bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Development and Field Testing of Novel Online Salt-in-Crude Oil Measurement Method and Analyzer - A Systematic Approach to Technology Qualification
Authors: Duval Sebastien , Less Simone , Szczebiot Ryszard , Prada Iran Charry , White Ramsey , Al-Khabaz Sajjad , Vilagines Regis 
Published: November 2017

Abstract
This paper describes a new approach to online monitoring salt content in crude oil. An extensive experimental study was conducted in the laboratory on different crude oil types, to evaluate accuracy and repeatability of the new method in comparison with the existing standard, the ASTM D3230. Following the successful laboratory study, an industrial prototype based on this new method was designed, installed in a production facility, and tested for 6 months.
Maintaining crude oil production rate and quality are the primary targets of any oil producer. Salt (defined here summarily as a mixture of Na, Mg, and Ca chlorides) is one of the undesirable crude oil contaminants that affects crude oil quality. Salt is mostly entrapped in the micron-sized water droplets carried out from the last separation vessel of oil production facilities. While measuring salt content per the existing ASTM D3230 standard offers no difficulty in laboratories, implementation of online measurements remains very challenging.
Commercial analyzers based on the ASTM D3230 mix crude oil with three different solvents (Xylene, Methanol, and Butanol) and measure the mixture conductivity. Due to their numerous moving parts, commercial online analyzers’ reliability is low and maintenance is difficult and costly. Additionally, procurement, storage, and handling of these highly flammable, toxic, and low boiling point chemicals are not practical in remote areas or offshore production sites.
Saudi Aramco Research & Development Center and Saudi Aramco Oil Operation worked jointly to simplify the measurement protocol by replacing the three hazardous solvents with a relatively harmless single solvent. This solvent is very stable and has a high boiling point; consequently, it can be stored in large quantities, which significantly reduces the frequency of replenishments and limits the operator’s exposure to chemicals. The application of the new single solvent method has multiple advantages: ∘It reduces moving parts and complexity, and hence the fabrication and maintenance costs of industrial online analyzers.∘It reduces solvent consumption, as the solvent/crude oil mixture ratio is 50/50, in comparison with ASTM D3230 ratio of 90/10, thus further reducing the operating costs.∘It increases salt content in the measurement cell because of higher crude oil to solvent ratio, thus improving accuracy.∘It can be implemented by simple modifications to existing commercial analyzers.
Drilling while Casing Extended-Reach Wells?What is the Limit?
Authors: Li He , Gao Deli , Li Xin , Sun Fengrui , Liu Yongsheng 
Published: November 2017

Abstract
As an innovative drilling method, Casing-while-Drilling (CwD) was first proposed to reduce the non-productive-time (NPT) required to trip the drill pipe and run the casing. However, several case studies have confirmed the plastering effect it produces during the implementation of this drilling method. The plastering effect, which refers to "plastering" drilled cuttings and lost circulation materials (LCMs) on the wellbore wall to form an impermeable mud cake and simultaneously plug the induced fractures, can strengthen the wellbore wall and provide a wider safe mud weight window (SMWW) during the drilling process. Thus, the models published before to predict the maximum allowable measured depth (MAMD) of extended-reach-wells (ERWs) drilled with conventional drilling method should be amended for CwD with consideration of the plastering effect it produces.
In this work, a prediction model of the MAMD of ERWs drilled with CwD considering the plastering effect is presented. Two kinds of strengthening mechanisms (i.e., the fracture based and non-fracture-based wellbore strengthening mechanisms) are properly combined to quantify the resultant improvement of the fracture pressure gradient by the plastering effect. Meanwhile, the factors that affect the MAMD with CwD are also investigated.
The results show that, for non-fracture-based wellbore strengthening mechanism, the impermeable mud cake formed by plastering effect significantly improves the fracture pressure gradient. Whereas, the thermal effect caused by continuously contact of the casing string with wellbore wall is not obvious for the resultant improvement. Besides, the wellbore will be strengthened a lot by plugging the induced fractures with the drilled cuttings and LCMs during the drilling process. Although forming mud-cake with low porosity and permeability can contribute to a higher fracture initiation pressure (FIP), it will inversely decrease the fracture re-initiation pressure (FRIP). Thus, the factors that play a positive role in non-fracture based wellbore strengthening mechanism may impair the effect of fracture based wellbore strengthening mechanism. Therefore, these influencing factors should be properly combined, in order to attain a greater MAMD with CwD method.
The Evaluation of the First Biodegradable Diverter in Acid Fracturing in Kuwait: Case Study
Authors: Al-Othman M. R. , Elmofti M. , Bu Hamad A. , Alhouti N. B. , Al-Haddad M. N. , Al Hamad A. M. , Allam A. , Eid W. 
Published: November 2017

Abstract
Numerous methods have been applied in matrix acidizing over the previous decades to successfully stimulate multiple zones. These methods have also been implemented in fracture acidizing with varying degrees of success. This paper discusses the application of a new biodegradable material used for diversion in multiple zones or long formation intervals and presents improved results obtained using a new biodegradable diverter.
Acid-fracturing diversion can be more challenging than diversion for matrix acidizing. To effectively stimulate multiple or large zones, the diversion treatment should be able to bridge not only the perforations themselves, but often inside the fracture system as well. This can be difficult because acid reacts with the rock, forming an etched/enlarged path, thus the diversion also requires bridging inside this conductive path. This differs from matrix acidizing techniques, in which the diversion depends mostly on the perforations in an interval(s) and the stimulated reservoir permeability. Historically, several methods have been implemented for acid-fracturing diversion, such as ball sealers, viscous fluids, packers, etc., resulting in limited success or cost-ineffective results. The new biodegradable material helps improve acid fracturing diversion success in multiple zones or long formation intervals.
The development of this biodegradable material is discussed along with a case study. Also, details are provided of the biodegradable material evaluation that consists of 1) pre and post-temperature logs, 2) pre and post-injection logging profiles, 3) pre and post-production history, and 4) further recommendations. The results of the evaluation methods show that the biodegradable material can be used as an effective alternative diversion method to seal existing perforations and effectively stimulate all perforated intervals. Production increased more than threefold, and the targeted fracture height was achieved based on the temperature log data.
Design of Safe Well on the Top of Atharamura Anticline, Tripura, India, on the Basis of Predicted Pore Pressure from Seismic Velocity Data
Authors: Brahma Jwngsar , Sircar Anirbid 
Published: November 2017

Abstract
Pore pressure prediction is essential part of wildcat well planning. In India, Tripura sub – basin is characterised by huge anticlines, normal faults and abnormally pressured formations. These factors push the wildcat well planning in this area into wide margin of uncertainty. Pore pressures were predicted from seismic velocities by using modified Eaton’s method over the synclinal and flank part of Atharamura to understand the pressure succession towards the anticline. These predicted pore pressure on the flank part lead to a reasonable match when plotted with offset well measured pore pressures. To reduce the uncertainty fracture pressure were established by various methods such as Hubbert & Willis method and Matthews & Kelly method from predicted pore pressures. But the fracture pressures were predicted with available horizontal stress correlations due to lack of Poisson’s ratio curve for the study area. The mud pressure required to drill the well is calculated using median line principle and hence drilling mud window is established by assuming virtual tight conditions. The plot of Equivalent Circulation Density (ECD) versus depth suggest that well can be drilled with two casing policy. But it is found that adding one more casing pipe will ensure the safety of well. Casing pipes were designed on the basis of collapse pressure, burst pressure and tensile load. Finally a well plan which includes pore pressure, fracture pressure, drilling mud policy, casing policy, kick tolerance graph were proposed to give clear picture on well planning on the top of the anticline in pore pressure point of view.
Normalized Depths as Key Input and Detailed QC Steps for Improved Permeability Predictions Using Existing Machine Learning Techniques
Authors: Voleti Deepak Kumar , Kundu Ashish , Singh Maniesh 
Published: November 2017

Abstract
Because of advance computing technologies, machine learning today is widely used for many types of prediction. The performance of existing prediction techniques has been quite acceptable but still it needs improvement. In oil industry, this type of machine learning is being used for Permeability prediction. In case of homogeneous reservoir, conventional permeability prediction techniques are very well documented in the available published literature and are easy to be implemented however, it is a real challenge in case of complex carbonate reservoir which are highly affected by diagenetic overprint. The machine learning algorithms exactly does according to what user had trained for it. It get confused either if it receives a new unseen input for which it was not trained or it has multiple answer to the same input. This study shows that by using selective intelligent inputs (quantitative factors influencing permeability) and with proper segregated and intuitive training to machine it is possible to gain better correlation between different inputs and a reliable permeability prediction can be achieved.
The studied Early Cretaceous reservoir has a large areal extent with 20% average porosity and large range of permeability, from 0.1 to 1000 md due to preferential diagenetic processes over large variety of lithofacies. Capturing high permeability streaks/zone simultaneously with low K intervals was quiet important to understand the fluid flow dynamics and hence was a real challenge in this project. This paper describe the workflow developed to analyze data in different dimensions away from the conventional ways, detailed QC steps and preparing the intelligent input data sets (Normalized depths, Rock types, zonal and sectorial flags, synthetic permeability guide curve, etc.) which facilitate the machine to make a best decision and output optimum results. This paper shows two- point normalization method to bring reservoir depth interval between 0 to100 and pick up consistent permeability profile in each sector which correlates better to stratigraphic framework.
In this study, the models were built with 3081 CCA data from 30 spatially distributed cored wells and blind tested on 10 other cored wells; later these models were used to predict permeability in 210 uncored wells. Comparison of the predicted permeability with the well test permeability shows Ktest/Klog in the range of 1.05 to1.6 suggesting fair to very good reconciliation. The normalized depth vs. predicted permeability and an independent cumulative permeability QC plots are introduced to qualify the prediction model.
The workflow shown in this paper is logically built and gives the interpreter flexibility to choose inputs based on the observed permeability variance. The QC flags and the predictive models are easy to implement and update permeability model as the new data comes.
Mapping Completion Design Trends in a Compartmentalized Tight Oil Reservoir for Rapid Evaluation Using Artificial Neural Networks
Authors: Bansal Y. , Ertekin T. , Karpyn Z. T. 
Published: November 2017

Abstract
Lower oil prices pose a threat to developing tight oil reservoirs economically. Typically, completion cost varies between 50-70% of the total capital costs of drilling unconventional wells (EIA, 2016). Major challenges in justification of drilling these new wells lie with the uncertainty in production, and thus, with the efficiency of drilling and completion design of these wells. Identifying a suitable completion design can be a complex problem as tight oil systems are discontinuous hydrocarbon sources. These resources often present challenges in building good geological models. However, abundant data for production, well logs, seismic, drilling and completions are available through recent developments in these formations. This information can be utilized to characterize these reservoirs and identify case-specific and cost-effective completion strategies. This paper discusses the utilization of the data to map completion trends in tight oil systems to optimally complete these wells. The available data is used to generate trends for completion parameters with the application of artificial neural networks. It is shown that the complex relationship among geological properties, well logs, production history, and completions methodology can be established with this methodology. The suggested completion design may enable to lower the effective cost of production from these wells. In addition, the proposed ANN based proxy takes only a few seconds to suggest completion design for a new well. It is also shown that the proxy model developed with this application can easily be utilized with available optimization algorithms to optimize the completion parameters in a time efficient manner.
Engineering and Constructability Challenges of Site Preparation at Zirku Island for the Satah Al-Razboot New Oil Field Development in the Arabian Gulf
Authors: Ahmed Iqbal , Seddik Sameh , Al-Hajaj Mohamed Eissa , Chasiotis Ioannis , Vandolas Vasilis 
Published: November 2017

Abstract
Abu Dhabi Marine Operating Company (ADMA-OPCO) is developing the Satah Al Razboot (SARB) Oil Field, located in the Arabian Gulf in the United Arab Emirates (UAE). Two new artificial islands have been constructed for oil extraction, while the processing, storage and offloading facilities for SARB are located on Zirku Island. Construction of the Zirku Island facilities was conceived and planned for implementation on a modularized basis because of the relatively remote offshore location, which required the incorporation of a permanent jetty and harbor for the transportation of these modules. The Zirku Island topography consists of mountainous terrain composed of a special set of geological conditions characteristic of salt domes. A major requirement of the project was the design and construction of cut and fill slopes as high as 75 meters. The site works have required substantial excavation and backfilling work to create level platforms for the proposed facilities. Surplus excavated material has been used onshore and nearshore to create new land. A robust material management plan was devised to efficiently move the huge excavated material volumes to the designated fill areas and stockpile locations directly due to space constraints. Close collaboration between the project teams and contractors of the different packages of the SARB Project has resulted in the successful delivery of the Site Preparation Project's goals. The main challenges and lessons learned are shared as part of the paper.
Successful Completion of the First Ten Multistage Acid Fracturing of an Oil Producer in Saudi Arabia
Authors: AlOtaibi F. M. , Al-Dahlan M. N. , Rafie M. , Otaibi S. G. , Said Rifat , Aljulaih H. A. 
Published: November 2017

Abstract
Challenges have arisen when developing a relatively tight oil reservoir in Saudi Arabia using conventional matrix stimulation techniques to improve well productivity. The oil producer wells responsiveness to matrix stimulation was not adequate to supply the estimated oil production capacity due to the tightness carbonate reservoir formation. In order to get better well productivity in this low permeability environment, open hole with multistage frac completion using swellable isolation packers was chosen to develop this reservoir.
This paper discusses the challenge journey of first ten multistage job from the well drilling and completion stage, design and lab optimization of the fracturing fluids, modeling of the optimized fracture geometry, onsite well QA/QC of each stage fracturing fluids. In addition, step rates test regression approach prior each stage for fracturing gradient calculation, pre and post fracturing injectivity test, and finally analyzing the flowback samples for four days.
A ten multistage acid fracturing was performed on an oil producer well that was drilled as a single lateral into the oil tight carbonate reservoir. The well was completed with a ten sleeve multistage fracturing and eleven oil swellable packers. These packers showed excellent zonal isolation with no communication observed during the fracturing operation. The job resulted in a well producing 9 folds of production, with a water cut range less than 10 %. The four days flowback samples analysis revealed the need for longer cleaning up time.
A successful approach was achieved using multistage acid fracturing technique. Lessons learned from this job planning and execution shed the importance of previously steps for future acid fracturing jobs in similar oil fields.
Myanmar Online Bowtie to Prevent Major Accident Events MAEs
Authors: Rujipattanapong Sontirat , Apornsuvan Akaradech 
Published: November 2017

Abstract

Objective / Scope
With the PTTEPI goal of Safety "Everybody returns home safely and nobody gets hurt". PTTEPI has developed "Myanmar Online Bowtie to Prevent Major Accident Events" to provide "Line-of-sight to Safety Case barriers status" contributing to Process Safety Management and Asset Reliability and Integrity Management process of "Ensuring asset can perform its required function efficiently and effectively whilst safeguarding life and the environment" for managing workplace safety.
The Myanmar Online Bowtie can illustrate the status of safety barriers by color-coded graphics e.g. Red, Amber or Green for each Major Accident Event and barrier groups at any given time. It is a traceable and transparent system to measure compliance with the management system for Asset Integrity. In addition, it is a bottom-up monitoring tool from site personnel, Technical Authority (TA), to decision makers or management team in order to prioritize operational tasks and resources for barrier repairs, modifications and temporary measures based on barrier conditions and recording. MAE can provide a safety alert for the management support on the operation when necessary.
The Myanmar Online Bowtie can provide an integrated system to monitor key Safety Critical Elements (SCE), a mix of plant (equipment function, or deviation), process (documents) and people (personal certificate/training records), in the following areas:
Achieving Cost Reduction In Mature Gas Fields Through Material Optimization
Authors: Terras Y. , Mansur D. , Saithala J. R. , Flores P. R. , Gonuguntla M. S. 
Published: November 2017

Abstract
After standardizing a well design and drilling multiple wells in a mature field, it is often difficult to find new ways to reduce the cost of the wells. The traditional approaches to reduce the well cost during the planning and design phase of the well is to look at opportunities to reduce the number of casings required (for instance by changing casing show depth, changing mud systems to combine drilling sections, etc.), to reduce the size of casings required (slimming down the well design) and to look for new technologies allowing faster delivery of the well (for instance through ROP enhancement, faster casing running, etc.). After going through this well design optimization phase and improving the drilling performance thanks to the implementation of operational learnings, it becomes increasingly difficult to reduce further the well cost as the well delivery reaches a plateau.
Following a challenge of the functional requirements of the wells, an initiative was raised to review the different materials used across the Petroleum Development Oman (PDO) gas wells portfolio and assess if they were fit for purpose or if there was any possibility to change these materials for more cost effective ones while remaining compliant with the minimum functional requirements of the wells and retaining a high level of standardization in the materials used. Due to the high corrosion tendency of the produced fluids and the required service life of the wells (&gt;20 years), this review focused mainly on the tubing, wellhead and Christmas trees as expensive Corrosion Resistant Alloys (CRA’s) are selected for well completion materials.
A structured approach was put in place to gather actual production field data and compare them to the design functional requirements while in parallel conducting in-house detailed laboratory tests on a specific more cost effective CRA material to improve the operating envelop of such material and extend its use to a wider range of application. This resulted in a set of new material recommendations that were reviewed from a casing design perspective to assess the potential implementation.
Ultimately, several changes were made to the materials selected for the Christmas trees and the tubings on specific fields that resulted in an estimated 3 mln USD cost savings per year for the entire gas portfolio.
A Robust Surveillance and Optimization Workflow for Offshore Gas Lifted Wells
Authors: Xiao Feng , Dani Neeraj R. , Long Ted A. , Gantt Justin A. , Borden Zachary H. , El-Bakry Amr 
Published: November 2017

Abstract
In this paper we present an automated surveillance and optimization system for gas lifted wells. The system integrates flow instability diagnostics, steady-state flow models, and transient multiphase flow models to provide engineers and operators with a complete solution for well flow surveillance and optimization. This system is a significant enhancement to the Gas Lift Optimization Workflow (GLOW™) that was developed and deployed to multiple assets including a platform in the Gulf of Mexico. The system calibrates the models to match flowrates and pressures from multiple well tests. The calibrated models are then used to produce operational maps that provide accurate and robust flow instability recovery recommendations and stability constraints for optimization routines.
We will show an example implementation of the system for a gas lifted well from an offshore platform. In most cases, the calibrated transient flow models accurately replicated the amplitude and frequency of pressure and flowrate oscillations for two types of flow instability: casing heading and hydrodynamic slugging. We also compare transient flow and steady-state models, and discuss the use of both to maximize computing efficiency.
The developed system uses multiphase flow transient models, in an automated way, to produce operational maps that can aid either asset staff or the GLOW™ system to optimize production while steering away from unstable flow. In summary, the system provides a comprehensive, robust, and integrated set of tools for the surveillance and optimization needs of asset staff.