bluuebunny/crossref_metadata_2025_split huggingface dataset:
Inhouse Design and Implementation of Well Integrity Database Management System
Authors: Elrefai M. A. , Al Mutairi A. M. , Al Saadi M. , Nasser F. , Abdi R. M. , ALQamzi A. , AlNaqbi M. A. , Ashgar Ali 
Published: November 2017

Abstract
The Utilization of well integrity management and monitoring system consider a key success for establishing reliable strategic decision impacting the production targets for any organization. ADMAOPCO is a pioneer in constructing and developing Well Integrity Database Management System (WIDMS) purely in-house through integration of well integrity team and digital oil field team. The new software application provides well integrity team with full implementation for the key well integrity elements in order to achieve the objective of the company.Incorporate the current well Integrity data to the organization repository.Full integration of all related application and database, to eliminate fragmented solution to business needs.Elimination of redundant data and processes; thereby increase efficiency and productivity.To provide instant data loading facility from fields with validation capability, thereby reducing delays in decision making.Ease of use, reduction in maintenance cost, standardized training and resource development, increase support efficiency and enhance communication.Incorporate realtime annuli pressure data for wells in a staging environment for validation and then push the acceptable data into the definitive/approved WIDMS.
The in-house build Oracle base software has been used in the filed for more than 700 wells with no limit of additional wells, the software development made to serve ADMA-OPCO well integrity activites and can be expand to the other OPCO with no additional cost. Data relevant to well integrity is widespread including annului pressure management, cased hole logging evaluation, well intervention activities, downhole safety valve management, wellhead and Xmas tree management, well integrity evaluation and certification, this type of activites present a huge challenge.
Extracting the Last Molecule of NGLs - GASCO L.P Model Experience
Authors: Ramachandran Arvind 
Published: November 2017

Abstract
An ADNOC operating company, GASCO is one of the world's largest natural and associated gas processing companies, with a processing capacity of 8 billion cubic feet of feed gas per day. Processing associated and non-associated gas, GASCO operates 3 desert plants for gas processing and natural gas liquids (NGL) extraction, a Natural Gas Liquids Fractionation facility and a pipeline distribution network.
GASCO plays a strategic role in the ADNOC and UAE hydrocarbon chain, which makes it a vital enabler of industrial and economic progress of UAE. Gas yields substantial revenues from exports and is key for the country's electricity generation and water desalination. In a carbon constrained world, interest in its use is growing rapidly by all users, whether residential, commercial or industrial.
As GASCO delivers on its responsibility as an economical and sustainable supplier of gas and related products, it seeks to drive operational excellence by focusing on people, performance, profitability and efficiency.
The GASCO schematic is presented below for your reference.
Novel Electric Submersible Pump Cable Operates in High H2S Production Environment
Authors: Roth B. A. , Xiao J. X. , Paquette M. 
Published: November 2017

Abstract
Electric Submersible Pumps (ESP's) are a widely used artificial lift technology. Conventional ESP systems provide power with a cable banded to the outside of the tubing. These systems have drawbacks in terms of installation speed and efficiency. To overcome these obstacles, a novel cable-deployed ESP system developed for use in a high H2S production environment is a future solution. This paper focuses on the material selection process and validation of the nontraditional National Association of Corrosion Engineers (NACE) selected materials.
An evaluation process was developed and used early on to narrow down several potential alternatives. A metal-jacketed power cable was selected as the most viable solution since it provided the best protection to H2S attack and provided a smooth outside diameter that could be gripped on and sealed. The cable is required to withstand H2S levels up to 15% and chloride levels in excess of 150,000 ppm for a minimum of 5 years. A major challenge was developing a method to construct the system that supported the weight of the cable inside the metal jacket. The cable was qualified through extensive physical and chemical testing.
Interlocking of the metal jacket (tubing) with the inner core (cable) was qualified through extensive mechanical testing of the power cable. Testing included pull resistance, bend, thermal growth, and mechanical splice connections. Electric testing included insulation resistance. Chemical compatibility testing was performed on a number of metallurgies using a modified NACE H2S Sulfide Stress Cracking test based upon ANSI/NACE Standard TM0177. H2S test coupons of the various metallurgies were welded and formed, for testing of the tubing. The test coupons were bent to stress levels in excess of the final design stresses.
The high chloride levels caused several metallurgies to fail even at low H2S levels. A single metallurgy successfully passed all the physical, electrical, and chemical testing and will be used for field trials of the technology.
A rigorous evaluation and test program resulted in development of a novel high-H2S-rated cable-deployed ESP (CD ESP) system that can improve the speed, efficiency, and ease of ESP deployment.
Safe, Green Approach in Drill Cuttings Waste Mangement
Authors: Hussain Ibraheem , Clapper Dennis , Doostdar Nadjmeh 
Published: November 2017

Abstract
Innovative technologies offering safer and greener designs for handling and transporting hydrocarbon-contaminated drill cuttings are of great interest for offshore platforms. Traditional offshore mud skips require use of crane lifts that take up large areas of rig space and hinder continued drilling under inclement weather conditions. This paper describes a unique bulk transfer system that improves offshore cuttings handling safety and provides an environmentally acceptable solution to cuttings waste management and discharge requirements.
The bulk transfer system consists of a single remote control panel unit, intermediate cuttings storage tanks, dual-pod pneumatic transfer unit, boat tanks with a logic control system, air compressor and an onshore hydraulic tipping mechanism. The unique drill cuttings storage with pneumatic transfer technology provides a means of storing drill cuttings in non-pressurized bulk storage tanks on an offshore rig. Cuttings are transferred in dense phase over long distances and heights to the boat storage tanks arrangement, enabling continued drilling over the duration of the well section.
The rig storage tanks include a self-emptying mechanism that generates full drainage, enabling continuous collection of cuttings until they can be pneumatically transferred to the boat storage tanks at variable discharge rates of up to 60 tons per hour, depending on the drill cuttings properties. The reduced height and footprint of this system optimizes space, while its improved efficiency enables reduced downtime in operations. The pneumatic blowing pump can move cuttings over 400 feet at a rate of 20 to 35 Mt/hr continuously to the storage tanks that are mounted on the support boat, enabling continued drilling in poor weather. The boat tanks are low profile and secured by ISO locks for safer navigation and quick emptying system for faster turnaround times. When the boat tanks reach the waste management facility onshore, the drill cuttings are safely emptied by a specialized hydraulic tipping mechanism that is designed to tilt the tanks up to 85 degrees for optimized discharge. The bulk storage tanks total capacity of 320 tons (290 Mg) using (100 m2) of deck space.
This bulk transfer technology enhances operational safety by significantly reducing the use of crane lift and minimizing environmental impact while enabling continuous drilling. The bulk transfer system also offers higher storage capacity, takes smaller floor space on the rig and enables mitigation of accretion or bridging in cuttings.
Building Petrophysical Groups in a Low Permeability Carbonate Reservoir Located in Transition Zone: A Case Study from Onshore Field in UAE
Authors: Khan Muhammad Faisal , Al maskari Shaymaa , Kundu Ashish , Voleti Deepak Kumar , Al-Rawahi Ali Salem 
Published: November 2017

Abstract
The objective of this paper is to present a unique Petrophysical Grouping (PG) approach in a carbonate reservoir located in transition zone. It is very challenging, especially in Carbonate reservoirs, exist in transition zone, to establish PG definitions due to the complexities result from reservoir heterogeneities and diagenesis. Consequently establishing a suitable Saturation Height Function to match the Log derived Saturation is another challenge. In addition, the limited coverage of Mercury Injection based Capillary Pressure data (MICP) as compared to Routine Core analysis (RCA) data provides difficulties in establishing appropriate PG definition.
In first step the MICP data was used together with porosity/permeability to define distinctive groups. The PGs were further up-scaled using deterministic and Neural Network (NN) approaches. The best method was chosen by performing a test that compares the Washburn Pore Throat Radius (PTR) with the predicted PTR. To estimate a most representative log based permeability model, independent of water saturation a NN and Self-Organization Map methodologies were adapted. The limitations of MICP samples were handled by using an analog of a larger field with 100s of MICP samples. This was used to propagate the PGs to log domain by utilizing the permeability model.
Five PGs were defined using deterministic approach in which the best one is characterized having low displacement pressure, low irreducible water saturation, high pore throat radius and high porosity and permeability responses. Winland was shortlisted after testing other methods as the most applicable PG method in the reservoir as it provides the best correlation with lab PTR (94%) and the shape of WR35, consequently provides good match with computed Sw log and the shape of the PRT curve (Gunter, 2017). Regardless of the good response of NN approach the method was not chosen due to limitation of MICP data. A good relationship of Winland based PGs were found with geology and associated facies indicate strong affinity with the depositional environment and diagenetic overprints on each existing facie associations, hence a permeability model is depicted with confidence. The permeability model was executed for two geographic sectors using density, neutron porosity and GR as main inputs. SOM and NN Permeability were blind tested which resulted in more than 80% match. The predicted Sw matches with log based Sw over the entire field thus the PGs definition and propagation to log domain are considered valid.
Improved Fracture Productivity Prediction Using Enhanced Seismic Attributes
Authors: Ramsay Travis , Hernandez Luisalic , Lomask Jesse , Sullivan Allison 
Published: November 2017

Abstract
Production from unconventional reservoirs is influenced by well spacing and induced fracture placement as well as the interaction between hydraulic fractures and in-place natural fracture systems. The purpose of modeling of these complex systems is to evaluate how production can be maximized while maintaining operational efficiencies, which promote reduced well pad footprints and effective fracture stage placement.
Comingled flow conduits in unconventional reservoirs exist as amalgamated fracture systems, and multidisciplinary characterization with analysis from geologists, geophysicists, and engineers is necessary to maintain a consistent subsurface representation. To extend model fidelity in the description of complex fracture systems, a workflow was developed to evaluate the spatial constraint of natural fractures based on use of a fault indicator in cases where correlation exists between faults and fractures as a result of exerted structural controls. Use of the fault likelihood attribute in the development of an unconventional reservoir confirms that some of the better producing wells have been completed near heavily faulted zones; however, such increased productivity can also be hindered when pressure communication is established between wells associated with the same fault block.
An examination of an Eagle Ford formation was conducted, highlighting how a consistent subsurface description not only enabled increased efficiency in future wells and hydraulic fracture placement but also promoted reduced drilling and completion costs as well as increased field productivity. This was achieved by combining fault likelihood constrained natural fracture network (NFN) as well as dynamic simulation of the stimulated and external reservoir volume, incorporating a petro-elastic model (PEM) to preserve geologic continuity between seismic attributes and the simulation.
Impact of Poro-Chemo-Mechanical Parameters on Pre-Stress and Cement Sheath Integrity under Well Pressure and Thermal Loadings
Authors: Onaisi A. , Urbanczyk Ch. , Lansot J-Y. , Garnier A. 
Published: November 2017

Abstract
More and more cement compositions used for oil and gas wells, such as resilient cement with post expansion additives, are designed to obtain elastic and strength properties as well as pre-stresses in the cement sheath that allow the cement sheath to resist tensile or shear stresses induced by pressure and thermal loads emanating from the well during its full life cycle.
The computation of stress changes induced by well loads once the cement is hardened is straightforward. Those stresses will depend on geometrical parameters such as casing and hole sizes on one side and on elastic properties of casing, cement and formation on the other side. The difficulty stems from the need to compute the pre-stress in the cement sheath which is the result of complex hydraulic, chemical, thermal and mechanical interactions during hydration. Another difficulty is to measure the evolution of relevant hydro-thermo-mechanical (HTM) parameters that affect the transition from hydrostatic pressure after placement to stress with shear components after hardening.
In the recent years, Total has developed both modeling and laboratory capabilities that allow to characterize the HTM behavior of cement under in-situ pressure and temperature conditions and to use the measured parameters to analyze the mechanical integrity of cement sheath from placement on. Those tools are now routinely used to determine the best suited ranges of mechanical properties on one side and to QC and adjust cement systems proposed by service companies. This approach allowed achieving successful cementation of wells in harsh environment such as HP-HT wells.
The development of the software and laboratory facilities with internal resources proved beneficial from many perspectives. A great advantage is to be able to know how the various parameters associated with different cement compositions are affecting the cement integrity under specific down hole conditions. More importantly, it allows Total as an operating company to perform sound validation through confrontation to real field cases.
The aim of this paper is to present the fundamental concepts used in the Total's proprietary cement integrity model called T-CemInt and to describe the associated parameters and the ways of measuring them in the laboratory. Also, the paper will show a real case study that included lab tests, modeling and post cement sheath assessment with standard logging tools.
TOTAL New Production Data Management System: from the Concept to Deployment
Authors: Allanic Christophe , Trallero Jose-Luis , Vincent Aymeric 
Published: November 2017

Abstract
Actual context of low barrel prices is driving all field development cost optimizations across the oil industry. This environment is also an opportunity to extend these policies to field production operations.
Developing a process oriented Production Data Management System (N-PDMS) grounded on fundamentals, industry best practices and lessons learnt from legacy systems has been the contribution of production departments within TOTAL E&P. The approach should be good enough for handling Total's operations diversity efficiently, with full transparency and traceability. Project's main objective is to continuously improve data quality from sites to offices (affiliates and headquarter teams), partners and authorities in the host countries.
A commercial product was selected to develop the N-PDMS template embedding key production processes from Well Test to Reporting passing through Well allocation, Shortfalls, Material Balance, Forecasts, Lifting Planning, Lifting Reporting and Gas Production Program. Both Production and Injection are covered. New functionalities like production forecast, automated data capture based on standard asset models and automated historical data migrations were developed along the way.
N-PDMS template is now in the deployment phase in all operated affiliates of TOTAL E&P. This paper describes how the N-PDMS was built as a process driven project; from concepts to their deliverables in a software solution.
Improving Separation of Oil and Water Using a Novel Coalescing Centrifugal Pump
Authors: Husveg R. , Husveg T. , van Teeffelen N. , Ottestad M. , Hansen M. R. 
Published: November 2017

Abstract
A novel centrifugal pump, which increases oil droplet sizes in produced water, has been developed. This paper investigates a concept of pumping pressure optimization with respect to downstream separation efficiency, for the new pump. The investigation shows that the coalescing centrifugal pump always increases the separation efficiency of a downstream hydrocyclone. Furthermore, it is seen that the pumping pressure can be adjusted to maximize the improvement. Experimental results demonstrate how pumping conditions, which minimize the volume fraction of droplets with a diameter smaller than the cut size of the hydrocyclone, maximize the separation efficiency. Finally, it is exemplified how the concept of pumping pressure optimization can be implemented in a typical produced water treatment plant.
HPHT Sour Gas Production- Case Study
Authors: Ahmad Mubashir , Mohamed Ihab Nabil , Yousfi Fawad Zain , Al Hajri Zaher Hilal , Al Zaabi Saleem Salman , Nasr Alaa Mohamed , Romdhane Mourad ben , Albadi Mohamed Mubarak , Al Badi Fuad Shamekh , Shamlan Abdulla Mubarak , Al-Ahmed Mohammed Hasan 
Published: November 2017

Abstract
The expansion in recent years in the oil and natural gas sector has a profound implication for the continuous supply of energy in the market. There is no doubt a surge in the domestic natural gas production with tremendous opportunities as gas is used extensively for electricity generation. With the increasing energy demand, it is always a challenge to bridge the supply and demand gap. The era of sweet shallow gas is fast depleting and hence developing local sour gas production having higher concentration of hydrogen sulphide (H2S) and carbon dioxide (CO2), which are toxic and corrosive is seen as the viable solution.
Currently, ADCO took up a project to study developing the sour gas reservoirs. The objective of the appraisal program was to gain valuable reservoir data including PVT samples to finalize the facilities and full field development plan including testing the reservoir in an area where seismic data indicated better quality sweet spots.
The appraisal program was carried out and the major challenges to drill, test and produce the highly sour HPHT (High Pressure, High Temperature) gas were identified and mitigated. The data from the previously drilled wells penetrating the sour Arab zone was used to drill in the sweet spots identified but additional data was required to reduce the remaining key uncertainties to firm up the Gas In place volumes as the final results were crucial for strategical decisions.
This paper highlights the work progress and then the lessons learned during each step of the operation with the proposed mitigation to safely and efficiently drill the appraisal wells in the Arab sour reservoir having 37% H2S and 10 % CO2.
Casing Swivel Tool Greatly Expands Liner Deployment Capability in the Giant Offshore Oil Field Abu Dhabi Resulting in a World Record Single-Run 6-5/8 Inch Lower Completion
Authors: Ryan James Thomas , Alvarez Juan , Clews Matthew , Reichle Melanie , Szary Tomasz , Deschamps Benoit , Espeland Kent 
Published: November 2017

Abstract
Extended Reach Drilling (ERD) and Maximum Reservoir Contact (MRC) well design can drastically decrease development costs. A critical ERD and MRC challenge is frictional drag encountered when running long casing and liner strings. If the frictional drag becomes too great the string will stall before reaching total depth (TD), severely compromising the completion of the well. This paper presents the implementation of the casing swivel tool to effectively mitigate this friction risk.
String rotation can provide a large reduction in axial drag by shifting the friction vector to primarily affect the torsional direction. Full string rotation offers the largest benefit, but the torque required often exceeds both the casing connection rating and top drive capability. The use of a swivel enables partial string rotation above the swivel to reduce the torque requirement. With increasing production lateral lengths the swivel was moved from the running string into the liner to increase the rotating length of pipe while managing rotational torque.
The drill pipe swivel has a long history of effectively providing a reduction in axial drag by allowing for the running string to be rotated when running long MRC lower completion liners. As lateral lengths have increased from 10,000 feet up to 20,000 feet in Extended MRC (EMRC) wells, the ratio of liner length to running string length has greatly increased. To accommodate this shift in well design the swiveling point needed to be pushed deeper into the well, from running string to the liner. The fit-for-purpose design of the sacrificial casing swivel allows it to be integrated permanently into the completion and enables increased partial string rotation.
To date the casing swivel has been deployed on eight wells, including a world record single-run 6-5/8″ production liner. In one well, the liner stalled and only reached TD after engaging the swivel. The use of the casing swivel has reduced the required well count and capital investment by enabling lateral sections of up to 20,000 feet while also decreasing drilling risk due to less overburden drilling.
The application of casing swivel in the Giant Offshore Oilfield Abu Dhabi was a first for this size and length of lower completion liner. The casing swivel has become a key enabler to maximizing the length of production laterals resulting in substantial well construction cost savings.