bluuebunny/crossref_metadata_2025_split huggingface dataset:
Risk-Free Delivery of Production Chemicals to Deepwater Oil and Gas Fields
Authors: Grutters Mark , Kuzniarek Justin , Jackson Steven 
Published: November 2020

Abstract
Uninterrupted delivery of production chemicals through umbilicals and capillary strings is absolutely critical for oil & gas operators to avoid build-up of solids in wells and flowlines as well as excessive corrosion of the subsea infrastructure. However, flaws in design, poor installation and maintenance of subsea chemical injection systems, or deviating from operational procedures can cause blockages or leaks.
In this paper two case histories will be provided about chemical injection failures. One failure is related to the formation of gas hydrates in the umbilical due to malfunctioning of an injection valve. The other failure occurred due to delivery problems due to high viscosity. Some information will be shared on why these failures could occur and improvements to the qualification process to avoid this in the future.
Several deepwater operators and service companies developed chemical selection criteria based on the guidelines and recommendations from the 2007-2011 "Blockage Avoidance in Subsea Injection and Control Systems" (BASICS) JIP. Many companies have incorporated these recommendations in a subsea qualification process for deepwater chemicals. Chemical injection failures often relate to mechanical failure or limitations to the subsea injection system rather than to the chemical itself – especially after the JIP recommendations were incorporated. However, a qualified chemical product may cause injection problems if a holistic review of the application is lacking. The case histories will demonstrate the criticality of collaboration between the operator, engineering company and suppliers; sharing system information and operational conditions avoids costly mistakes.
The complexity of deepwater chemical qualification is to design experiments that reliably predict field performance from lab testing. Moreover, failure mechanisms, e.g. corrosion, gunking and polymerization, are slow processes and laboratory experiements have to be accelerated to much shorter timescales for chemicals to be deployed quickly in the field to treat the risks they are designed for. With the deepwater boundaries getting pushed to new limits some of the laboratory testing has to be redesigned to assess the risks for these extreme conditions. We will, therefore, provide an overview of the different kind of tests that are required and add some considerations on how the tests can be modified and how the test results are best interpreted for field application.
Effects of CO2/Rock/Formation Brine Parameters on CO2 Injectivity for Sequestration
Authors: Md Yusof Muhammad Aslam , Ibrahim Mohamad Arif , Idress Mazlin , Idris Ahmad Kamal , M Saaid Ismail , Mohd Rodzi Nadhirah , Mohsin Saiful , Azhari Awangku Matali Awangku Alizul 
Published: November 2020

Abstract
CO2 injection into saline aquifer has gained attention as an effective technique to permanently secure the produced anthropogenic gas from high CO2 gas field in South East Asia region. However, problem such as injectivity impairment has been faced by operators and researcher has attributed the interactions between CO2-brine-rock to be the major cause. This research investigated the effect of CO2 displacement schemes, reservoir rock permeability, formation brine type and concentration on CO2 injectivity. CO2 coreflood experiment with detailed characterization of the rock and effluent produced are presented. Various core samples which represent low and high permeability of typical geological storage for sequestration were selected. The core samples were analyzed using X-Ray Fluorescence (XRF), X-Ray Powder Diffraction (XRD) and Field Emission Scanning Electron Microscopy equipped with Energy Dispersive Spectroscopy (FESEM-EDX). Then it was saturated with synthetic formation brine composed of 6,000 ppm, 30,000 ppm or 50,000 of either Sodium Chloride (NaCl), Potassium (KCl) or Calcium Chloride (CaCl2). Lastly, core samples were injected by either supercritical CO2 (scCO2), CO2-saturated brine and combination of CO2-saturated brine and scCO2 and the pressure drop profile was recorded. Fines were then being separated from the collected effluent for further analysis. FESEM images of the pre- and post-injection core samples were compared to assess physical changes. Results indicated that CO2 injection scheme, flow rate, brine concentration and initial rock permeability are the principal factors that contribute to the porosity and permeability alteration of the core samples. Moreover, FESEM-EDX analysis of the produced fines shows precipitated salt, silica grain and kaolinite were migrated during scCO2 injection. It is suggesting that minerals were dissolved and precipitated, resulting in detachment of silica particles and formation of new secondary minerals, some of which plugged the pore spaces reducing the permeability. In addition, core saturated with CaCl2 brines are the only samples that showed permeability improvement after CO2 flooding experiment.
An Engineering Approach to Optimise Rate of Penetration through Drilling Specific Energy
Authors: Al-Rubaii Mohammed Murif , Gajbhiye Rahul. N , Al-Yami Abdullah , Haq Bashirul , Glatz Guenther , Al-Awami Mohammed 
Published: November 2020

Abstract
Continuous efforts are made in drilling engineering to identify and develop advanced tools and technologies to maximize rate of penetration (ROP). Optimization of ROP has a major impact on both the reduction of the cost in terms of cost per foot and well delivery. Numerous correlations, methods, designs, models, and tools for ROP optimization are available in literature but rarely are applied in drilling operations. This paper introduces a robust methodology aiming to optimize the rate of penetration without inducing any associated wellbore stability problems.
The objective of this paper is to detail the methodology and the effectiveness of the technique introduced. We report performance indicators for a trial well drilled using the novel approach and compare the findings with a conventionally drilled offset well. The drilling parameters for a challenging horizontal hole section were collected and analyzed to evaluate their effect on ROP performance. The drilling parameters selected are from corresponding hole sizes, formation and mud types with respect to the offset well for a consistent comparison. The proposed approach contributed to an enhanced well drilling performance by more than 40% and was instrumental in mitigation of stuck pipe incidents.
In this paper, we introduced and verified a novel technique to maximize the rate of penetration (ROP) by optimizing the drilling parameters (RPM and WOB). As long as the CCA is less than 0.05, the proposed workflow in this study can be used to determine an optimized ROP in conjunction with a minimized DSE yielding ideal RPM and WOB values thereby reducing the cost per foor drilled. Evidence of the efficiency of the proposed procedure is provided by comparing the ROP and DSE measured for a horizontal section drilled employing the technique with data for an offset well drilled in a non-optimized fashion. Compared to the latter case, we reported a 44% improvement in ROP and a 48% reduction in DSE.
Transforming Offshore Oil and Gas Production Platforms into Smart Unmanned Installations
Authors: Tan Jaime HuiChoo , Roberts Brian , Sundararaju Prabakaran , Sintive Christophe , Facheris Laurent , Vanden Bosch Joel , Lehning Virginie , Pegg Mathew 
Published: November 2020

Abstract
Offshore oil and gas production platforms are complex and hazardous process facilities which are usually attended by a permanent human crew to run the daily operations. In recent years, the oil and gas industry has demonstrated strong commitment to change this traditional operations approach and move towards inherently safer philosophy in offshore facilities design and operations, i.e. removing human crew from the facility and operating it remotely from a safe location over extended periods.
This paper aims to demonstrate the readiness of robotics technologies coupled with digitalization technologies in process control and facility automation in transforming offshore oil and gas production platforms into smart unmanned installations. This paper is focused on the application of smart robotics, with highly dexterous capabilities and equipped with multiple sensing instruments, in maintaining an offshore oil and gas production facility in full operation without a permanent human crew, and with planned visits to the platform at 12-week intervals, in a case study. The robots are developed to be remotely operated from an onshore control center and/or may be programmed to function autonomously for routine missions on the offshore facility.
Overcoming the Oil Base Mud Barrier for High Resolution Imaging While Drilling: An Industry First Technology Advancement for Borehole Image Acquisition
Authors: Shrivastava Chandramani , Maeso Carlos , Wibowo Vera , Auchere Jean-Christophe , Amir Irlan 
Published: November 2020

Abstract
New sub-surface challenges are encountered everyday as the industry drills more in complex geological and operational settings; and smarter applications are being made with new and more efficient technologies for real-time solutions. And, one of the remaining frontiers, that of real-time, high-quality, multi-applications borehole images while drilling with oil-base mud (OBM) has been overcome with deployment of multi-sensor, multi-physics measurements providing the highest resolution data. A new feature-based compression technology is developed to transmit the geological feature-rich data in real-time, even with limited telemetry; enabling real-time decision making.
Logging-while-drilling (LWD) imaging in OBM started from low-resolution density images with limited meaningful applications; even ultrasonic imaging introduced lately was not able to consistently unmask the geological information. Industry-first technology advances for borehole image acquisition in OBM were made possible with the deployment of ground-breaking integration of multi-sensor, multi-physics technologies of electromagnetics and ultrasonic on one small sub. Four operational frequencies of electromagnetic measurements are used for resistivity-imaging to cover a wide resistivity range in the sub-surface, whilst ultrasonic images are made at two frequencies to help optimize the imaging for varying standoff and rugosity during drilling. This enables feature identification of subtle variation in texture, structure, sedimentation and diagenesis style; most of the sedimentary structures imaged on the apparent resistivity images made from electromagnetic measurements whilst the drilling-related features manifesting themselves more visibly on ultrasonic images.
Results of this technology are discussed with various examples acquired during the early deployment; examples showing the plethora of information available in real-time enabling drilling optimization to hydro-fracturing decisions. A comparison has also been made with established wireline technology for validation of the LWD images in some of the examples. With more applications being developed to integrate this data, this opens up new avenues for geosciences and drilling solutions while drilling.
This new technology overcomes the OBM barrier for high-resolution imaging while drilling, and coupled with feature-rich data transmission in real-time enables real-time decision making.
Integration of Wireless and Remote Monitoring in Condition Monitoring Systems for Offshore Applications
Authors: Tanabe Satoru , Prasertsintu Thanasin 
Published: November 2020

Abstract
Offshore platforms often contain mission-critical equipment that should be monitored on a real-time basis, but because of the hazardous and hard-to-reach environments they are located in, there are always challenges to the conventional method of using wired sensors and on-site monitoring. The wireless sensor and remote monitoring technologies, introduced in this paper, enables practical condition monitoring to detect early signs of change in machine conditions with limited investment and optimize their overall maintenance program and workflow remotely, for rotating assets on offshore platforms.
The system introduced in this paper is comprised of the wireless sensor and software with remote monitoring capability. The wireless sensor is able to measure key condition monitoring parameters including dynamic vibration data to detect early sign of change in machine condition and support to identify its failure mode as well. Because of its wireless design, initial investment of installation can be minimized. The software interface is designed to provide adequate information to complete asset condition assessment and root cause analysis of the machine failure when it occurs. The software is capable of monitoring assets located on multiple platforms through the network. The data provided by the software can be utilized not only for machine health monitoring but also for reliability assessment, reviewing effectiveness of maintenance at pre & post maintenance or advanced analysis by using the latest technologies, ultimately optimizing maintenance program for those assets observed based on the data captured by the system.
The software is designed to comply with network security requirements of today to establish secure network connections for remote access from an on-shore facility, making condition monitoring data readily accessible, and remotely for analysis by a qualified diagnostic team. This feature allows offshore platform maintenance engineers to plan maintenance tasks effectively. What maintenance tasks need to be performed for which assets, which probable tools and materials are needed will be determined and organized in advance before a maintenance resource is mobilized based on actual data measured the assets. This could potentially reduce the number of trips to remote area where the assets are located such as unmanned platforms, minimize time to be spent by the maintenance resource per visit, optimizing overall maintenance program without compromising asset reliability, quality of maintenance, and safety risk.
This new system with the wireless sensor presented in this paper does not only enhance the visibility of asset condition, but also possible to improve the effectiveness of maintenance tasks and optimize the overall maintenance program with reduced safety & environmental risks for assets on offshore platforms.
Real Time Online Hydrate Monitoring and Prevention in Offshore Fields
Authors: Azman Syahida Husna , Abu Bakar Afdzal Hizamal , Abdullah Nur Hidayah , Jamaluddin Muhamad Nasri 
Published: November 2020

Abstract
Hydrate blockage had caused impeded flow in offshore pipelines and resulted production stoppage and significant economic loss. Hydrate blockages can occur very rapidly especially during winter conditions. The amount of inhibitor used need to be frequently revisited to ensure sufficient inhibition due to temperature change and other affecting parameters. The objective of this study is to provide an online monitoring of hydrate formation for four offshore pipelines to ensure sufficient mono-ethylene glycol (MEG) inhibition. It also provides an integrated operations monitoring that can be accessed anywhere and anytime. The system can provide early warning of hydrate formation to avoid blockage and production disruption.
There are three parts in this study:-Part 1-Hydrate Prediction Model, Part 2-Integration with PETRONAS Integrated Operations platform and Part 3-Hydrate Monitoring and MEG Tracking. In Part 1, fluid composition for each pipeline was used to develop the hydrate curve. The minimum inhibition concentration model was built using mathematical curve fitting at maximum operating pressure under varying temperature. Another computational model was built to determine the MEG injection rates based on various parameters such as water cut, lean MEG concentration and safety margin. The model was then integrated with both real-time and sporadic data and run on predetermined schedule on the Integrated Operations (IO) platform. Part 2 ensures the critical parameters are linked to the hydrate prediction model and provide results such as hydrate operating condition, minimum inhibitor concentration requirement and MEG injection rates. In Part 3, real-time hydrate monitoring has to be readily accessible to everyone via a mobile compatible web interface. Actual MEG concentration vs minimum MEG concentration is analyzed to represent adequacy of current MEG injection rates. Further analysis can be done to predict the MEG recovery plan by tracking MEG inventory.
The online hydrate monitoring is frequently used by offshore operations in their daily meetings. The system assists in advising the amount of MEG injection rates and ensure sufficient inhibition for all of the pipelines. From available trending, operator can optimize the MEG rates based on current operating temperature, pressure, watercut and relevant parameters. This online monitoring is useful to avoid re-occurrence of hydrate blockage in the pipelines and to optimize MEG usage.
There are many hydrate inhibition technologies in existence, but this is the first in the world of its kind which is simple, innovative and inexpensive method to monitor the pipeline from entering hydrate region in real-time, which can be conveniently accessed anytime and anywhere. Not only the system had prevented production loss in millions of dollars, it also saved operating cost of MEG which may cost operations several million dollars.
Augmented Machine Learning Approach of Rate of Penetration Prediction for North Sea Oilfield
Authors: Hong Youngjun , Yoo Jaeyoon , Wang Shinjo , Yoon Sungroh 
Published: November 2020

Abstract
Rate of penetration (ROP) refers to penetration speed in drilling process, which is directly related to drilling cost and time. Therefore, ROP optimization by choosing the best drilling parameters has been an important issue in drilling fields to cut cost and spend less time in drilling. To optimize ROP in an accurate and efficient manner, an accurate ROP prediction should precede. An accurate ROP prediction makes optimizing drilling parameters possible, which leads to cost-effective drilling.
Recently, the development of machine learning brings new insight into various fields including petroleum engineering, where conventional and domain knowledge-based equations were dominant. Particularly, leveraging deep neural networks that are highly capable of representing complex relationship of features has shown promising results in various tasks and fields such as computer vision and language modeling.
In this paper, we present a novel machine learning model for the ROP prediction. We focused on developing a model which is trained with offset well logs data to predict ROP of unseen target wells within the same field. By utilizing the state-of-the-art deep neural networks specialized in sequential data process, we show that the data driven ROP prediction significantly outperforms conventional ROP prediction methods.
In addition, we utilized a stacked generalization ensemble method that integrates several ROP prediction models to produce an optimal ROP prediction model. We also show that our stacked ensemble model can improve prediction performance of a single model.
Ten-Year Pilot Test of Steam and Flue Gas Stimulation for Offshore Heavy Oilfield
Authors: Han Xiaodong , Zhong Liguo , Tang Xiaoxu , Wang Hongyu , Zou Jian , Wang Qiuxia , Liu Hao 
Published: November 2020

Abstract
There is large amount of heavy oil resources whose oil viscosity over 350 mPa·s in Bohai Oilfield and their producing degree and production performance are relative low for lacking of effective exploitation technology. For seeking effective production technology for heavy oil exploitation, the steam and flue gas co-injection technology is proposed and studied. Considering the limited platform space, miniaturized steam and flue gas generator is designed and applied for field test. Besides, integrated matching technologies such as sea water desalinization, heat insulation, anticorrosion are also studied and developed. The south part of NN Oilfield was selected to be the target oilfield and the first thermal pilot area in Bohai Oilfield in 2008. Until now, the pilot in NN Oilfield has lasted for 10 years, nearly 30 well times of stimulation has been conducted and part of these wells has entered the third stimulation cycle. Compared with natural energy production, peak oil production and periodic oil production of thermal production are both greatly improved. With the increase of the stimulation cycle, the gas channeling problem has bad influence on the production performance, and the production rate declines rapidly. Steam flooding might be an effective replaced technology after huff and puff for further enhancing oil recovery of offshore heavy oilfields.
Research and Application of Nanometer Dispersion Oil Displacement Technology
Authors: Tian Miao , Xu Guorui , Wang Tao , Jia Yongkang , Feng Qing 
Published: November 2020

Abstract
With most oilfields at Bohai Bay enters into middle and late waterflood development stage, the oilfields have high water cut but low recovery degree. Chemical methods of enhanced oil recovery (CEOR) such as polymer are applied. However, the degradation and retention of polymer inside reservoir make it less attractive. Moreover, due to serious over-standard injected water quality or low-medium reservoir permeability, the CEOR are confronted with many challenges such as high injection pressure, difficulty in injection. Therefore, a new oil displacement technology of nanometer dispersion with good injectivity, dispersion stability and strong oil displacement characteristics is proposed. The focus of this study is to indentify the stimulation mechanism of nanometer dispersion and reveal its possibility for EOR in Bohai oilfield.
A set of experiments, including interfacial tension, contact angle, wettability, viscosity and core displacement, were conducted to investigate the effects of nanometer dispersion on the recovery of crude oil in Bohai Q oilfield. It was observed that nanometer dispersion fluid at the concentration of 0.5 wt.% can: 1) reduce the oil-water interfacial tension to 10−3 level; 2) decrease the oil-water contact angle from 55° to 9 °; 3) reduce the crude oil viscosity from 259 cp to 132.8 cp, with a viscosity reduction rate of 48.7%; 4) improve the oil washing efficiency of oil sand to as high as 79.1%; and 5) improve the oil recovery rate of core plugs by 25%∼46% compared with water flooding.
The lab-scale test was then extended to field-scale test. A pilot field test was conducted in Bohai Q oilfield, which was very successful, and obvious effect on controlling water and increasing oil production was obtaineded, with an oil increment of 6158m3. Laboratory and field test results show that the nanometer dispersion, as a new EOR technology, could considerably increase oil recovery and has a wide application prospect.