadership and most importantly attracts and retains talent. We as, ADNOC Gas Processing Technical Services Engineering division inspired by the ADNOC CEO's speech and adopted introduction of innovative technology in every sphere of technical field. We choose to explore the possiblitity of the introduction of drones, robotics and other technology that are increasing efficiency and productivity while protecting the environment in all stages of energy production.
ADNOC Gas Processing has conducted Corrosion and Inspection forum in 2019 as a part of digitasation by inviting leaders in the NDT field to show cause the available latest technology. During the forum, we could explore several advanced NDT techniques including Drones, robotics, helmet mounted cameras and wireless UT thikness monitoing devices. With the advancement of technology, drones once predominantly used for patrolling highways and delivery of the foods were used extensively for visual inspection of elevated structures (stacks) and robotics are used to inspection pressure vessels and storage tanks with out necessity of man entry and thus avaiding the human exposure to the hazdous evironments.
Subsea Pipeline Temporary Decommissioning & Recommissioning for an Emergency Repair
Authors: Thomer Mark 
Published: November 2020

Abstract
The paper presents how Dolphin Energy's Emergency Pipeline Repair System ‘ASSIST’ (Advanced Subsea Intervention Support & Technology) has addressed the challenges of being ready to decommission and recommission a large diameter high pressure gas pipeline during a pipeline repair in the shortest possible time, while also protecting onshore assets. The challenges in temporary decommissioning and recommissioning of a large size high pressure gas pipeline are demanding, due to the complex technical requirements and the need to intervene quickly. This case study shows how Dolphin Energy has tackled this technical challenge by developing bespoke subsea tooling not available from the market. At the same time, the company has balanced its commercial responsibilities by ensuring third parties provide other tools and resources required during an intervention. This means Dolphin Energy can study available resources from contactors' over the long term, ensuring resources are available as and when needed.
To address this challenging technical requirement, ASSIST has implemented the following three solutions:
Development of a unique subsea launcher & receiver covering Dolphin Energy's 48" and 36" subsea pipelines; this allows the pipe to be decommissioned and isolated on the seabed, thus enabling the repair to proceed in a dry condition without the need to recover the inventory of a flooded pipe at one of the terminals. The subsea tool does not require extensive subsea preparations Procedures and processes to allow decommissioning to start in the shortest possible time have been developed An on-call LTSA Provider, capable of providing equipment and personnel to meet the demanding requirements of decommissioning and recommissioning large gas pipelines. This includes regular monitoring of market capabilities and availability of equipment and personnel
By implementing these three steps, we ensure that decommissioning and recommissioning of the pipeline does not become ‘bottle necked’. The impact on asset integrity has also been minimized.
Three-Phase Compositional Simulation for Asphaltene Precipitation Using CPA-EOS with a Realistic Well Model Representation
Authors: Zidane Ali , Firoozabadi Abbas 
Published: November 2020

Abstract
Reservoir simulation of asphaltene precipitation especially around the wellbore is of importance in relation to well productivity. In this work we demonstrate the importance of accurate representation of the wellbore in simulation of asphaltene precipitation compared to a simplistic representation of the well. A simple representation of the well with a sink/source grid overestimates the deposition and underestimates the production rate. A more physical representation of the wellbore geometry provides a better description of the physics and an accurate estimation of the deposition. Cubic equations of state that are widely used in commercial simulators are not accurate in describing asphaltene-rich phase. We use the cubic-plus-association equation of state (CPA-EOS) in the simulation of three-phase compositional flow where one of the phases may be rich in asphaltene content. In absence of the asphaltene phase, CPA-EOS reduces to the standard cubic equation. The presented algorithm accounts for both structured and unstructured grids and includes a 3D geometrical representation of the wellbore. The phase fluxes are evaluated with the hybridized form of mixed finite element (MFE). The discontinuous Galerkin (DG) method is used to discretize the mass balance equations.
Development in Non-Metallic Reinforcement of Damaged Offshore Decks Utilising Composite Materials
Authors: McKay Stuart James 
Published: November 2020

Abstract
The conventional repair and rehabilitation of damaged metallic decks in offshore production facilities can prove to be a challenge mainly due to costs, operational impact and potential interruption of production. To overcome these challenges, an innovative repair solution was developed utilising Fibre Reinforced Polymers (FRP's), also known as composite materials, to reinstate the integrity of the damaged decks while avoiding the potential problems and challenges caused by conventional repair methods. In the Oil & Gas industry, using composite materials to repair damaged pipelines and piping systems is an accepted and established method. The popularity of this method has resulted in the development of well-established standards. However, governing standards or codes do not exist at the moment for repairing damaged metallic decks using composite materials, or metallic structures in general for that matter. In the absence of a relevant governing design standard or code being available at the time of writing this paper, a repair solution was uniquely developed and proposed to enhance the reputation of utilizing this method and to prove its capability as a viable repair option. This paper will also detail the approach used for developing this repair solution with respect to material selection, design methodology and qualification testing.