bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of Wormlike Micelles for Mobility Control in Chemical Enhanced Oil Recovery
Authors: Kumar Sandeep , Kalwar Shuaib Ahmed , Abbas Ghulam , Awan Abdul Quddos 
Published: November 2018

Abstract
Mobility control is one of the most important parameters in chemical enhanced oil recovery (CEOR). Hydrolyzed polyacrylamide (HPAM) polymer, the standard mobility-control agent, is often degradable and causes poor sweep efficiency under changing shear rates and at temperatures above 140 °F. Under these conditions, HPAM solution loses more than 90% of its viscosity and is unable to sustain appropriate viscosity necessary for residual oil displacement. Therefore, a wormlike micellar (WLM) solution was developed as a substitute mobility polymer for CEOR applications. The WLM solution is composed of chains, bonded by electrostatic forces, which can deform and reform rather than permanently breaking down when subjected to high shear rates and temperature fluctuations.
In this study, two compositions of WLM solutions were chosen and prepared in the laboratory. For each of these two solutions, their effectiveness was determined by comprehensive thermal compatibility tests; interfacial tests (IFT); and rheological tests to evaluate the impact of concentration, shear rates, salinity (NaCl = 3.5%, CaCl2 = 0.05%, and MgCl2 = 0.05%), and temperature (86 to 158 °F) on viscosity. Next, the core displacement test was performed to examine the residual oil displacement by a mixed-surfactant WLM solution (zwitterionic surfactant 1.09% w/v, R = 0.55).
Test results determined that both of the tested WLM solutions showed great potential in high-salinity and high-temperature conditions. Each of the two WLM solutions was equally adaptable and unrestricted, despite differences between the components of each formulation. With the addition of salts, the WLM solutions were highly tolerant over the entire range of shear rates. At 158 °F, the thermal degradability of WLM solutions was less than HPAM polymer. In addition to this, IFT between crude oil and WLM solution was also observed to be very low compared to the typical water-and-oil system. Moreover, the WLM solution produced an additional oil recovery of 10.9% beyond secondary recovery during the coreflooding test. Hence, the results supported WLM solutions to be potential mobility control for CEOR.
WLM solutions have been successfully shown to perform beyond the salinity, temperature, and shear-rate limitations of HPAM polymers. This makes WLM solutions more flexible, not only for EOR applications, but also for well completion, well stimulation, and for coiled-tubing cleanout processes following gravel-pack operations.
Reservoir Health Indicators Driving Performance Through Data Analytics
Authors: Al Marzouqi Mohamed , Saputelli Luigi Alfonso , Abdou Medhat , Narayanan Ram , Mohan Richard , Ismail Ayat , Escocia Alvaro 
Published: November 2018

Abstract
Reservoir management leverages on surveillance practices to diagnose reservoir conditions which aid in the identification of treatments that maximize the business value of reservoir deliverability while protecting the long-term sustainability. However, operators struggle to exploit value from data because of big data avalanches, data dispersion and ambiguity in the data definitions across department and companies.
Typically, operators are satisfied by meeting average targets within certain tolerance. This is obtained by calculating the ratio of plan vs actual performance. In this work, reservoir management excellence is pursued by an integrated review of leading and lagging indicators, which are represented by continuous and proactive KPI computation and monitoring.
The objective of this work is to simplify reservoir performance data analysis on such a way that performance management is decomposed in 5 key areas (business, operation, quality, recovery and predictability) driving continuous improvement, and yet establishing a culture of variance reduction and sustainable consistency in results delivery.
The scope of this work entails the definition and case studies of implementing performance indicators that facilitate the analysis of reservoir performance and field development strategic decisions. Such indicators are leading pointers of quality, recovery status and predictability, which ultimately affect business and operations performance at multiple time scales.
A solution to continuously compute reservoir health indicators and assure reservoir performance is implemented across various assets, leveraging big data management with automated scheduled extraction, transformation and loading (ETL) capabilities. Raw and calculated data are further provided to end user via commercially available business intelligence (BI) analytics. Each indicator measures the compliance between actual and planned values, and the roll-up is done by computing the volume-weighted average of each underlying element. For this purpose, key performance indicators (KPI) are calculated and creatively concatenated from well to reservoir level, from reservoir to field level and from the field to the operating company level.
KPI rollout showed a new way to report and monitor performance on a proactive, sustainable and cost-efficient manner. Some of the realized benefits included reducing more than 90% the time require to identify variances between actual performance and expectation during the execution of projects and improving compliance to the reservoir management guidelines from ~61% to ~84%. This ensures long-term production sustainability while mitigating shortfalls proactively.
Sub Seismic Fault Identification within Carbonate Reservoirs with Borehole Images Logging-While-Drilling: Integrated Approach in Optimizing Well Placement; A Case Study from Offshore Abu Dhabi
Authors: AL-Hassani Sultan Dahi , Ahmed Shafiq Naseem , Khan Owais Ameer , AL-Tameemi Ibrahim Mohamed , Khan Shahnawaz , Marza Philippe , Abdulrahim Jaja Uruzula , Shasmal Sudipan , Alexander Malcolm 
Published: November 2018

Abstract
Reservoirs located offshore Abu Dhabi can be complex in terms of sub-seismic structural features such as faults and localized deformations. With use of high-resolution resistivity image logs, a TST (true stratigraphic thickness) technique, along with 3D structural models, uncertainties related to sub seismic structural ambiguities are resolved and well trajectory is optimized while drilling.
In this case study, real-time resistivity image logs were used while drilling. The sinusoid’s shape on images provided cutting down dip or up dip information. Dip trends were analyzed using a dip vector plot and to identify zones-of-interest. Dip attribute along with the log response were compared with the pre-job model and the inclination is adjusted accordingly during drilling. Several high angle features can be characterized as stratigraphic changes, fractures, or faults. The morphology and trend change observed in the dip vector plot of these features lead to the conclusion that these are sub-seismic resolution faults and deformation is associated with the fault.
The stratigraphic drilling polarity and the TST were calculated using the formation dip data. Using a TST scale and splitting the logs into stratigraphic drilling polarity domains, the fault throw displacement is estimated. The model is updated to reflect the interpreted data. The fault plunge and trend are extrapolated away from the wellbore and to nearby wells.
Novel Scavenger Technology for Effective Removal of H2S from Produced Gas in Oilfield Applications
Authors: Ramachandran Sunder , Lehrer Scott , Chakraborty Soma , Jani Jagrut 
Published: November 2018

Abstract
Hydrogen sulfide (H2S) scavengers are used to reduce the total well operation cost of working with H2S by reducing the need for gas sweeting equipment, manpower costs for H2S monitoring, fines due to out of specification production and liability due to H2S release. Commonly used H2S scavengers such as triazine and glyoxal have limitations in different applications. When overspent, triazines can form difficult to remove solid deposits. The prescence of triazines in crude oil can lead to the formation of amine hydrochloride salts that cause corrosion in refinery operations. Glyoxal based H2S scavengers are acidic and can cause corrosion especially in stagnant pipelines containing oil and water. In this paper laboratory and field results are provided on new H2S scavengers that are both non-amine and neutral pH. The applications that are examined are batch tower applications and inline injection.
ADNOC Gas Processing Experience in Hydrocarbon and Acid Gas Flare Recovery Utilizing Liquid Ring Compressor and Dry Screw Compressors
Authors: Ramasamy Babu 
Published: November 2018

Abstract
The gravity of this paper submission is to intimate and share that ADNOC Gas Processing, a group of ADNOC (Abu Dhabi National Oil Company) launched and implemented recently a considerable number of flare gas recovery projects like Habshan Hydrocarbon Flare Gas Recovery, Habshan acid gas flare recovery, Habshan-5 Hydrocarbon Flare Gas Recovery, Habshan-5 acid gas flare recovery and Habsha-5 flash gas recovery with great success.
The purpose of these projects is to recover low pressure hydrocarbon and acid flare gas, compressor and inject into gas network for further downstream processing before converting it to sweet gas for sale or use for other applications.
Integrated Asset Modeling Assists Brownfield Rejuvenation
Authors: El Faidouzi Mohamed Mehdi , Al-Katheeri Walaa Anees , Fathalla Magdy Farouq , Bedewi Mahmoud , Kedia Rachit 
Published: November 2018

Abstract
An integrated asset modeling (IAM) approach was used to evaluate a reinvigorated facilities configuration for a mature giant oilfield offshore Abu Dhabi. The field has produced for 50 years through steel jacket-based "supercomplex" facilities. A new artificial islands-based strategy has been envisioned to cater to higher production requirements, replace ageing facilities approaching their design lives, and debottleneck the water and gas handling capacity.
Commercially available reservoir simulation software was used to develop the integrated reservoir simulation model. The IAM fully couples three compositional simulation models for each reservoir unit to an extensive pipeline network and incorporates the timely rerouting of existing facilities to the new processing centers. Eventually, the "supercomplexes" only receive wellstream fluids from the existing wellhead towers (WHTs) network and redirect production to the new centralized processing island where it goes through a three-phase separation. Recent pressures and production data were used to calibrate the IAM.
The IAM was successfully used to evaluate the impact of the new surface layout on production. The production profiles from the standalone models, based on constant terminal node pressure at the wellheads, were compared to the IAM profiles. Pragmatic guidelines were defined to obtain representative profiles from the standalone models. Additionally, the IAM was used to guide the future facilities design by addressing the sizing of the water and gas handling capacity and identifying future surface bottlenecks. Moreover, the compositional IAM allowed quantifying the H2S content in the stream. The reservoirs being drained have varying levels of H2S, and prediction of the gas sourness is an important parameter for separator and pipeline design and for determining the sale gas value. Finally, the IAM had flow assurance applications, such as assessing the changes in pipeline temperature. Indeed, as the field matures, wells are forecasted to produce more water, raising the field water cut from the current 7% to 20% in the next 10 years. This increase in water cut would increase the pipeline temperature. The IAM allowed forecasting of the steady-state pipeline temperature to ensure existing pipelines are operated within specifications and to help design future flowlines.
Corrosion Management, Field Trial Results of High Pressure Black Bimodal PE100 HDPE Liner in a Super Gigantic Field Provides Innovative Strategy for High Pressure Water Injection Flow Line Internal Corrosion Management
Authors: Amabipi Abby Kalio , Salem Marwan Hamad , Grandhe Siva Prasada , Gupta Tijender Kumar , Awah Mohamed Ali , Schell Jeff , Compton Ted , Herbig Nicholas 
Published: November 2018

Abstract

Objective
Internal corrosion in high pressure water injection flow lines is a very serious problem in the ADNOC super gigantic onshore fields. This issue has resulted in frequent pipe leaks and water injection flow lines outage which adversely affected oil and gas production due to failure in meeting the required water injection. This paper illustrates successful cost efficient innovative application strategy of the HDPE Liner technology in mitigating internal corrosion problems in water injection flow lines.

Methods
Innovation centers of some petrochemical companies have now made available "BIMODAL PE100 POLYETHYLENE" materials which are suited for high pressure pipes and able to provide extra flexibility and safety in case of surface scratches in highly deviated flow lines. This paper presents the detailed preparation of the HDPE material, installation, intensive monitoring program, results and integrity challenges of the technology validation in 3km pipeline. A rolling machine reduced the OD of HDPE liner by 7% before drawing into the flow line by a pulling machine, the HDPE OD expands back to full size to give a tight fit in the flow line after sometime.

Results
The field trial was initiated in June of 2011 and actual installation completed in two weeks. The Liner conditions were monitored from 2011 through 2017. The flow line section protected with HDPE liner still operates in excellent conditions without any sign of corrosion up till date. This is a technology break through that eliminated internal corrosion threats with huge Opex savings in chemical treatment programs as no chemicals were applied. This Technology is now at the implementation stage in the ADNOC super gigantic onshore field.

Novel
The paper elaborate on the value added to the company and possible areas of application of the technology for maximum benefits. Finally, this technology has clear impact on the internal corrosion management process that guarantees proper flow line long-life innovative design strategy and provides alternative solutions to conventional flow line designs.
Feasibility Analysis and Field Application of Waste Oily Sludge Resource Utilization Technology in Oilfield
Authors: Wang Yao , Wang Siwen , Li Rui , Wang Hao 
Published: November 2018

Abstract
Oily sludge is one of the main wastes produced during oilfield development. The composition of oily sludge is complex, resulting in difficult separation and high processing cost. The existing technologies such as landfill, microbiological deterioration, heat treatment and solvent extraction are difficult to meet the needs of oily sludge treatment. It is necessary to develop a highly efficient and cheap reutilization technology for oily sludge. For this reason, we have proposed to recycle the oily sludge which can be utilized to profile control in water injection and thermal recovery wells.
In the process of research, we have developed five aspects of work: First, three-phase separation of oily sludge was carried out by distillation, and water quality, oil-phase composition and solid particle size were analyzed. The compatibility of oily sludge and oil reservoir was investigated. Second, the mechanism and influence factors of the oily sludge for profile control were studied by long core model test and microscope observation. Third, suspension analysis and mobility analysis were developed on oily sludge, and experimental results were used to research oily sludge profile control agent. Fourth, numerical simulation was used to optimize the engineering design of Oily Sludge Profile Control (OSPC). Fifth, ground process flow of oily sludge for profile control was designed.
The following conclusion can be drawn from the study: OSPC is a Reutilization Technology for oily sludge, which could seal up oily sludge in-situ in oil reservoir and be favorable for increasing production of oil wells through profile control. Through the rheology and plugging test, it was clear that OSPC could greatly reduce the pollution risk of oily sludge and the ground treatment cost, and solid phase and oil phase of mud were retained in the formation. It could plug high permeability channels and high permeability area (the plugging rate was more than 90%) to adjust water/steam injection profile of water/thermal recovery wells. Profile control agent, engineering design method and ground process flow for oily sludge were developed. The technology applied 72 wells in the oilfield, 184 thousand tons of oily sludge were used in total, production of crude oil was increased by 84 thousand barrels, and a lot of sludge treatment costs could be saved.
Precision Gas Sensing Based on THz Spectroscopy
Authors: Assefzadeh M. Mahdi , Jamali Babak , Babakhani Aydin 
Published: November 2018

Abstract
In this work, we introduce a spectroscopy system based on an electronic source that can radiate terahertz frequency combs to perform broadband spectroscopy of trace gases. A single-chip source provides us with a highly compact and cost-effective system in comparison with a laser-based source, and a faster response time in comparison with chemical sensors. We have performed THz gas spectroscopy using three different gases, H2S, NH3, and H2O. These measurements have been performed at 575, 736, and 754 GHz.
Challenging ICD & Swell Packers Completion Running in 3D Complex ERD Well With Continuous Swiveling to Break Frictional Drag and Helical Buckling
Authors: Singh Rudra Pratap , Paila Phalgun , Al-Kindi Rashid Khudaim , Al-Wahedi Khalid Ahmed , Kirby Cliff , Blakely Michael , Christie George 
Published: November 2018

Abstract
Extended Reach Drilling (ERD) from the artificial island is particularly challenging for anti-collision, directional drilling and wellbore construction; facing various issues including but not limited to wellbore instability, hole cleaning, tortuosity, torque and drag etc., affecting the completion liner running and its ability to reach the setting depth especially in the smaller hole sizes. This paper describes the application of ground-breaking technology that enables completion liner with multiple ICDs and Swell Packers to be deployed at setting depth in ERD well maximizing oil reservoir production and saving cost.
In 3D complex well profiles, while running conventional completion liner string, frictional drag is cumulated along the string, exposing the same to sinusoidal buckling which is further elevated to helical buckling and consuming the load available from surface to transfer to shoe, ultimately preventing the string to reach the setting depth. The buckling is even more severe in smaller hole sizes like 6" hole section where tapered drill string with 4" DP against 7" liner is used to run lower completion.
By allowing a portion of the string to be rotated, significant amount of axial friction is converted from drag to torque and provides additional hookload at surface to push the string to TD. This selective rotation is enabled by the integration of a Swiveling Tool into the string above the Liner Hanger. The tool has been tested in a development well in an artificial island of offshore Abu Dhabi. This was the longest well drilled by operator with measured depth of 24,414 ft (Horizontal departure +/− 20,000 ft, 6" drain hole length +/− 5,200 ft).
Later this technology was implemented in most of the challenging 3D complex wells and the Swiveling Tool became part of completion running string (4-1/2" Liner with ICD's and swell-able packers) based on the T&D simulation results if they indicated very little or no margin of drag available prior to string lock up which might make it impossible to reach setting depth.
This paper describes a structural approach towards running 4-1/2" lower completion with ICD and swell packer in 3D-complex ERD well utilizing swiveling tool to ensure completion is run to the desired setting depth. The proposed tool can be implemented any project worldwide where buckling could prevent running lower completion and there is restriction to rotate the lower part of completion or if there are chances of having obstructions due to hole condition/geometry.
Correlation Between Drilling Parameters and Lithology - The Hidden Geological Information of Drilling Data
Authors: Lamik-Thonhauser Bouchra , Schoen Juergen H. , Koller Christian S. , Arnaout Arghad M. 
Published: November 2018

Abstract
Drilling process is fundamentally controlled and influenced by the properties of the penetrated formation. The focus of various studies is directed mainly on the optimal design of drill bit and drilling operations related to the (expected) geological situation of a safe drilling process.
Out of interest the question "Is it possible to extract any lithologic information from drilling data?" also arises.
The drilling process at the bit represents a complicated rock mechanical process. The drill bit acts as a rotating cutter, controlled mainly by weight on bit (WOB), bit size, number of revolutions per time (RPM), which controls speed of the cutting process. We define a "cutting force Fc" as a combination of these parameters and investigate the relationship between Fc and rate of penetration (ROP). For the correlation with lithology of penetrated formations, two methods are applied on test wells:
– crossplots Fc versus ROP with discrimination for dominant lithology. – histograms of the ratio of two variables for dominant lithology.
Drilling data from two basins are analyzed (in both cases wells are nearly vertical):
– Vienna Basin: Dominant lithologies are sandstones (varying degree of cementation), shale/marls, limestones, and dolomites. – Williston Basin: Dominant lithologies in the analysed section are sandstone shale, dolomitic limestone, and limestone with anhydrite.
Data points from the rocks with similar lithology in the crossplot are situated in a cloud - different rocks show different cloud position. Particularly between clastic (sand, silt, shale) and carbonate (limestone, dolomite) rocks, a clear separation is visible.
The implementation of lines for a constant ratio Fc/ROP in the crossplot separate the different lithologies. Therefore, the statistical distribution of this ratio S = Fc/ROP for the dominant lithologies was analyzed by histograms. For the two test wells, histograms separate the different lithologies and confirm the information content.
The drilling process is controlled by rock type; the analyse of drill-process data can be used for a lithological discrimination and especially for detecting changing lithology (boundaries) during drilling process. For two test wells, the discrimination could be demonstrated by the crossplot and histogram technique. The exact position of discriminator magnitudes (center of data clouds in the crossplots, peaks in the histograms) is specific for the considered field and may be controlled by more drilling parameters.