bluuebunny/crossref_metadata_2025_split huggingface dataset:
Understanding Mauddud Waterflood Performance in a Heterogeneous Carbonate Reservoir with Surveillance Data and Ensemble of Analytical Tools
Authors: Konwar Lakshi , AlOwainati Ebrahim , Nemmawi Nadia , Michael Dowen , Ali Almuntaser 
Published: November 2020

Abstract
Bahrain oil Field being the first oil discovery in the gulf region in 1932 is now in a mature stage of development. Crestal gas injection in the oil bearing, under saturated, layered and heavily faulted carbonate Mauddud reservoir has continued to be the dominant drive mechanism since 1938. Thirty-eight 40-acre 5-spot waterflood patterns were implemented from 2011 to 2012. These patterns were located in both South East and North West part of Mauddud reservoir with a maximum injection rate of 80 MBWPD. With less than 10% PV water injected as of December 2012, premature water breakthrough was observed in most of the producers. Rapid water breakthrough in Mauddud A (Ba) is attributed to presence of high permeability vugs and layers resulting water cycling and poor sweep in the matrix leaving bypassed oil. Following recommendations from the 2013 partner Peer Assist, the South East and North West waterfloods have been converted from pattern to peripheral with down dip wells providing water injection. Peripheral re-alignment has arrested the production decline, reduced water cut and stabilized the production.
Surveillance data such production logs, reservoir saturation logs, noise logs, temperature and tracer data form the basis of understanding waterflood performance. Additionally, an array of analytical tools were used for diagnosis and analysis. Amongst the diagnostic tools, the Y- function helped to understand water cycling and sweep; the modified-Hall plot helped understand high-permeability channel or lack thereof and water-oil-ratio (WOR) gave the clue on fluid displacement. Additional plots such as "X" plot, hydrocarbon pore volume injected vs. recovery, Jordan plot, Cobb sweep plot, Stagg's plot and decline curve analysis were generated to gain insight on the sweep, recovery and remaining moveable oil of the waterflood.
Based on the waterflood analysis, a field study was initiated in December 2016 by shutting more than 80% of water injection followed by complete shut-in in September 2017. The motivation was to reduce the water cut, improve production taking advantage of gravity drainage effect of gas injectors located up dip of waterflood areas. The implementation of water injection shut-in is still ongoing in the field and pressure/production performance is being closely monitored.
This study underscores the importance of fit-for-purpose surveillance data along with ensemble of modern analytical tools to diagnose and analyze waterflood performance. This understanding also paves the way for much improved learning to take appropriate actions and help devise long-term reservoir management strategy.
Using Integrated Process and Electrical Digital Twins to Right-Size Electrical Systems and Reduce Capital Expenditures
Authors: Parker Janet 
Published: November 2020

Abstract
Electrical system design in capital projects takes place very early in the cycle because large motors and gas powered generators are long lead time items and plant assets require power during installation. This means that electrical design employs only preliminary process design data and instead relies on simple load factor formulas. Under-designing the electrical system could mean the process cannot reach nameplate capacity, which could have significant financial consequences. If a similar process unit has already been built, an accurate simulation of that process could be used to right-size the electrical system, especially if the process simulation is connected to an equally accurate electrical simulation. This would allow engineers to evaluate process and electrical dynamics to ensure electrical power always meets process demand and that the electrical design is adequate for a variety of real life scenarios, such as plant startup and shutdown, process upsets, and unplanned grid outages.
This paper explores the potential cost savings during a capital project and into the operational phase, the significant challenges in creating an accurate process simulation, and other use cases for a mixed process and electrical simulator can provide. A simple study was performed for a client where both the electrical design data and the process simulator was available to determine if the simulator was accurate enough to calculate load demand and if the motors were oversized in the unit. The crude unit was selected because it contained the largest number of medium voltage motors and was relatively easy to operate. The model and the historian predicted that the motors were oversized between 15–63%. Extrapolating the excess power to cost could reach 1.3 MUSD per year.
Unlocking Stratigraphic Trapping Potential in SE Abu Dhabi
Authors: Al Ghafri Thuraya , Liu Jinhui , Al Aufi Yousuf , Aghbari Ibrahim , Al Katheeri Faaeza , Jung Hyunyoung , El Noamany Said 
Published: November 2020

Abstract
The study area is located in the south east of Abu Dhabi, covering approximately 4,000 km2. During several prospectivity studies carried out since 2012, high exploration potential was identified for Lower Cretaceous stratigraphic traps. To resolve the Aptian subtle trap configuration and lateral seals, it was decided in 2017 to acquire a 2,146 km2, high resolution 3D seismic cube. The paper will describe the planning, acquisition, processing and current interpretation results of this seismic campaign.
Prior to the 3D seismic acquisition, a parameter design study was conducted to assess the requirements for the seismic acquisition and to insure that potential stratigraphic traps can be imaged in the newly planned 3D seismic cube. The processing was conducted on a zipper by zipper basis, allowing the processing of the acquired data while the remaining acquisition was still ongoing. It was conducted in a south to north direction, allowing the interpretation of the southern most zipper first which has greatest potential according to the existing prospectivety studies.
Initial interpretation results confirm the challenge to interpret actual clinoform shapes at the Aptian level. Furthermore, multiples initially obstructed the seismic interpretation. Additional processing was carried out to reduce the impact of multiple energy on the seismic events. It was observed that noise reduction was acheived after the integration of each zipper, as the velocity model was further improved with each step. Albeit with these challenges, attribute extraction has been proven to be highly valuable in defining clinoform trends due to the high quality of the acquired seismic. Based on the seismic interpretation results, an exploration campaign to unlock the potential of the Aptian and deeper prospectivity in the East of the study area has been planned.
For the first time in ADNOC and the emirate of Abu Dhabi, a 3D seismic survey was designed, acquired, processed and interpreted to target stratigraphic traps as the main objective. To accelerate the exploration campaign, the 3D seismic data was processed while the acquisition was ongoing. With this strategy, an 18-month turnaround from start of acquisition in December 2017 to the spud of first exploration well in May 2019 was achieved.
Low Polymer Retention Opens for Field Implementation of Polymer Flooding in High Salinity Carbonate Reservoirs
Authors: Skauge Arne , Skauge Tormod , Pourmohamadi Shahram , Solbakken Jonas , Kedir Abduljelil Sultan , Djurhuus Ketil , AlSumaiti Ali , Masalmeh Shehadeh 
Published: November 2020

AbstractPolymer flooding has been a successful EOR method in sandstone reservoirs for decades. Extending polymer flooding to carbonate reservoirs has been challenging due to adsorption loss and polymer availability for high temperature, high salinity (HTHS) reservoirs. In this study, polymer flooding for carbonate reservoirs is moved forward as we show that HTHS polymers can exhibit low adsorption and retention in carbonate reservoir rock at ultra-high salinity conditions.Carbonate reservoir core plugs with permeabilities ranging from 10 mD to Darcy range were used for the adsorption/dynamic retention studies. The dynamic retention experiments made use of water-soluble tracers as comparison for the polymer transport in porous medium. The synthetic formation water had ultra-high salinity, i.e. 180 000 mg/L TDS with a hardness of 19 %. In addition to experiments performed on single phase water saturated cores, experiments were also performed on crude oil aged reservoir core samples. The aged core samples were flooded to Sorw by water flood or by centrifugation.The implementation of polymer flooding in carbonate reservoirs has long been restricted due to adsorption and retention. Most polymers for Enhanced Oil Recovery (EOR) are negatively charged. It has long been assumed that the rock surface is primarily positively charged in carbonate rock. The argument of electrostatic attractive forces indicates high loss of polymer due to adsorption. However, the rock surface charge in carbonates may vary with presence of surface biofilms, oil layers and highly varying pore geometries. Measurements of surface charge have shown that this assumption has been too simplistic and that some surfaces are negatively charged or near-neutral due to earlier mentioned effects or ion composition, hardness and total ionic strength. Furthermore, wettability is a key factor. The results of the retention experiments on aged carbonate reservoir rock, show that retention is reduced by a factor of 4-6 when remaining oil is present. This is highly surprising when the ultra-high salinity (180 000 ppm TDS) is considered. The paper shows detailed analysis of retention experiments and discusses the influence of oil, salinity, and polymer chemistry on retention in carbonate rock.Retention is a key factor for implementation of polymer flooding in carbonate reservoirs. This study shows that new, commercially available HTHS polymers can be applied for polymer flooding in carbonate reservoirs without a high loss of chemicals. The results obtained show a positive impact on economic feasibility of polymer EOR in carbonates. The solutions found here can be applied to similar reservoir conditions and facilitate polymer flooding in HTHS carbonate reservoirs. Pilot tests based on these results are ongoing at the time of writing.
Peculiar Structural Geometry of Abu Dhabi Fields
Authors: Noufal Abdelwahab , Shehab Abdulla , Obaid Khalid 
Published: November 2020

AbstractA reasonable model for folding evolution in Abu Dhabi is presented answering the questions of the many interpretations for the folding patterns. If these folds related to the compressional forces, then why they did not represent series of anticlines and synclines? Why they dissected? Why showing different amplitudes from the deflection to the hinges zones? And finally, why the main geometry is open folding style and did not showing step dipping limbs towards the direction of the compression more than the other limb?The giant Fields of Abu Dhabi, UAE possess different geometries and structural patterns. These patterns can be subdivided into two main categories, salt related, and tectonic related. The tectonic related patterns are mainly folding related faults. Most of the fields are double plunging anticlines for the fault related tectonic and four-way domal anticlines in salt related, with few out of both possess unusual structural geometry. This paper addresses these structural patterns in order to shed lights on the trapping mechanism, in a multi-disciplinary approach of well data, seismic, potential data and outcrop analogues. The initial fold axes were determined; the axial plane and direction of heterogeneous shear displacement responding to the first folding and refolding phases were addressed. Unique shaped folds can be grouped in 6 major patterns that can be differentiated into:The first pattern evolved as dip-closed triple plunging anticline with a northeastern plunge and the southern plunge is bifurcated into two trends; SE and SW. Refold structures showing physical orientation of the first and the second fold generation in a closed pattern. Cone shaped pattern, which possess extended northern hinge zone, while the southern closure is tapering in nature. Snail and Tongue shaped patterns, which are deep rooted by salt diapir. Zigzag shaped pattern, which is mainly evolved in response of connecting pop-up structures related to wrench faults. Chevron High amplitude closed anticline, which is the only and unique pattern, as all others are open folds.A close relationship of the kinematics and timing between high-angle strike-slip faulting and upright folding is established for the Cretaceous systems. Folding accompanied tectonic denudation developing elongated plunging anticlines with fold axes both parallel and perpendicular to the direction of transpression. The strike-slip systems trending NW-SE of transpressional forces led to evolution of most of the anticlinal fields of tectonic nature in Abu Dhabi.The structural patterns of the fields and their kinematic evolution leads to understand their genetic and dynamic evolution and hence understanding the trapping mechanisms effectively.
Challenges in Execution of Brownfield Offshore Oil & Gas Projects
Authors: Kumar Naresh , Mukherjee Debarati , Paul Raju , R. Kamal Faris , Takieddine Oussama 
Published: November 2020

Abstract
The execution of large scale Brownfield Offshore Oil and Gas projects remains a challenge mainly due to space constraints on existing platforms and minimum production shutdown requirements from Client. The objective of this paper is to explain the design innovations to overcome the challenges in brownfield project execution and the implementation of electrical changeover philosophy with minimum production shutdown.
The innovative technical solutions are discussed to solve the space constraints on the existing platforms. This paper also discusses the methods to cut down the process shutdown period. Various value engineering ideas are presented to solve the actual technical issues faced on site while executing the brownfield project.
There are many challenges in executing a brownfield project. While each project offers unique set of technical challenges, some common challenges are discussed in this section. The mitigation measures to solve the technical issues are also covered below for some items. However, the value engineering ideas, technical innovations and mitigation measures for the major points are presented in next section. This section is mainly for highlighting the challenges faced during project execution.
Autonomous Inspection System for Anomaly Detection in Natural Gas Pipelines
Authors: Qassab Abdullah , Bhadran Vishnu , Sudevan Vidya , Sharma Arjun , Karki Hamad , Shukla Amit , Al Habshi Mohammed Hashem 
Published: November 2020

AbstractOil and gas industry operates according to stringent standards that primarily strive to keep the pipeline transportation and other related operations efficiently while maintaining and practicing high standards of industrial safety. Due to which, the routine inspection and maintenance of underground/overground structures became a challenging process. Over the years, performance based integrity management programmes became popular and it have been implemented for managing the safety and environmental risks associated with hazardous oil or gas pipelines. Pipeline safety and integrity team must verify, repair and certify the integrity of pipelines that could leak or failure in the future. Internal inspection using pipeline inspection gauges (PIG) are considered expensive and the need for surface preparation procedures makes the inspection operations time consuming. Whereas, external survey operations are carried out by highly trained and certified inspection/survey team where they manually identify pipeline leakages or any visible damages. External manual inspection is conducted using various handheld devices and recorded data is later analyzed to identify and locate the possible anomalies. Relatively high surrounding temperatures and uneven terrain makes the manual survey a mundane mission. The shortcomings and the challenges of the conventional external inspection and survey mechanisms are tackled by introducing a mobile robotic platform equipped with non-invasive magnetometric diagnosis (NIMD) system which allows non-contact anomaly detection from a distance of up to 2-3m from the underground pipeline metal core without unearthing or any surface treatments such as coating removal that are performed in the conventional techniques. The proposed autonomous pipeline inspection system has various sensors that can precisely locate, navigate and detect the underground pipeline faults. A novel hierarchical controller which was developed in our previous studies was utilized and employed for the navigation of vehicle over the buried infrastructures. The effectiveness and the performance of autonomous system was tested on real field conditions and the true ability of the system was showcased to detect the underground pipeline anomalies even in extreme environmental conditions.
Utility of Image Logs in Understanding Flow Profile Patterns: Case Study from Onshore Field, UAE
Authors: Girinathan Sajith , Al Zeyoudi Fatmah , Pillai Anit , Kutty Abdurahiman , Ayoub Walid 
Published: November 2020

Abstract
This paper displays an example of the power of data integration. Multiple sub-surface datasets viz., Bore Hole Images (BHI), triple-combo logs, core data, production logs and geomodels were tied together to throw light on suspicious injection profile patterns observed in a horizontal well drilled in the Thamama Group. This well was drilled in an onshore green field.
The production log provided information on injection profile patterns and quantity of fluid intake per zone along the drilled well path. Bore Hole Images (BHI) were processed and analysed for structural features including fractures and faults. Advanced analysis was performed on BHI to gather information on diagenesis along well path. Emphasis was put on extraction of moldic (vuggy) porosity content. Allied LWD resistivity, density, gamma ray and porosity logs were used to calibrate and back-up BHI-based findings. Core descriptions, core photographs, and petrographic analysIs results from offset vertical wells were looked-into in detail to understand diagenesis better, in the adjoining area of candidate well. Structural events identified at well scale were calibrated to field-scale using up-to-date geomodels.
The integrated approach helped in comprehending flow profile patterns in candidate well. Prior to this study, it was assumed that the observed flow profile behavior was related to factors like tool malfunction, well trajectory and even large open fractures. However, post-study findings revealed clear diagenetic control on injection profile (and zonal intake). The role of fractures were observed to be minimal to negligible in this case.
A Novel Approach to Maximize Revenue by Maximizing the Condensate Production in A Giant Field Using Molar Fraction Optimization in an Integrated Production System Platform
Authors: Alsaeedi Ayesha Ahmed , AlHarethi Fahed Ahmed , Alsenaidi Shemaisa Ahmed , Al Bairaq Ahmed Mohamed , Soni Sandeep , Tripathi Deepak , Hidalgo Melvin , Alkuwaiti Hamda 
Published: November 2020

Abstract
Meeting the gas production target while maximizing the total gas condensate and hence the revenue from condensate reservoirs is one of the key business drivers for an operating company. This paper describes a comprehensive simulation process to strategize production optimization, which helps in meeting the target molar fraction at the delivery point from the overall asset producing from complex reservoirs with varying fluid properties and achieving the overall target of lean gas production.
This process uses an integrated approach encompassing the various nodes in a production system, starting from reservoir to the export system to assure a representative and accurate prediction. In the first step, using the representative fluid model and the desired target production from the field, the well capacity-based rates are allocated to the individual production strings. In the second step, a component level optimizer is used to estimate the contribution of each well based on the well production stream composition. In the third and final step, this contributed production figure is fed back to the surface network hydraulic simulator to assess the back-pressure impact on the overall production and the achievable field-target.
The objective of maximizing the condensate production was fulfilled considering the provided constraints of operating guidelines, reservoir, wells, and surface facility capacities. Two different scenario runs were put together where the target gas production was achieved while increasing the condensate production by maximizing the condensate specific molar components and minimizing the heavy molar components. The expected condensate production was forecasted to increase by 5% in the scenario.
As the predictive hydraulic model is seamlessly integrated with the true field operating conditions, the outlined optimization process ensured that various business-scenarios accurately forecast the system behavior under various operating conditions. In the scenario, the forecast was able to maximize the condensate while meeting the production target within 1% tolerance limit.
The outlined approach provides a clear step by step standardized process approach which can be expanded to cater to the other business needs, such as minimizing the H2S for reducing the corrosion problem, minimizing the C7+ components to produce a high-quality condensate.
Such a framework based standardized methodology incorporates a seamless integration between the molar composition optimization and the associated hydraulic calculations-based optimization. Solving the both objective optimization functions simultaneously, this approach provides a novel way to address a vital industry business objective.
Fast Power Anywhere: Reaping the Benefits of Mobile Gas Turbine Packages
Authors: Balestrino Cristiano 
Published: November 2020

Abstract
In the oil and gas industry, a dependable supply of electricity is critical to safe and profitable operation. Currently, many oil and gas facilities throughout the Middle East and North Africa (MENA) region rely on damaged and/or aging power infrastructure to meet their electricity needs. This paper discusses the benefits of utilizing mobile gas turbine (GT) packages that can be rapidly deployed to provide reliable power within in a matter of weeks, days or even hours. The packages can be used to provide fast, scalable power, supplemental power or serve as back-up in the event of extended outages.
The paper outlines the capabilities of multiple mobile aeroderivative GT models, with a particular focus on the SGT-A45, which is currently the world's largest mobile aeroderivative unit in terms of power output. The GT package is designed to enable delivery of a complete power plant solution on a fast-track basis, with each unit pre-assembled on trailers and tested at the factory in order to verify operation and performance and minimize the scope of commissioning work needed at site. The self-contained, plug-and-play design reduces the installation time needed at site to only two weeks and minimizes "Balance of Plant" equipment.
The high power density and compact footprint of the aeroderivative mobile unit minimizes usage of real estate as a back-up power solution. As an example, a 4X units installation can provide approximately 175 MW at ISO within just one hectare (2.5 acres) of land.
For illustrative purposes, a case study is presented in which the SGT-A45 was deployed for a gas-fired power generation facility. The facility currently provides power to approximately 200,000 homes in Afghanistan. The paper will describe how the technology has addressed the specific challenges of this application to provide critical support to the country's development and infrastructure.