bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multi-Tubular Electromagnetic Corrosion Inspection Tool – Performance Demonstration using Yard Testing
Authors: Fouda Ahmed , Dai Junwen , Hu Yunyun 
Published: November 2020

Abstract
A multi-frequency electromagnetic pipe inspection tool with multiple transmitter and receiver arrays was designed to accurately estimate the individual wall thicknesses of as many as five nested pipes. The new tool enables monitoring well casing integrity without having to pull out production tubings, therefore minimizing inspection time and cost. This paper demonstrates the performance of the tool using yard mockups with known defects. The principle of tool operation and the methodology for data processing are also detailed in the paper.
The tool relies on eddy current principle in its operation. It comprises two sections of transmitting and receiving coil antennas and operates in continuous-wave mode at multiple frequencies. The configuration of strategic transmitter-receiver spacing and multi-frequency operation delivers a suitable range of information to evaluate individual pipes for the majority of well configurations. An advanced inversion-based data processing workflow is executed to estimate pipe parameters, including electrical conductivity and magnetic permeability, wall thickness, and eccentricity.
The proficiencies of the technology are confirmed by performing yard tests with two long test mockups. Each mockup has multiple combinations of overlapping and non-overlapping man-made defects distributed along sections consisting of three, four, and five nested pipes, which mimic typical corrosion progression. The measurement data from the mockups are validated against synthetic data generated from a 2D electromagnetic forward solver. Then, a procedure including pipe material property estimation, calibration, and inversion algorithms is performed to retrieve pipe thickness.
Results from the yard tests reveal that this tool is fully capable of detecting various kinds of corrosions concurrently across five strings of pipes, even on the outer pipes with high severity. The impact of pipe eccentricity on the accuracy of thickness estimation is also shown by deliberately decentralizing the innermost pipe over a length of the testing setup.
The information provided by this tool can improve the efficiency of well intervention operations, especially in areas with high-corrosion rates, and could result in significant cost savings to the operator.
Epoxy Resins-Cement Slurries for Primary Cementing Application
Authors: Hashmi Ahmad Atef , Al-Yami Abdullah Saleh , Dahmoush Abdullateef Ahmed , Wagle Vikrant , Alanqari Khawlah Abdulaziz , Alshaikh Saber Y , Gumsani Abdullah M , Ali Wajid , Al-Turki Faisal Abdullah 
Published: November 2020

Abstract
Polymer resin systems have many advantages over conventional cement. Since resins are solids-free particles, they can be used in low injectivity zones such as narrow fractures where conventional cement cannot be squeezed through. Besides, the resins can be used in combination with cement to enhance casing/cement bonding for improved wellbore isolation. To ensure the success of a field application, the lab testing must be performed at downhole conditions.
The objectives of this paper are to study the performance of epoxy resins and their curing agents. Also, to examine cement-resin slurry formulation testing and field application.
Cement Slurry was designed with suitable rheology and thickening time. This was done by utilizing enough curing agent into the cement-resin slurry. This study also highlights a successful field deployment to cement a 9 5/8-in liner tie-back job.
An Automated Diagnostic Analytics Workflow for the Detection of Production Events - Application to Mature Gas Fields
Authors: Poort Jonah , Shoeibi Omrani Pejman , Vecchia Adrian Luciano , Visser Gerlof , Janzen Mathijs , Koenes Jimmy 
Published: November 2020

AbstractDetection of production and well events is crucial for planning of production and operational strategies. Event detection is especially challenging in mature fields in which various off-normal events might occur simultaneously. Manual detection of these events by an engineer is a tedious task and prone to errors. On the other hand, abundance of data in mature fields provides an opportunity to employ data-driven methods for an accurate and robust production event detection. In this study a data-driven workflow to automatically detect production events based on signatures of events provided by experts is demonstrated. In the developed workflow, state-of-the-art data-driven methods were integrated with the domain knowledge for an accurate and robust detection. The methodology was applied on several case studies of mature fields suffering from production issues, such as scaling and liquid loading. It was found that the workflow is accurate, robust and computationally efficient which could detect new events (verified by the expert). The demonstrated method could be implemented both in the real-time or offline fashion. Such a workflow is sufficiently generic which can be applied for detection of different events and anomalies than tested and verified in this paper, such as leakage, production losses, …
Advanced Analysis of CO2 Storage Development Plan and its Unique Compared to Field Development Plan
Authors: Widyanita Ana , B W Zairudin W Ahmad 
Published: November 2020

Abstract
There will be future development of hydrocarbon fields with high CO2 content in Malaysia. Carbon Capture and Storage (CCS) is required in order to develop these fields, since venting and flaring of CO2 to atmosphere is not allowed. Reducing CO2 emission will impact to environments and climate change. On the storage part, integrated study needs to be conducted to ensure the field is suitable as storage site. The main objective of this paper is focusing on the important advanced analysis and assessments for maturing potential CO2 storage sites, which is called Storage Development Plan (SDP).
The evaluations and analyses will cover 4 major areas, which are Storage Capacity/Injectivity; Containment; Well Integrity; and Monitoring, Measurement and Verification (MMV). These evaluations and analyses are conducted in order to assess the subsurface risk, reduce uncertainties and mitigation plan in maturing the fields as storage sites. Integrated screening and maturation assessments of potential storage sites must be conducted in order to identify the most suitable CO2 storage sites.
The Storage capacity/injectivity analyses will cover estimation of CO2 storage capacity, optimum injectivity strategy, sensitivity on CO2 injection scenarios, and study on porosity-permeability changes, trapping mechanism and long-term fate study. Containment analyses will cover assessment of containment/seal integrity, possible leakage risk pathways, evaluation of compaction and subsidence to hold injected CO2 as long-term storage solution. Well Integrity analyses will cover the evaluation of well integrity and leakage assessments through existing wells, assessment of existing wells for conversion and propose cost-effective mitigation plan. Monitoring, Measurement and Verification (MMV) will cover monitoring and verification of CO2 injection performance and behavior consistent with prediction on capacity and injectivity, monitoring seal integrity, monitoring compaction and subsidence, and ensuring containment that address health, safety and environment. This advances analysis and maturation assessments provide solution to mature the best suitable storage sites for development of hydrocarbon fields with high CO2 content.
This Storage Development Plan (SDP) would form a benchmark of advance analyses and assessments for maturing the CO2 storage sites in Malaysia and elsewhere in the world. This will be integrated study consists of overburden, reservoir, laboratory, well integrity and MMV studies. This integrated study will reduce the subsurface uncertainty and mitigate the identified risk for any fields that are selected as storage site. This greatly aids to optimize and commercialize the future development of hydrocarbon fields with high CO2 content.
Reservoir Structural Imaging Using Azimuthal Dipole Sonic And Vertical Seismic Profiling
Authors: Van Kleef Franciscus , Verma Ravi , Waqas Muhammad , Donald Adam , Benett Nicolas , Suliman Israa , Al-Kharusi Saif , Hirabayashi Nobuyasu 
Published: November 2020

AbstractOffshore Abu Dhabi a deviated well, with a dip of 51 degrees over the logged section, was logged using modern full waveform sonic tool with monopole and dipole sources. By using the individual single receiver sensor polarized shear reflections from dipole source, the dip and azimuth of the reflector were determined. The reflections recorded matched very well with the structure recorded from a walk-above VSP and the resistivity image also acquired in the same well and with the 3D seismic.In another field offshore Abu Dhabi, standard dipole data was used to image layering and natural fractures using a modified workflow. In this horizontal wellbore, the relative dip of the events from the 3D-STC were used to place the migrated images appropriately above and below the wellbore.The described method using sonic tools detects reflections up to 30 m away from the wellbore at meter scale resolution. As such this fills the gap between seismic which records reflections at 30-100 m scale resolution, VSP at 10 m scale resolution and micro resistivity images at millimeter scale.
Advancing Relative Permeability Estimation Through Data-Driven Modeling
Authors: Kalam Shams , Khan Mohammad , Khan Rizwan Ahmed , Alam Mir Muhammad , Sadeed Ahmed , Mahmoud Mohamed , Abu-Khamsin Sidqi A. 
Published: November 2020

AbstractAvailability of large amounts of data helps in developing data-driven models using state of the art Artificial intelligence (AI) methodologies. Relative permeability is an important parameter used by reservoir engineers and are usually accurately obtained from laboratory experiments, which are relatively expensive. Therefore, AI can play an important role in developing models to predict relative permeability accurately without extensive lab procedures. Accordingly, this work presents application of two AI algorithms namely, Artificial Neural Network (ANN) and Adaptive Neuro-Fuzzy Inference System (ANFIS). Furthermore, two novel mathematical correlations are extracted from the ANN model to predict relative permeability of oil/water in oil- and water-wet environments. The input data, obtained from literature, for the development of AI models include porosity, rock absolute permeability, initial water saturation, residual oil saturation, wettability index and water saturation.A customized workflow is applied to ensure proper data is fed into the AI models. In addition, a rigorous sensitivity analysis is performed within the framework of this workflow. This analysis involves running multiple realizations with varying number of neurons, resulting in various weights and bias for the ANN model. Moreover, ANFIS model is tuned using various cluster sizes to result in the most optimum value. Finally, the optimized ANN and ANFIS models are compared using the Root Mean Squared Error (RMSE) and correlation coefficient (R2) analysis when applied to a blind dataset comprising of more than 300 data points. The analysis illustrates that the ANN model is relatively better in predicting relative permeability values to both, oil, and water. On the other hand, analysis of the ANFIS model shows that it yields high error values when tested on unseen dataset. Also, unlike the ANN mode, it does not provide an actual mathematical correlation. This work presents alternate data-driven artificial intelligence models which will lead to quicker and cheaper relative permeability estimates.
Insights of Processing Early-Outs from New High-Quality 3D Seismic Data for Exploration Prospectivity: A Land Case Example from Abu Dhabi
Authors: Caeiro Maria Helena , Cambois Guillaume , Mahgoub Mohamed , Al Hammadi Miaad , Smith Cara L. 
Published: November 2020

AbstractCurrently ADNOC is conducting the world's largest continuous 3D seismic acquisition campaign of approximately 90 000km2 with the aim of covering the entire Abu Dhabi emirate subsurface (both onshore and offshore) with 3D seismic. The main objective of this campaign is to provide high quality seismic data to explore conventional and unconventional resources. The new 3D covers areas that were under-explored in the past and is of excellent quality to apply advanced technologies for interpretation and reservoir characterization. The new 3D seismic data has high-trace density, broadband frequency content, full-azimuth and long offsets, which provides paramount information for detailed subsurface imaging and characterization of complex reservoirs.This study is focused on a 3D land seismic survey recently acquired that is currently at the time and depth imaging stage. The early-out volumes obtained from processing consist of valuable preliminary data that can be used to infer some possible exploration prospectivity features while final processing is still ongoing.A significant benefit of the pre-stack depth migration (PSDM) method is the construction of a detailed anisotropic subsurface velocity property model. Therefore, it accounts for lateral velocity variations, which are related to geological features especially attractive to explorationists, and has a more accurate overburden representation than historical time imaging workflows. Herein, we present some examples on how the 3D PSDM volume reveals more confidence in geological features that are not so clear in a pre-stack time migrated (PSTM) volume. The preliminary results indicate how shallow hydrocarbon presence can interfere with the PSDM velocity model and how it can be solved to reveal possible exploration potential in deeper sections.
Casing Wear Modelling: A Comparison between MFCL and 3D Stiff String Model
Authors: Aichinger Florian , Nobbs Benjamin , Couliou Florent , Dao Ngoc-Ha , Brillaud Loic , Medrano Silfredo 
Published: November 2020

Abstract
A stiff-string torque & drag & buckling model has been coupled to a 3D meshed casing wear calculation to model the effect of drilling operations on casing wall thickness reduction. Results of the numeric simulation are compared to MFCL for field cases and provide an understanding of possible well integrity issues during the well life cycle. A Hall wear model and 3D rigid stiff string model is used to predict casing wear. Using Wear Factor Coefficients obtained for several hard-banding, casing grade and mud-types, the process was tested against numerous field cases. For each field case, a history of drill string runs were modelled and filtered into operations in which the drill string rotates such as Drilling, Reaming, Back reaming and ROB. Initially, the calliper log was not analysed to ensure the results are non-biased using experimentally found Wear Factors. In a second phase, the Wear Factors were calibrated against the measured calliper log. This paper provides a methodology that was used to successfully quantify the effect of casing wear against numerous field cases. The 3D orientation of the casing wear was found from an un-calibrated MFCL. After calibration of the new Wear Factor, the casing wear can be predicted before and after well construction. When used as a post analysis tool, the methodology helps determine if casing wear was a root cause of loss of well integrity. This process also helps reduce the uncertainty in Wear factor as a major unknow in the contact force, is now properly modelled. When used in a post analysis process, the results where quantitative (groove depth vs 3D orientation) but also qualitative, providing a post-mortem description of the state of the well to operation's personnel. The methodology presented here can be used to both predict excessive casing wear and determine if excessing casing wear was a cause of failure. It can be used to help determine the state of well for workover operations or plug and abandonment operations. Accurate casing wear prediction at planning stage allows the anticipation of costly but fit for purpose mitigation means & measures.
What Test Environment for the Qualification of OCTG Sour Service Grades – Means and Consequences of pH Control
Authors: Florian Thebault , Julien Pennequin , Hervé Marchebois , Christelle Gomes 
Published: November 2020

Abstract
Many worldwide Oil & Gas fields are sour with H2S partial pressures (PPH2S) above 0.05 psi. For such situations, it is critical to employ Oil Country Tubular Goods (OCTG) qualified for sour service, meaning resistant to Sulfide Stress Cracking (SSC). More especially when very high strength grades are required for producing high pressure O&G reservoirs. For instance, a quenched and tempered sour service low alloyed steel with 125 ksi Specified Minimum Yield Strength (SMYS) has been investigated through various standardized test solutions. As corrosion processes in acidic environment with dissolved H2S make the testing solution to drift, some of the standardized test solutions are highly buffered with the acid-base couple acetic acid / acetate. Another method for limiting the pH drift consists by frequent additions of strong acid as hydrochloric acid during the test. The objective of this work is to compare the electrochemical of such high strength steel in NACE TM0177 Solution B, EFC 16 solution with and without pH adjustment. Thermodynamic calculations for predicting the saturation pH, hydrogen permeation tests, corrosion rate measurements and fine characterizations of iron sulfide scales (composition, morphology and defectology) were performed for being correlated to SSC test results. Build a better understanding of test methodology impact on the hydrogen uptake and the protectiveness of corrosion products is also an aim of this work.
An Accurate Model for Prediction of Hydrocarbon Gas MMP Based on a Large High-Temperature Data Set
Authors: Mogensen Kristian 
Published: November 2020

AbstractMinimum miscibility pressure (MMP) is an important parameter when designing a miscible gas flood. Traditionally, the MMP is evaluated using slimtube tests, which are time-consuming and expensive. Since it is typically not feasible to test more than a few injection gases on a subset of relevant reservoir fluids, reliable methods are required to estimate the MMP. The most popular correlations are often based on data from low-temperature reservoirs and are not always very reliable.In this work, we make use of the new, comprehensive ADNOC PVT database, which contains more than 100 slimtube MMP measurements for a variety of injection gases, including sour gases. We then complement this data source by performing equation of state (EOS) based miscibility calculations covering a large temperature range with appropriately tuned EOS models. The combination of measured and simulated data is then used as input for development of a general correlation.The new correlation is a modification of the Eakin-Mitch formulation. It has been tuned to a large variety of injection gases and reservoir fluid compositions, and covers a wider temperature range. The average deviation is 5% and the maximum error is less than 20%. Results show that the MMP exhibits a maximum versus temperature, a feature also noticed previously during development of CO2 miscibility (Yuan et al., 2005; Alshuaibi et al., 2019).One of the novelties of this work is the identification of a more complicated temperature-dependency of the MMP. Furthermore, the new correlation considers not just lean gases but also rich gases and sour gases, which develop miscibility based on the combined condensing-vaporizing mechanism. We believe that this model is more robust because it covers a much larger parameter range compared to existing correlations.
An Integrated Approach to Optimise an Offshore Field Development Plan
Authors: Kasekar Hiren , Ghauri Usama , Nevin Michael , Mel Raphaele , Uijttenhout Mattheus , Alblooshi Jamal , Draoui Elyes 
Published: November 2020

Abstract
The ADNOC Offshore oilfield located in the Arabian Gulf is being developed utilising various wellhead towers, infield pipelines and a standalone super complex. The field development team devised an updated subsurface plan to achieve production targets beyond the original plan. The incremental oil necessitated assessment of original surface facilities design to identify any bottlenecks and unlock constraints.
A set of production forecasts were initially provided as basis for assessment covering various scenarios and range of reservoir uncertainties. To manage these uncertainties, the facilities and subsurface development teams worked in an integrated and iterative way. The production profiles were used to assess and develop understanding of surface facilities such as oil flowline network, water injection supply and network, gas lift networks and the major equipment.
The assessment results provided guidelines on the process facilities constraints which were feedback to subsurface team. An optimised subsurface development plan was then generated respecting the facility constraint and leveraging the existing facilities design to utilise ullages.
An initial view of investment to produce incremental oil considered installing three new wellhead towers, a new manifold platform and a new water injection platform both linked to the super complex and a new main oil line installation to transfer partially stabilised oil from super complex to oil processing plant. The technical evaluations and the decision analysis resulted in a low-cost solution that was needed to ensure that the field's incremental oil production is economically viable.
The integrated approach not only allowed selection of techno-commercial robust solution but also allowed optimisation of investment providing flexibility to accommodate the key project uncertainties. This was achieved by deferring the investment to future by descoping the overall development plan in two separate projects - achieve production plateau and sustain plateau. The interim period between the two projects would provide time to resolve the subsurface uncertainties and an opportunity to revisit future development strategy without committing any investment. In addition, the original UTC was significantly improved. This approach emphasised the importance of having a flexible surface facilities solution in accommodating the developments in the subsurface field development strategy especially in an offshore environment and during the early field production period.
This paper presents an approach followed for optimisation of an offshore oilfield development plan under various surface facilities constraints.