bluuebunny/crossref_metadata_2025_split huggingface dataset:
Completion Barrier Glass Plug with Integrated Bypass Sleeve
Authors: Mousa Amier 
Published: October 2022

Abstract
In order to optimize Completion installations by eliminating Intermediate Completion, reducing rig time, and preventing fluid loss, a project was initiated to develop a barrier glass plug with bypass capability. The plug allows self-filling of the tubing while running in hole and circulating of fluid to displace the wellbore. Once the bypass is closed using a pressure key applied from surface, a V0 certified barrier is established.
A glass plug with an integrated bypass sleeve was developed to allow pumping through the plug. To develop the plug, multiple technologies from existing plugs with proven track record were incorporated. To close the bypass sleeve an Electronic Counter system, known as E-Trigger, was utilized. A pressure key is programmed in the E-Trigger Software. Once the pressure key is applied, the bypass sleeve will close. To open the plug, a Mechanical Balanced Counter System was utilized which requires pressure cycles to activate. Once the Balanced Counter is fully cycled, the glass will break and the plug will open.
Utilizing barrier glass plug with bypass capabilities in the lower Completion will eliminate the requirement to use an intermediate completion to isolate the well and displace the well to brine. Once the sleeve is closed it will prevent fluid loss to the formation after placement of the filter cake breaker. The plug can then be used to set production packers hydraulically, pressure test production tubing, and allow for the safe installation of Christmas Trees.
To verify the performance envelope and functionality of the plug, an erosion test was performed where 10 barrels per minute flowrate was achieved for a total volume of 10,000 barrels using water based mud. With the substantial volume pumped, no indication of erosion was seen after the test. The bypass sleeve was then closed and the plug was pressure tested and qualified to ISO 14998 V0.
The current technologies available in the market does not allow for high flowrate pumping and remote closure of barrier glass plugs after the pumping operation. Therefore, incorporating the barrier glass plug with bypass capabilities in the lower completion will result in significant savings by reducing the completion components in the string and reducing rig time.
A Cost-Effective Through-Tubing Gravel Pack Rigless Installation via Intelligent Coiled Tubing
Authors: Badrawy Kareem , Molero Nestor , Kewan Mona , Seoudi Seif , ElKaragy Alaa , Shalaby Roshdy , Desouky Ahmed , Slama Hedi 
Published: October 2022

Abstract
Sand production is deemed one of the major problems in the oil and gas industry. Additional surface equipment is needed to handle the sand returns, bringing on additional costs and disposal difficulties. In addition, among the most common setbacks of sand production is the increased risk of damage to the well jewelry and accessories. For wells that start sand production at a later stage, conventional gravel packing with a workover rig is one of the preferred methods to alleviate the problem. However, availability of workover rigs and project economics have driven operators and service companies in Egypt to explore alternative and cost-effective options.
The novel approach consisted of a rigless intervention aimed to recomplete the well with a through-tubing gravel pack (TTGP) deployed via coiled tubing (CT) equipped with real-time downhole telemetry. The array of bottomhole measurements, annulus temperature, CT annulus pressure, CT internal pressure, casing collar locator (CCL), and axial forces, was leveraged to ensure precise depth correlation and optimal use of the bottomhole assembly and make informed decisions based on the actual downhole dynamics. A high-pressure rotary jetting tool was used in the first CT run to clean out the wellbore and condition the tubulars across the planned anchoring depth for TTGP components.
The candidate well is a vertical gas producer completed with 4 1/2-in. tubing and 4 1/2-in. liner. After the wellbore was conditioned using a high-pressure rotary jetting tool, a sump packer was hydraulically set below the perforations in the second CT run. In the following run, a 200-ft vent screen assembly was connected and then hydraulically set inside the sump packer. The CT string was retrieved to surface upon confirmation of proper setting of the vent screen assembly, and the gravel pack slurry was bullheaded from surface. Excess sand was removed in the fourth CT run, followed by retrieval of the vent plug from the top of the screen assembly. An upper packer was connected to the screen assembly in the next CT run, and then hydraulically set in the 4 1/2-in. liner. Finally, the well was kicked off using nitrogen and then evaluated using a complete surface testing package. The target production rate of 11 MMscf/D was achieved, which represented a 55% improvement with zero sand production on surface. Now with over 2 years of production, the well is producing an average of 10 MMscf/D and maintaining zero sand production.
This enhanced TTGP conveyance approach represents an effective and economic solution to remediate wells compromised by sand production where conventional workover rig methods challenge economics. This technique greatly relies on CT real-time downhole measurements, and operators from the Middle East and across the globe can benefit from the experience gained in Egypt from this project.
Case Study of the First Large Bore Remote Open Fluid Loss Control Device Compatible with all Multilateral Well Levels
Authors: El-Mallawany Ibrahim , Normand Marc , Bernal Ricardo , Shukor Arrauf 
Published: October 2022

Abstract
The first large bore remote open fluid loss control device (FLCD) presented in this paper was developed specifically for a tri-lateral TAML level 4 well and then successfully trial tested. Multilateral wells with limited or no pressure integrity at the junction add additional challenges in regards to the design of a fluid loss control device. In those applications, positive pressure cannot be applied against the junction to remotely open the FLCD. Moreover, depending on the final multilateral completion deployed, the access to the FLCD installed in the laterals may be prevented like in the case of the monobore intelligent completion reviewed in this paper featuring inflow control valves (ICVs) across each lateral entrance. Therefore, retrievable FLCDs cannot be used in those instances and the required interventions would add rig time and cost. Alternatively, treatment with Hydroxyethylcellulose (HEC) pills and/or loss circulation material (LCM) can cause skin damage to the reservoir that can affect production negatively. All these requirements were considered to design the FLCD technology presented in this paper to make it compatible for any TAML level in a multilateral well.
First Application of Intelligent Gas Lift System in ADNOC Offshore Field to Improve Profitability Through Enhanced Gas Lift
Authors: Wang Zhihua , Wills John Andrew , Faustinelli Juan , Abdulhai Walid , Faux Stephen 
Published: October 2022

Abstract
Gas lift is one of the most crucial components for achieving and maintaining the production targets in a giant offshore oil field development. All producer wells are completed with gas lift mandrels (GLMs) using both dummy and tubing pressure shearable valves to accelerate and enhance efficiency of the initial unloading and gas lift start up. The gas lift designs are optimized considering reservoir conditions and surface constraints over the well life cycle. However, once the GLMs are installed, the gas lift optimization would require intervention work, hence production interruptions. To maximize the gas lift performance and minimize the intervention work, a digital intelligent gas lift (DIAL) system was trialed.
Once the system was selected, a comprehensive design review was conducted covering product qualification, material suitability, factory acceptance testing, and technical limits in both initial installation and well life cycle operation. Detailed pre-installation preparation such as system integration testing and installation procedures were prepared. Four DIAL units were installed successfully in a record extended reach drilling (ERD) well together with 4 conventional GLMs along with dummy valves, as contingency. The system was successfully tested during nitrogen unloading operations which not only demonstrated the functionality of the equipment, but also the increased efficiency of the use of the system.
It is estimated that the use of DIAL in this pilot well will result in substantial net present value generation based on the elimination of well intervention related cost to service gas lift valves, avoidance of production deferral, and production gain resulting from optimized real time gas lift operations.
Each DIAL unit has built-in pressure and temperature sensors and adjustable size orifices. This allows the operator to manage the evolving well and reservoir conditions by applying data driven decision making and surface control during well unloading and production to enable the optimum gas lift injection rate and depth to maximize production. This is all able to be accomplished without the need of wireline intervention for valve change out. This process is repeated until gas reached the deepest valve. Additional benefits of using DIAL system in gas lift operations, as compared to conventional systems, will be described in the paper.
The first DIAL system was installed in one of the top 10 globally longest ERD wells containing the largest DIAL system ever mounted. The paper will describe the brief history of artificial lift strategy for the field and current practices, drivers for trialing DIAL, the equipment qualification process, installation overview, and finally ultimate benefits seen in the initial unloading and gas lift operations.
Depth Surface Update Using Velocity Model Integration Workflow
Authors: Al Anbouri Buthaina Abdullah , Hodgson Linda , Al Anboori Abdullah , Cook Peter , Al Rashdi Khalil 
Published: October 2022

Abstract
This paper describes the workflow to derive a robust depth reference case map and associated depth uncertainty range suitable for use in the planning of new wells and for ‘gas in place’ calculations. DGI's Covizsoftware was used to deliver this objective. A number ofseismic and well velocity inputs and seven methodologies were tested withPre-stack depth migrated (PSDM) interval velocities chosen as the most reliable for geologic top prognoses (based on drop-out test results). All other methods were used to frame the uncertainties around this reference case. This methodology was tested in the recent ABCXX8 well with a resultant depth prediction error at the reservoir level of 0.5%. However, it should be noted that distance from nearest control point is a crucial factor in the prediction of depth and corresponding depth uncertainty. Further updates of the calibration model will be made with an upcoming regional well trade and the latest wells on the block. Covizallows rapid updating of the model with any new information.
Data Visualization Workflow an Alternative Procedure to Quality Check Static Grids
Authors: Contreras Perez David Rafael , Almehrzi Amal 
Published: October 2022

Abstract
Static grids are commonly an ensemble of millions of reservoir property values. Analyzing this vast dataset is a challenging task and is usually performed via simple statistical parameters (e.g arithmetic mean and standard deviation). The objective of this paper is to present a quick and efficient way of analyzing static model realization results in a more visual, interactive and efficient manner allowing a multidisciplinary team to absorb information and key ideas quickly.
The proposed methodology starts with a set of properties from a given static grid realization. The data are prepared with all necessary labeling and categorization to be analyzed (e.g. reservoir and segment indicators, well regions etc.). All kinds of data variations available in the static model are gathered and mobilized into dynamic data dashboards for further analysis. The interactive data visualization templates provide flexibility to filter information either by categories or data ranges. The filtering schemes are immediately propagated to all available plots in the dashboard highlighting common patterns from all the data relationships in the static model.
The principle output from this methodology is an interactive data visualization panel that displays all necessary infographics related to reservoir data-trends. Starting from simple rock quality pie-charts, which can be mapped showing field-wide trends, porosity-permeability plots, to more detailed infographics of property ranges per well/reservoir indicator as well as summary tables of average properties per reservoirs/layers/segments etc. The ability to have all plots linked in a single display provides a simple but powerful platform to evaluate and interrogate data from the static grid using different views. Data can be aggregated in different ways and summarized accordingly. With this continuous process of data filtering, it is possible to quickly identify outliers and collect evidence of data inconsistency within the static grid. The additional value of the presented approach is the ability to compare multiple property realizations in a single template and summarize similarities and differences between different static realizations.
The implementation of reservoir property dashboards proved to be an effective practice to increase the understanding of distributed properties inside static grids. A more comprehensive and detailed data quality check can be performed in multiple properties using a single view of the structured dataset. Additionally once data is loaded into the data visualization platform it can be easily shared with team members without the need of any specialized modeling software.
Sedimentological, Diagenetic, Petrophysical Controls on the Miocene Submarine Deposits, Gulf of Suez: Implications for Reservoir Quality
Authors: Abdelhalim Kareem B. , Radwan Ahmed E. , Abdelfattah Tharwat A. , Shabaan Mohammed N. , Elkhawaga Mohammed A. , Kassem Ahmed A. 
Published: October 2022

Abstract
The Gulf of Suez Miocene ASL Member is an important reservoir for hydrocarbon development. This study specifically focused on the sedimentological, diagenetic, and petrophysical characteristics to better delineate the reservoir quality variability. The data comprised of well logs from four (4) wells, two of which had whole core with a total length of 150 ft. About 65 rock samples were selected and made into thin sections. These thin sections were examined under a polarizing microscope to observe mineralogical composition and diagenetic evolution. X-Ray diffraction (XRD), scanning electron microscope (SEM), and core plug porosity and permeability analysis were performed and used to interpret the mineralogical composition, pore throat geometries, and pore system characteristics of the reservoir zone. The comprehensive analysis showed that the ASL Member was deposited as turbidities and gravity flows in a submarine fan system. Two closer siliciclastic sources, Wadi Baba and Wadi Feiran, are interpreted to be potential sediment sources that fed coarser siliciclastic material via submarine canyons and relay ramps between extensional faults. The petrophysical measurements showed clear reservoir heterogeneity with a range of porosities between 2 to 10 %, and permeabilities between 0.4 and 60 mD. The reservoir quality is influenced by sedimentation and diagenesis, which play a major role in enhancing or reducing the reservoir quality. Combining the sedimentological and petrophysical analysis will help identify sweet spots by delineating high quality reservoir fairways. The presented work provides a reference for depositional, diagenetic, and petrophyiscial controls on submarine fan depositional systems in the studied basin and elsewhere.
Elastic Full Wavefield Inversion: The Benefits and the Challenges in Clastic and Subsalt Setting
Authors: Baumstein Anatoly , Routh Partha , Basler-Reeder Kyle , Ho Cha Young , Tang David , Barr Jay , Martinez Alex 
Published: October 2022

Abstract
The main focus of our work is application of visco-elastic Full Waveform Inversion (eFWI) to estimation of elastic parameters directly from seismic shot data. In particular, we aim to recover the ratio between pressure wave velocity Vp and shear wave velocity Vs, which can be indicative of the type of fluid present in a potential subsurface reservoir.
The workflow we describe does not directly use well ties for wavelet control, as is typical in seismic inversion. We provide intuitive explanations for choices behind the proposed multi-stage hierarchical algorithm, outline its key steps, and present field data examples from a structurally simple clastic setting and a complex sub-salt environment. The latter, in particular, makes differentiating net versus non-net in pre-salt carbonate reservoirs a challenging problem when using narrow azimuth streamer data. The challenges include significant illumination variability caused by complex geometries of the evaporites, complex wave modes and scattering caused by strong property contrasts in the evaporites and carbonates, and layering of anhydrite and other salts within the evaporites causing complex transmission losses. The thick carbonate reservoir units beneath the salt further complicate the estimation process due to lack of low frequency signal recorded in streamer data.
Our methodology shows that it is possible to directly invert shot data to obtain geologically meaningful elastic properties that can be useful in exploration and early development phases. However, challenges remain. We demonstrate that inverted acoustic impedance (Ip) from eFWI has higher fidelity and more reliable magnitude compared to the ratio between compressional and shear wave propagation speeds (Vp/Vs). In fact, the former is sufficiently accurate to be reliably used for porosity prediction. In turn, eFWI Vp/Vs inversion results are in qualitative agreement with well information (as a blind test) for the clastic example and able to discriminate the net versus non-net for the pre-salt example without well information. However, the quantitative match may be insufficient to determine the type of fluid via rock property inversion without any well control. Further research is needed to investigate the sensitivity of Vp/Vs and determine if the quality of the data is key a factor, in addition to stabilizing simultaneous extraction of several elastic parameters from seismic data via constrained inversion framework.
Automated Well Location Optimization Using Wish Technology
Authors: Motlagh Masoud , Thenon Arthur , Ismail Ahmed , Eberle Nicolas , Bergey Pierre 
Published: October 2022

Abstract
To optimize the value of the ADNOC future development, subsurface optimization opportunities in several reservoirs under development (Shuaiba, Lekhwair-3, Kharaib-2 and Kharaib-1) are investigated. The Shuaiba reservoir is the major contributor to field production, with three main different areas: North, Center and South. This paper presents the application of the WISH tool and associated workflow to optimize the location of significant number of both producer and water injection new wells in central and northern units.
WISH (Well Improvement ScHeme) is an automated Generative Design method and tool developed by TotalEnergies to improve well pattern designs. The approach balances the importance of several positioning rules to generate potentially performing candidate patterns. Commonly accepted positioning rules are suggested (e.g.: positioning wells away from undesired fluids, in rich areas, etc.) and can be mixed with custom positioning rules designed by the engineer (e.g.: positioning wells in good history-matched areas, etc.). These patterns are evaluated using conventional dynamic reservoir simulations. Optimization methods like Design of Experiments can be utilized to identify faster and better patterns compared to traditional approaches.
By sequentially optimizing the location of injectors and then producers, it demonstrates that up to 170 mmbbl of additional reserves and 3 years of extended plateau could be achieved. Number of injectors remains the same but the injection and sweep strategy changes significantly. Number of producers however could be reduced by 45% to 60% with different economical outputs respectively (higher reserve/lower NPV).
The paper will strengthen the literature corpus relative to benefits of introducing physics driven well placement heuristics in Computer Assisted Design well design processes by showing results of a complex real-life application. The process is applicable on single or multi-realization models (considering uncertainties). Thanks to the intuitive nature of WISH design rules, human easily keep control of overall optimization during the exploration loops. Performing patterns are identified in looping processes involving comparatively few simulations.
Delineating Karst, Fault and Fractures Interpretation Through Integration of Seismic Attributes and Diffraction Imaging in Giant Offshore Field Abu Dhabi
Authors: Goraya Yassar , Alfelasi Ali Saeed , Inoue Hiroyuki , Al Hmoudi Amna Rashid , Yingpeng Chen , Xiaolin Lyu , Albeshr Manal I. 
Published: October 2022

Abstract
Today, in a matured developed field, reservoir management is challenging due to poor seismic resolution at reservoir level. Whereas overburden geology further deteriorate seismic quality due to foot prints, observed at reservoir level. Overburden geology is a key challenge for reservoir characterization and may mislead faults and fractures interpretation, identification of rock properties and distribution of fluids. In this paper we tried to integrate both diffraction and reflection data to improve seismic resolution to delineate reservoirs and non-reservoirs zone with drilling and well data.

Seismic data
Seismic data was acquired using OBC technique. PreStack Time Migration processing was performed in 2002, 2016 and psdm migration was performed in 2018 for structural interpretation. However data quality for reservoir characterization was affected by the hardness of the seafloor and anomalies in the overburden. These challenges are currently being addressed through diffraction imaging.
In 2022, Diffraction imaging is performed for 10×10 KM2 pilot area, due to which we were able to delineate karstic feature in detail and faults at reservoir.