bluuebunny/crossref_metadata_2025_split huggingface dataset:
Utilizing Well Digital Twins to Optimize Offshore Nitrogen Lift Operations
Authors: Alhumaid Saleh , Al-Kadem Mohammad , Daanyal Muhammad , Bayounis Ryyan 
Published: April 2023

Abstract
Nitrogen lifting through coil tubing is widely accepted as an efficient and reliable method for reviving a dead well. In offshore fields, it becomes more challenging to conduct a nitrogen lifting by coil tubing operation given the additional cost of securing a barge, cost of rigless well interventions, logistics and continuously changing weather conditions—all of which create a very limited window of opportunity to conduct a successful nitrogen lifting operation. This paper proposes an advanced method of conducting nitrogen lifting using coil tubing, optimizing for injection rate and depth of injection. The objective of this optimization is to reduce both operation time and consumed volume of nitrogen.
By leveraging emerging technologies, an advanced production modeling algorithm using well digital twins was created to maximize lifting of liquid for each unit of gas injected. The method identified several parameters which can be used for nitrogen lifting by coil tubing—such as injection rate, depth of injection, and injection methodology. Ultimately, given the high levels of computing power needed to conduct this analysis, this method is optimal in offshore rigless activities where there is a limited window of opportunity to conduct rigless operations including nitrogen lifting by using coil tubing. Well digital twin was used to model well and fluid behavior under coil tubing conditions—ultimately calculating Gaslift Utilization Factor (GUF), which is a measure of how much liquid can be lifted for each unit of gas injected. Then, in an iterative process, all the possible parameters that can be changed would be altered to reach the highest GUF factor.
As a pilot to see the outcomes of the advanced modeling algorithm, this method was deployed at an offshore well to revive a well back into normal production. The results were remarkable. There was a 40% reduction in the consumed nitrogen relative to traditional methods, and the job was completed 12 hours ahead of schedule. The tool provides two scenarios, one for most optimal scenario and another option in case the first scenario does not lift the expected volumes of fluid as anticipated. In the trial test, there was no need to resort to the second scenario.
There are plenty of publications related to offshore rigless activities or the use of advanced modeling techniques. None, however, bridge the gap between the two areas combining advanced modeling with rigless operations to increase the efficiency and optimize to reduce cost and time.
Proactive Intervention: A Holistic Examination of Safeguarding Well Integrity, and Optimizing Future Production, to Collaboratively Maximize a Field's Potential
Authors: Billingham Matthew , Cornelio Janio , Singh Kamaljeet , Pacheco Leonardo , Moreira Marcio 
Published: April 2023

Abstract
The paper focuses on the field life cycle and how new technology (including digital) and proactive, collaborative workflows can significantly optimize a field's production, with a focus on Brazil. Specifically, we discuss how, in the presalt, it is important to monitor casing integrity to identify salt creep and deformation as soon as possible. Proactive early identification of issues can accelerate the plugging and abandonment (P&A) decision at a stage where costs are reduced by avoidance of a more complex P&A caused by deformation of major completion components. Considering the complexity of a deepwater intervention, an innovative approach of through-tubing well surveillance was implemented, based on the third interface echo measurement provided by an advanced ultrasonic tool. The technique was deployed in some wells where the casing stress analysis indicated there was a risk of collapse, providing valuable information about casing and tubing integrity, as well as precise identification of annulus content. The paper intends to present local examples of the logs run, collaboration among technical experts, and the decisions made. The scope extends beyond the initial production period to maximizing production, when it is necessary to consider production issues as well as well integrity issues. The paper proposes that conventional KPIs may not measure the real intervention performance and can indeed detract from an optimal outcome.
Most of the wells assessed were found with their integrity preserved, and therefore the production and/or injection, could continue. Where integrity issues were identified, the data gathered were used to redefine the intervention, allowing a safe temporary well suspension, assertive P&A planning, reducing the uncertainties, and facilitating communication with the regulatory agency. The paper will then discuss, during the barrel chasing phase of the field's life, how a better, collaborative alignment of the interests of all shareholders to the outcome of increased production can be achieved. Case studies reflect application of the technique in Brazil. The study demonstrates how to achieve the optimized field life cycle.
New technology, including advanced digital workflows, has been applied to the challenge of well integrity assessment to examine casing deformation in Brazil. This has proven extremely important in early identification of issues to enable the most cost-effective remediation. New collaborative workflows initiated after well integrity optimization optimize production from existing well infrastructure to extend the field life cycle.
Injection Enhancement in a Deep-Water Gulf of Mexico Multi Zone Completion Enabled by Downhole Multi-Position Flow Valves
Authors: Smith Kevin , Esquitin Yosafat , Cone Ryan , Fürstnow Mette , Hazel Paul , Kumar Satish 
Published: April 2023

Abstract
The Deep-Water (DW) Gulf of Mexico (GOM) fields have a complex mix of multi-layered reservoirs, with thicknesses and rock properties which can widely differ from layer to layer within the same reservoir. Injection of 25,000 bpd of water from a shallower aquifer B4 sand via a dump flood technique, benefited from a variable and controlled zonal distribution of the injection into two separate layers connected to the producer B6 Sands over life of well.
This paper presents the modelling performed to achieve optimal choke selection, specified distributions, job execution and results of utilizing multi-position flow valves as part of the 3 ½" completion with the objective of achieving the optimal injection rates in the upper and lower layers of the BB Sands.
Design parameters considered critical by Talos included a controlled and variable distribution of the injection via dump flood of 50%/50% or 25%/75% respectively for the upper and lower layer of the producer B6 Sands, with the option to selective shut-off one of the layers over time, while maintaining the 3 ½" full-bore inner diameter for future interventions.
Discussed within this paper :
The selection process to meet the required distribution rates with the extensive modelling performed using modeling software for the choke size selection, quantity, and distribution in each of the three open positions of the multi-position flow valve to achieve the total flow area required to distribute the injection at the desired rate in each layer of the producer sand, and CFD (Computational Fluid Dynamics) for the choke design. Field data from the first installment of two multi-position flow valves in a well located in the Tornado project, operational considerations that enabled the manipulation of the flow valves and a summary of the achieved results will be presented and explained.
This is the first deployment for the multi-position flow valve with variable chokes in the deep-water Gulf of Mexico well environment. The solution provided controlled injection with variable rates into the two upper and lower producer sands, this technique enables a cost-effective and reliable proven solution which can be applicable to any type of injector well, with the goal to increase the overall NPV of the field, through the increased recoverable using a predictable and safer method of downhole flow control.
Reduced Carbon Dioxide Mobility in Experimental Core Flood Using Surface Coated Silica Nanoparticles as a Foaming Agent
Authors: Alfakher Ahmad M. , DiCarlo David A. 
Published: April 2023

Abstract
Carbon dioxide (CO2) is the most used solvent in enhanced oil recovery (EOR), as it can have a high displacement efficiency in favorable conditions. Its disadvantages are relatively low sweep efficiencies caused by a viscosity and density that is lower than the fluid it displaces. Surface-coated silica nanoparticles create in-situ CO2 foam, which has a more favorable mobility ratio and therefore better sweep. These nanoparticles can also be used in carbon capture and storage (CCS) applications in injecting CO2 foam into brine aquifers.
This paper presents the results of core flood experiments that aimed to study surface coated silica nanoparticles as an in-situ CO2 foaming agent. In these experiments, pressure drop was measured across the core as a whole and in five individual sections. The core was placed vertically, and liquid CO2 was pumped at the top of the core. Surface coated silica nanoparticles suspended in the brine is used in some of the floods and compared to a control flood that had no nanoparticles.
In these experiments, pressure drops in nanoparticle cases were a multiple of 5-10 those in the control cases. In addition, total core pressure drops in nanoparticle cases increased as the core got more saturated with CO2, and the increase was observed sequentially in each section as it got invaded by CO2.The mobility of CO2 was reduced by an order of magnitude on average compared to the control. The CO2 moved slower through the core and breakthrough was delayed in the nanoparticle case.
The study provides quantitative nanoparticle CO2foam mobility measurements and calculations, compared to those in control cases. Properties calculated from this study can be used to improve both EOR and CCS applications of CO2 flooding by scaling the results to the reservoir scale.
SIIBED: Investigation of Ice Loads on Subsea Pipelines and Cables Using RHITA
Authors: Thijssen Jan , Fuglem Mark , Taylor Rocky , Afzali Soroosh 
Published: April 2023

AbstractMedium scale indentation tests have been conducted using a 12.75" diameter rigid pipe indenter, mounted on a purposely designed test frame (RHITA – Rapid High-capacity Impact Test Apparatus) and large laboratory made freshwater ice samples (approximately 4 m3 each). The purpose of this study is to collect ice failure data, representative of iceberg keel interactions with subsea pipelines or electrical cables laying on the seabed. Previous assessments of pipe response due to iceberg impact conservatively assumed no ice failure. As no widely accepted numerical models is available that captures prevalent ice failure mechanisms, experimental data was collected using RHITA. The data can be implemented in a coupled ice-pipe-soil FEA as a pressure or force limit to the ice. Also, the data can serve for calibration and validation of numerical models of ice fracture or ice crushing.The tests were executed at 0.2 m/s, a typical iceberg drift speed, on the Grand Banks of Newfoundland and Labrador. An ice mould was used to grow ice samples measuring 2.5x1.5x1.0 m (LxWxH). The top half of the ice sample was exposed, the bottom half confined by the mould. Global loads during the 2.0 m interaction were measured using six load cells, and tactile pressure sensors were used to measure the ice pressure distribution on the indenter. The test matrix includes variations of interaction depth, ice geometry, embedded rock material and ice temperature.The observed ice failure mechanisms ranged from localized damage near the interaction zone, to large fractures spanning the entire sample. The tactile pressure sensors showed the interface pressure distribution across the contact area, largely affected by local spalling events. Ice temperature and associated boundary conditions were found to affect the propagation of the cracks and resulting loads.This paper presents a summary of the tests executed from June 2022 to January 2023. Future works will include testing of rigid and flexible flowlines, and subsea electrical cable samples.
New Measurements Provide Enhanced Understanding of New York Bight Wind Resource
Authors: Eichelberger Scott , Brennan Katie 
Published: April 2023

Abstract
Understanding the wind resource potential across the New York Bight (NYB) offshore region is critically important for the winners of the Bureau of Ocean Energy Management's (BOEM's) February 2022 offshore wind energy auction. Early-stage feasibility studies and bidding strategies for the NYB offshore wind leases relied on Numerical Weather Prediction (NWP) model simulations in combination with floating LiDAR buoy data deployed by the New York State Energy Research & Development Authority (NYSERDA). While the NYSERDA buoys are hugely valuable, additional measurements in the region will be needed to further refine wind energy analyses and reduce uncertainty as the wind leases are developed and eventually financed. In this work, we will explain where TGS is deploying additional floating LiDAR buoys and show early results comparing the TGS and NYSERDA buoy data.
1D Hydro-Geomechanical Modelling of Pore Pressure on an Active Convergent Margin: East Coast Basin, New Zealand
Authors: Calderon Medina Erika E. , Obradors-Prats Joshua , Aplin Andrew C. , Jones Stuart J. , Rouainia Mohamed , Crook Anthony J. 
Published: April 2023

Abstract
This study aims to understand the causes of anomalous pore fluid pressures within sedimentary sequences of an active tectonic basin through well log analysis, pressure data evaluation and thermo-hydro-geomechanical modelling. The study focuses on the East Coast Basin (ECB), New Zealand, an active convergent margin, where anomalously high pore pressures have been encountered in deep-water systems at burial depths as shallow as 200 m.
A regional investigation including analysis of the Cretaceous to Holocene tectono-stratigraphy and diagenetic histories of the ECB, was combined with seismic and well log interpretation to understand the structural and sedimentation history of the ECB, and thus the main factors that were likely to contribute to overpressure generation/dissipation and porosity loss. 1D hydro-geomechanical models were then built to undertake a parametric study to investigate the effect on porosity and pore pressure evolution of different sedimentation and erosion rates, hiatus periods, different erosion thicknesses, and tectonic compression. The parametric models show that high overpressures can be preserved during rapid erosion events due to the relatively small timeframe for pore pressure dissipation, depending on sediment permeability. Furthermore, only recent erosion events are relevant to the present-day overpressure. In addition, high levels of tectonic compression (12.5 %) applied in recent events can produce both high pore pressure values and significant porosity reduction if the sedimentary column was undercompacted prior to the tectonic compression.
Learnings from the parametric studies were used as a starting point to understand controls on the pore pressure and porosity in the Opoutama-1 well, located on the onshore area of the ECB. Results from the Opoutama-1 well show that the high pore pressure registered at shallow depths (&lt; 1 km) in this well is significantly driven by tectonic compression as a result of high subduction rates (presently 48 mm/yr). Disequilibrium compaction also contributed to overpressure generation due to high sedimentation rates (up to ~3000 m/Ma). However, much of the disequilibrium compaction-related overpressure was dissipated during uplift, hiatus, and erosion. Where overpressure is preserved, it is related to thick (up to 1 km) mudstone packages deposited during the Cretaceous to Holocene, thin low permeable layers of limestones deposited during the Miocene to Pliocene and marl intervals with high content of smectite.
Geopressured Geothermal – Correlations to Offshore High Pressure High Temperature Geothermal Opportunities
Authors: Batir Joseph F. , Gentry Emilie N. , Soroush Hamed 
Published: April 2023

Abstract
The northern Gulf of Mexico basin contains geopressured zones ideal for geothermal energy production, still to be explored. These systems are defined by primarily Eocene to Miocene sands that are confined by shale beds, which facilitates the formation of anomalously high pressures and temperatures. The overpressure in these zones results in an increased geothermal gradient, which makes geopressured zones of interest for geothermal exploration. Resources are commonly found at 3 to 6 km depth and reservoir fluid temperatures can range from 90 to 200°C. There has been a substantial amount of work done to understand these geopressured reservoirs on the Gulf Coast for geothermal potential. Many of these geopressured zones extend and exist offshore in the Gulf of Mexico. The knowledge and technical success of wells completed in these geopressured zones onshore can be transferred to understand how to produce a high pressure high temperature offshore well for geothermal power production. This paper will provide a review of previous work on geopressured geothermal zones in the Gulf Coast, the challenges with these systems, how these were overcome, and the knowledge transfer of those findings for offshore geothermal opportunities in high pressure high temperature wells.
Technology Advancement in Deepwater Pipeline Repair to Mitigate Offshore Risk and Application Case Study of Duplex Pipe Recommissioning by ROV Operation
Authors: Hao Ziyong , Kaundal Pardeep Kumar , Liu TaoHsin , Mckinlay Samuel Ramos , Ouyang Simon , Tang Fei , Shavandi Mohsen , Cheng Chen 
Published: April 2023

Abstract
Deepwater pipeline repair planning and execution plays an important role to ensure the pipeline integrity during its service life. Due to the complexity of the work and capital associated, a more rigorous design and testing qualification program on the repair connector is needed to account for the offshore campaign risk. This paper details a complete qualification program which is compliant to the latest industry recommend practice and how the design/qualification approach can be used to scale into a different size with less testing involved after proper risk assessment. A case study describes the installation application of a scaled design in this method to recommission the Pipeline End Termination (PLET).
This paper will discuss, for the first time, the qualification program in detail to mitigate the deepwater pipeline repair or tie-in risk following the latest industry recommended practice. The paper will also present application of this technology to re-commission the subsea production system with tie-in 2 in. flexible hose by ROV.
Experience of Low Salinity Water Flooding in Mumbai High Field - First Offshore Field in India to Implement Enhanced Oil Recovery Technique
Authors: Dwivedi Siddhant , Awasthi Dheeraj K , Pandey Saurabh , Prasad Sheel Ranjan , Ram Binay , Zahir Mohammed , Bose Subhojit , Mathavan C 
Published: April 2023

Abstract
Low Salinity water flooding (LSWF) is a potential method for enhanced oil recovery (EOR). Lab and simulation studies of U-III reservoir in Mumbai High field indicates that the reduction of injection water salinity results in significant increase in oil recovery. On the basis of these studies, LSWF has been started in large pilot area in carbonate X1 layer of U-III reservoir in Mumbai offshore.
In Mumbai High Field, U-III reservoir has been under conventional sea water flooding for pressure maintenance and better volumetric sweep which has yielded nearly 30% recovery over the past 4 decades.
In search of feasible EOR process for further increase in recovery, numerous studies have been taken up in the past but high temperature, high salinity and pressure were major challenges in application of conventional EOR towards field implementation in Mumbai High. In addition, offshore conditions and multilayered reservoir with vertical and horizontal heterogeneity makes implementation of any EOR process even more challenging. After screening many EOR processes, low salinity water flooding was found to be most feasible solution which is environment friendly, cost effective and comparatively easy to implement in offshore conditions considering vast network of injection infrastructure (pipelines, facilities) already existing in Mumbai High.
Over the past two decades there has been significant growth in evidence supporting the use of low salinity water flooding as a viable EOR method. LSWF unlocks oil by improving microscopic and macroscopic displacement efficiency. It involves physical (such as fines production that can block high permeable zones thereby increasing sweep efficiency) and/or geochemical process involving complex Crude Oil-Brine-Rock (COBR) interactions. Decrease in residual oil saturation is due to resultant change in rock wettability (more water wet) thereby enhanced oil recovery. In cases worldwide, LSWF can improve the oil recovery by almost 5 to 10% as per core displacement studies and few field pilot tests.
This paper discusses the entire workflow adopted starting from EOR screening, Core studies, identification of Pilot area, Simulation studies and subsequent field implementation as a multiwell pilot. Further, the surveillance mechanism has also been discussed in this paper. The results of this pilot project will be a torch bearer for ONGC to implement LSWF in entire Mumbai High field in future.
Gimbal Joint Riser: Qualification Program of a Novel Concept
Authors: Amorim Andre Ramiro , Ribeiro Felipe Oliveira , Gomes Rodrigo Klim , Carvalhal Rodrigo do Nascimento , Diezel Alexandre Rezende 
Published: April 2023

Abstract
As oil and gas exploration is moving to deeper waters, a key challenge is to design risers in harsh environments. Steel catenary risers (SCR) are cost-effective solutions that have been used in offshore developments due to their simplicity and robustness. However, stresses at the touchdown zone (TDZ), in such configurations are very large in ultra-deep waters for FPSOs in harsh environments leading the solution to become unfeasible in some fields. Therefore, steel lazy-wave risers (SLWR), are the market solutions for those fields. Nonetheless, SLWRs are, normally, longer risers with buoyancy modules, which increases installation time and overall cost.
Gimbal Joint Riser (GJR) provides an alternative to reduce stresses at TDZ in SCRs. It is a patented device that comprises a series of hinged connection elements placed around a flexible pipe. This mechanism articulates, absorbing the energy coming from the motion of the hang-off, thus reducing stresses at TDZ.
GJR is currently under qualification process. Recently, an experimental campaign involving two small scale models have been concluded. This paper brings a summary of the improvement in the GJR development obtained from these tests. A numerical model has been built to represent the experiments and the results of the calibrated real scale model derived from the experimental outputs are also presented. Results show a significant mitigation in the compressive wave at the TDZ of between 50% to 70% reduction in energy in comparison to SCRs.