bluuebunny/crossref_metadata_2025 huggingface dataset:
Edukasi Kesehatan Reproduksi Wanita pada Pengajian Aisyiyah Turisari, Desa Palur Kulon, Kecamatan Mojolaban, Kabupaten Sukoharjo
Authors: Ropitasari Ropitasari , Rahayu Rachmi Fauziyah , Ramadhana Retno Tri Astuti
Published: November 2020

Knowledge of reproductive health is not only important for a midwife or general practitioners to have, but it is also very important for every woman as a young woman or a wife or as a mother or prospective mother of her children for the sake of health in order to achieve women's welfare. Reproductive health is a healthy condition in all organ systems, functions and reproductive processes. The aim of this service to educate on women's reproductive health is to provide knowledge in order to behave correctly and accurately regarding the reproductive health of each woman. The method of implementing this activity is through educational outreach by a team of D3 Midwifery lecturers, as paramedics and doctors as a medical team, as well and midwifery students, with written materials and applicative videos. The results of the activity were followed by 105 women who are part of the routine recitation activities of mothers, 50 women of productive age divided into 40 reproductive ages, 4 early adolescents, 6 late adolescents, and also 55 elderly women. Questionnaires were given after the activity, 60 women had good knowledge, 25 women had moderate knowledge and 15 women had poor knowledge about women's reproductive health, the rest did not fill out the questionnaire because of the 5 women over 70 years old. In conclusion, there are still some women who do not understand about maintaining their reproductive health, so this educational activity needs to be carried out periodically.
DIGITAL EDUCATION: OPPORTUNITIES, THREATS, AND CHALLENGES
Authors: Gambo Danmuchikwali Bilkisu , Muhammad Suleiman Muhammmad
Published: November 2020

Digital education is largely an innovation of the last few decades, although it already existed in various forms slightly earlier. Shortly, the educational system environments are anticipated as mitigation to unforeseen natural and artificial pandemics such as Covid-19 in 2020 by the significant changes associated with the digitalization of some portion of the system. This article aims to provide valuable perspectives of ICT and digital education into its future benefits, risks, and challenges of embracing the latest technologies in the digital era, and vast online open courses. We have checked a profound change in the way we interact and generate within the academics with the advent of internet technologies. Globally, the digital revolution favoured open access to information. Classrooms today have a lot of ICT resources nearly all the teachers have made great strides to incorporate digital technology to increase access to information and collaborative activities for the learners.
A Review of 25 Coiled Tubing Well Interventions: Customized Solutions for Bolivian Sub-Andean Basin.
Authors: Hernandez Jovanny A. , Antelo Luis F. , Rodriguez Carlos D. , Antelo Hugo E. , Andrade Juan A.
Published: November 2020

Fields in the Bolivian Sub-Andean Basin are remote, difficult to access locations. The producing zones include the country’s most challenging wells with depths of 26,000 ft. with high pressure, high temperature, high gas cut, cross flow, dog leg severity, well access restrictions, etc. A review of 25 well interventions (WI) delivered to extend the life of those wells is covered, including nitrogen lift, acid wash, milling, shifting sleeves, setting packers, stimulation, Velocity Strings (VS), and fishing.

In order to overcome logistic issues related to wells in remote locations, there were several opportunities to reduce mobilization and operational times without risking HSE or SQ, starting with using skid-based Nitrogen Generation Units (NGU), splitting the Coiled Tubing (CT) string into two sections (then joining the sections at location), and so on. Laboratory tests were performed to analyze the solids recovery of the well in order to choose the correct acid treatment. CT strings were designed to enable pumping at rates 1-2 bpm, without exceeding yield limits, and to reach extended depths.

Lessons learned and best practices, including diagnostic design and customized delivery of operations, compiled in this paper refer to:Logistic improvements for transportationRunning 5,000 m velocity string (VS) jobs with large 2 7/8-in. strings in live well conditionsManaging the corrosion generated by the oxygen associated with the NGU to avoid the formation of a plug inside the CT string during the N2 jobsRunning CT strings in a gas environment with no or minimum buoyancy effect and high well head pressure to reduce the risk of collapseIssues with shifting sleeves. Evaluating the ability of a mechanical shifting tool with low nominal diameter to close large diameter sliding sleevesRunning CT jobs while the well is in production to the processing plant

For well/reservoir conditions that include challenging access to locations, the versatility of customized intervention solutions is a differentiator in today’s industry. The state-of-the-art technology presented in this paper covering 25+ well interventions offers a unique compilation of lessons learned and methodologies.

This paper presents a guide for planning and solving cost-effective well interventions in fields with similar issues. These methods provide operators with customized solutions to increase the value of their assets with collaborative teamwork.
Custody Transfer Tank Calibration Technology
Authors: Patel Sahejad , Parrott Brian , Abdellatif Fadl , Trigui Hassane
Published: November 2020

In this paper a new, semi-automated tank calibration method based on advanced robotics is presented that enables enhanced volumetric measurement and calibration of custody/royalty transfer tanks, with an emphasis on those used in the Oil and Gas Industry. This technology offers relevant facilities a rapid and straightforward solution that offers improved precision over traditionally used methods, thus minimizing revenue losses resulting from inaccurately calibrated tanks.

The technology developed is a semi-autonomous robotic system capable of calibrating upright cylindrical tanks. To achieve this, a magnetic crawler was designed that incorporates a digital, laser-based ruler that collects data about the offset of the tank circumference along the tank height with reference to the tanks’ base circumference. The technology has been developed in accordance with the requirements of API MPMS 2.2B "Manual of Petroleum Measurement Standards Chapter 2—Tank Calibration Section 2B—Calibration of Upright Cylindrical Tanks Using the Optical Reference Line Method" to ensure alignment with industry standards.

The paper will present trials carried out in both the laboratory, during the technology calibration phase, as well as preliminary tests carried out at a tank farm in Jeddah, Saudi Arabia. The feasibility of using a magnetic crawler and the laser ruler configuration was first demonstrated in the lab environment where measurement uncertainty of less than 0.2 mm was documented, compared to the current technique, which yields measurement uncertainties of at least 1mm. As such, due to increased measurement accuracy, the technology enables consequential calibration of tanks every 2 years as opposed to every 5 years using existing solutions. Apart from the measurement accuracy improvement, this method significantly reduced the total time required to carry out the calibration measurements, increasing the efficiency of the process and reducing the down-time of the asset. Other advantages are based on the digital nature of the technology that simplifies data storage, thus allowing significantly more data to be captured. Finally, remote control of the robotic solution enhances operator safety as it eliminates the need for operators to perform calibration activities at elevated heights such as the roof of the tank.

The work performed and presented in this paper demonstrates a novel application of robotics in the Oil and Gas Industry that directly impacts operational efficiency while enhancing safety and minimizing revenue losses. Globally, the current lack of accurate and efficient calibration methods impacts the efficiency of the crude supply chain. The work presented here provides a suitable and cost-effective solution to enhance value realization from the sale of liquid petroleum products.
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

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

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

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

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

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

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

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

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

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

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

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

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.
Shift Handover: A Key Link to Process Safety and Operation Integrity
Authors: Viswanathan Rajesh , Mohamed Saleem Babar , Longford William , Kumar Anil , Hamad Al Saeedi Tareq , Al Harbi Mosleh , Hamad Al Shamsi Marwan , Hamad Al Junaibi Bader , Bamazahem Faizal Ahmad , Janahi Mohammed Ibrahim
Published: November 2020

Shift handover is one of crucial process of process plant operations and historical data revealed many of the industrial accidents resulted due to incomplete and poor handover. ADNOC Onshore recognized the need for digitalizing the shift handover. In 2017, Bab Gas operation conceived the idea to be implemented within one control room and later in 2018 the idea was expanded by TC-Integrity & Operation Excellence (TC I&OE) to standardize and implement the E-log in all fifteen ADNOC onshore control rooms to assure the safety of its people and assets, in compliance with ADNOC COP-Operating Integrity. TC I&OE, BAB GAS asset and IT collaboratively worked together in a structured approach to develop a tailor made in-house application. This would improve the shift handover communication, ease of retrieving historical logs at minimum time, enable analysis of information, and. The E log solution was developed with in-house resources and helped saving considerable cost of buying third party application.
Take Back Control of Your Capital Project with an EPC 4.0 Strategy
Authors: Sabharwal Amish , Pada Greg Pada
Published: November 2020

Objectives/Scope:

CapEx Project delivery in the Oil and Gas industry is markedly underperforming other industries. McKinsey and IHS have reported that for projects over $1BN:98% of Projects incur cost overruns or delaysThe average cost increase is 80% of the original valueThe average slippage is 20 months behind original schedule

The advent of "Industry 4.0" is highlighted by the adoption of integrated technology and software tools that focus on management of data across entire projects teams. This has enabled a leap in project execution performance in Aerospace, Manufacturing, and Agriculture. This paper investigates how the current Oil and Gas project execution methodologies can also be enhanced to leverage an Industry 4.0 strategy. This approach has been dubbed EPC 4.0.

Methods, Procedures, Process

Through a process of dissecting existing workflows, business processes, contracting strategies, organizational structures, and information management practices used in capital project execution, the authors have proposed revised practices leveraging digital technology capabilities. These practices take advantage of systems that bring true data integration between all project tools, leveraging a single source of truth that can be visualized in 1D (data), 2D (schematics) or 3D (model), 4D (time) and 5D (cost) enabling project analytics and collaboration between all project disciplines, project teams and project stakeholders.

Results, Observations, Conclusions

The result is an EPC 4.0 blueprint. A series of recommended best practices that are enabled by moving to a unified data centric strategy that will enhance project outcomes. The paper will cover the impact that EPC 4.0 has onContracting Methodologies and Project Team StructuresData Management and data centric workflows/business processesConceptual/Front End Design MaturityEnhanced project oversight, reporting and managementProject collaboration within teams and between organizationsEnhanced Change ManagementPreparation for handover to operations

Early adopters of an EPC 4.0 strategy are seeing immediate results. Typical savings are a 50% reduction in engineering in costs or 5% reduction in CapEx. In addition, higher quality output from engineering flows through to procurement, construction, and commissioning yielding a further 10% CapEx savings. More importantly, predictability in project outcomes have significantly increased with teams more effectively able to mitigate and manage cost overruns and schedule delays.

Novel/Additive Information

The key innovation at the heart of the of EPC 4.0 strategy is the stripping away of the project practices that have built up over the years to mitigate the complexity and volume of information generated during capital project execution. By centralizing and simplifying data management, project contributors can focus on their principal role. For example, engineers can focus on engineering tasks, not on information management tasks.
Analytical Methods for Estimating Hydraulic Diffusivity in Heterogeneous Reservoirs Influenced by Ocean Tides
Authors: El Faidouzi Mohamed Mehdi
Published: November 2020

In offshore wells, the pressure fluctuations caused by the ocean tide can be used to inform on the mechanical properties of the reservoir, in particular its compressibility. Such phenomena is not associated with water movement, except at the microscopic level. In heterogeneous reservoirs, these pressure oscillations can cause macroscopic movement of water, which can serve as the basis for the estimation of reservoir flow properties. The purpose of this study is to develop a set of analytical solutions that describe the pressure variations in a heterogeneous reservoir, in terms of amplitude ratio and phase shift. The solutions were developed using the coupled fluid flow-geomechanics equation for a reservoir under uniaxial tidal loading. This study looks in particular at three geometries of inhomogeous diffusion—radial composite, linear composite and composite slab.
Reservoir Characterisation of Low Resistivity- Low Contrast Pays from a Deepwater Field Using Integrated Analysis
Authors: Shiwang Rahul , Varghese Christeen , Panchakarla Anjana
Published: November 2020

A deepwater turbidite formation from Eastern Offshore, India, is a major focus for hydrocarbon exploration. The reservoirs in this field are primarily of low resistivity and low contrast and consist of thinly laminated shale-sand laminae with overlying thick shales. Conventional logs do not sufficiently distinguish between the overlying shales against the laminated reservoir intervals- owing to poor vertical resolution of the tools to characterize the thin beds properties. A standard practice followed by the operating company was acquisition of conventional logging data along with tensor resistivity measurement for a laminated-shaly sand analysis (LSSA) followed by formation testing. While multiple new pay sands were discovered through this method, the sand-shale-fluid model of LSSA is insufficient to provide fluid typing. Furthermore, fluid sampling using formation testers in these unconsolidated formations are risky due to relatively high SOBM invasion and therefore high clean-up time is required to collect samples. Due to the similar properties between the SOBM and formation oil, it is difficult to conclude between the two fluids during real-time monitoring. Thus, it was essential to delineate the formation fluid using methods other than formation testing.

The acquisition of magnetic resonance data and an integrated interpretation involving conventional logging, tensor resistivity and NMR data helped overcome these challenges, prior to formation testing. The electrical anisotropy and borehole image data helped identify thin beds. LSSA outputs based on conventional and tensor resistivity data indicated hydrocarbon bearing intervals. A continuous magnetic resonance measurement acquiring the longitudinal relaxation (T1), transverse relaxation (T2) and the diffusion coefficient (D), helped derive a lithology independent fluid typing in these wells to provide insights before formation testing.

Hydrocarbon bearing sands were identified as per the results of the integrated analysis, and the formation testing intervals were optimized. Conventional resistivity inversion, LSSA saturation and flushed zone saturation from magnetic resonance provided an understanding of the invasion. The hydrocarbon bearing intervals delineated from integrated formation evaluation using LSSA and 2D NMR analysis were successfully tested and proven using formation testing and sampling. Subsequently, the exploratory well logging programs were modified to include the magnetic resonance in future wells and the workflow explained herein was adopted field-wide.

This paper provides a framework for integrated data interpretation using multi-component induction, magnetic resonance, acoustic data and resistivity imager logs to quantify reservoir fluids and subsequently provide an alternative to formation testing and provides a workflow for exploratory wells for Eastern Offshore, India.
Well Construction Process in a Digital Era: Data Driven Approach to Support Well Operations
Authors: Cappuccio Pasquale , Dal Forno Luca , Mutidieri Luigi , Spitaleri Alessandra , Dalla Costa Riccardo , Tuosto Salvatore , Ricci Maccarini Giorgio , Rinaldi Francesca , Gravante Elpidio , Pizzo Anna , Siciliano Lorenzo , Vivi Valentina , Iannantuono Pietro
Published: November 2020

Way of working is continuously changing in O&G field thanks to digital solutions and the possibility to have consistent data driven analysis to support decision-making process.

Well Construction cycle from planning to execution and post well analysis is evolving as well, since data are at the base of all the analyses allowing higher operational safety, more efficient engineering, better real time optimization and more effective comparison of performances at the end of operations.

Eni Well Operations Department has invested a lot in advanced analytics tools able to extract value from historical and real time data focusing the attention first of all on data coverage, quality and reliability, that are extremely important enablers to let the tools work and perform analyses, and then on proper data transmission system from different rig site locations towards a centralized database.

High frequency performance measurement and data intelligence tools allow reaching the technical limit, predictive analytics help in reducing downtime while drilling and well simulation software enhances not only planning phase but also operational real time follow up activities.

Applications of digital solutions have run in 2019 on most challenging activities with tangible results in terms of safety improvement, operational efficiency and time and cost savings. Almost 50 wells (more than the totality of most complex wells as per Eni classification) have been analysed in real time with both advanced analytics and predictive algorithms achieving: avoidance of specific Non Productive Time events (about 25% of NPT reduction), with a major impact on operational safetybetter performances throughout development projects, thanks to an improved learning curve and a reduction of Invisible Lost Time (average of 2,5% of time saving per well)enhanced real time monitoring and early detection of well events, leading to a faster decision making and adoption of corrective actions (anticipated actions by average 6 hours)

The development and the application of these tools have been made possible thanks to a proper Data Management System. In fact, several initiatives have been put in place to provide proper data gathering, data transmission, data quality check and assurance and data storage.

This paper will show in details how the results have been obtained starting from creating an appropriate data infrastructure up to real case of application along 2019 Eni drilling activity.

The extensive use of digital tools, both in Geographical Units and Headquarters, has been proven to provide effective support to plan, monitor and evaluate performances during all well operation activities.
Pitfalls of Open Ended Front End Engineering Design
Authors: Chehab Helmi , Singh Sunil , Singh Harendra , Kamal Faris , Takieddine Oussama
Published: November 2020

Several essential parameters, that often form the basis of design activities performed during Front End Engineering Design (FEED), are oftenly modified at late stages of the FEED process resulting in the transfer of various critical activities to the subsequent Engineering, Procurement and Construction (EPC) stage, rendering the FEED open-ended. This paper presents the impact of an open-ended FEED on EPC projects, and provides an approach to enhance the overall effectiveness of Oil and Gas project execution.

Basic Engineering, performed during FEED, comprises of various critical design activities such as Simulations, Material Selection and Sizing Calculations. Process simulations are prepared based on the extreme governing cases such as maximum flowrates extracted from the production forecast. Moreover, equipment material is selected to suite the specified reservoir composition since different chemical component combinations exhibit varying properties and behaviors. Furthermore, equipment size is calculated to satisfy the defined battery limits’ conditions such as Temperature and Pressure.

The critical activities that are carried forward from FEED stage impose amplified risks of design variations during EPC stage, which may have significant schedule and cost implications on the EPC project. In recently executed EPC projects, the reservoir composition, production forecast, and battery limits conditions were modified after the completion of the FEED, which resulted in the reworking of various basic engineering activities that caused significant delays in the issuance of detailed engineering deliverable and the procurement of critical Long Lead Items (LLI). The alterations to the production forecast such as elevated water flowrate resulted in the reverification of the governing cases and the mitigation of the impact on the facility design. Additionally, the changes to the fluid composition such as increased Hydrogen Sulphide content led to numerous adjustments to equipment material specifications and coating requirements. Furthermore, the revision to the battery limits conditions such as Maximum Deadhead Pressure required several amendments to the size of control instrumentation and safety equipment. Clients are recommended to adopt the strategy of providing fixed and clear essential parameters during FEED stage in order to minimize the reworks/revalidations during EPC stage, enhancing the overall success of the Oil and Gas project.

This paper aims to raise awareness of the risks associated with an open-ended FEED on EPC project execution. This paper also presents valuable suggestions and mitigation strategies that will assist all Oil and Gas project stakeholders in effectively optimizing their resources, enhancing the efficiency and profitability of their projects.