bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reservoir Management Through Characterization of Smart Fields Using Capacitance-Resistance Models
Authors: Salehian Mohammad , Temizel Cenk , Gok Ihsan Murat , Cinar Murat , Alklih Mohammad Y. 
Published: November 2018

Abstract
Use of smart well technologies to improve the recovery has caught significant attention in the oil industry in the last decade. Capacitance-Resistance (CRM) methodology is a robust data-driven technique for reservoir surveillance. Reservoir sweep is a crucial part of efficient recovery, especially where significant investment is done by means of installation of smart wells that feature inflow control valves (ICVs) that are remotely controllable. However, as it is a relatively newer concept, effective use of this new technology has been a challenge. In this study, the objective is to present the efficient use of ICVs in intelligent fields through the integrated use of capacitance-resistance modeling and smart wells with ICVs.
A standard realistic SPE reservoir simulation model of a waterflooding process is used in this study where the smart well ICVs are controlled with conditional statements called procedures in a fully commercial full-physics numerical reservoir simulator. The simulation data is utilized to build the CRM model to obtain the inter-well connectivities at the zonal level beyond only the inter-well connectivity data as smart wells provide control and information on the amount of injection into each layer or zone. Thus, after analyzing the CRM model to detect the inter-well connectivities at the zone/layer-level in an iterative way, the optimum injection not only at the well level but also at the perf/zone level is found. The workflow is outlined as well as the improvements in the results.
The smart well technology has been challenged with the associated cost component thus, it is important to present the benefits of this technology with applications in more diverse cases with different workflows. It has been observed that a robust reservoir characterization in an intelligent field can provide an insight into the physics of reservoir including smart wells with ICVs. The results are presented in a comparative way against the base case to illustrate the incremental value of the use of ICVs along with key performance indicators. Most importantly, it has been shown that smart well use without a robust reservoir management strategy does not always lead to successful results.
In reservoir management, it is not only important to catch the well level details but also see the big picture at the field level to improve the performance of the reservoirs beyond individual well performances taking into account the interference between wells. This method takes the reservoir surveillance to the next level where reservoir characterization is improved using smart field technologies and capacitance-resistance modeling as a robust cost-effective data-driven method.
A Review of Industry-Wide Advanced Completion Best Practices
Authors: Al-Rabeh M. N. , Al-Noaimi K. R. , Brown J. 
Published: November 2018

Abstract
The objective of this paper is to communicate operational and engineering process enhancement and cost saving initiatives in advanced well completions. The initiatives were identified following a detailed review of industrywide advanced completion best practices standardized over the past decade. Several operational and engineering best practices involving inflow control valves (ICVs), inflow control devices (ICDs), zonal isolation (mechanical and swell packers), multistage fracturing (MSF) and sand control technologies were examined. In addition, downhole pressure relief requirements were also considered to introduce new ways of enhancing well integrity by preventing casing corrosion.
A standard research and development methodology was utilized for this review. The methodology was based on collecting and documenting industrywide actual operational and engineering challenges in advanced well completion deployments for both oil and gas fields. These challenges resulted in either lost time at the rig site, necessitated workovers, or rigless operations. Examples of such challenges include extreme frictional forces during ICD deployments, repetitive solids removal practices prior to running ICVs, coiled tubing milling requirements for MSF, wash pipe deployments for downhole sand screen circulation, and calcium carbonate scale deposition in sand screens. The research also encompass a literature review for identifying further advanced completion challenges across the industry.
The review resulted in identifying several areas of potential improvement. As a result, multiple engineering and operational process enhancement initiatives were recommended. This includes the utilization of centralizers to reduce frictional forces in ICD deployments. Also, the application of isolation valves to eliminate wash pipe requirements in screens or ICDs. Moreover, running downhole annular relief check valves to preserve tubular integrity by eliminating casing-to-casing annular (CCA) pressure communication and utilization of mono-bore ball seat technology to eliminate milling in MSF. Finally, the utilization of sacrificial completion accessories to improve ICV cleanup practices and save rig time in addition to several other relevant initiatives across the industry.
In summary, the paper provides a deep dive into several technical advanced completion challenges across the industry. Also, several new initiatives are proposed with the objective of achieving significant cost savings. It is intended for these initiatives to be adopted as new advanced completion best practices. Not only to yield significant cost savings, but also to supplement the existing best practices body of literature in the areas of ICVs, ICDs, zonal isolation, MSF, well integrity and sand control technology.
The Most Common Impacts of Drilling Dynamics and Environments on Log-While-Drilling Data: A Study from Abu Dhabi
Authors: Thakur Parmanand Dhermeshwar , Agnihotri Praveen , Deng Lichuan , Soliman Ahmed M. , Kieduppatum Piyanuch , Fernandes Warren 
Published: November 2018

Abstract
Logging-While-Drilling (LWD) has incorporated almost all wireline-equivalent technology with the added advantage of logging high-angle and horizontal wells with reduced rig time, critical for cost optimization efforts.
LWD measurements are affected by a rugged drilling environment, and logging interpretation with a wireline mindset leads to erroneous results. Identifying measurement artefacts from real formation information is critical for reliable log analysis.
This publication discusses the most common effects of drilling dynamics and environments on LWD logs that were observed during logging and drilling wells in cretaceous carbonate reservoirs in an Abu Dhabi onshore field.
Log data from more than one hundred wells are reviewed to identify several interesting effects due to bottom-hole-assembly (BHA) design, BHA driving mechanism (Rotary steerable system versus mud motor), tool eccentricity, well angle, mud properties, differential invasion, borehole condition, formation fluid properties and lithology. In a few instances, some of these effects occur simultaneously, complicating the log response. These phenomenons are discussed in detail with actual examples and compared to offset wells and response modellings.
The rugged logging environment and limited formation damage due to invasion provide a unique opportunity to obtain additional insight about reservoir behavior, especially when compared to wireline data in an offset well or in the same well. Pre-job planning and modelling can use these phenomena for getting additional information about dynamic reservoir behavior. This paper highlights a few such applications.
This paper explains the impact of a dynamic drilling environment on LWD measurements and serves as a ready reference to identify measurement artifacts from real formation information. It is helpful as a guidebook for log analysts, geologist, geo-steering engineers and other non-specialists to identify LWD measurement artefacts.
Successful Implementation of 15K Open Hole Multi Stage Fracturing Completion
Authors: Rodoplu Rasim Serdar , Tiss Amine , Adnan Asif Bin , Siham Ahmed M. 
Published: November 2018

Abstract
15K Open Hole Multi Stage Fracturing (OH MSF) completion was successfully implemented with the goal of hydrocarbon production at sustained rates from tight HPHT gas formation and to diversify technology portfolio to address similar challenges.
OH MSF completion technology has been globally proven successful in enhancing the well design, stimulation efficiency and production. As more wells are being drilled deeper, longer and in more challenging formations, the OH MSF technology also evolved resulting in introduction of a HPHT – 15K psi working pressure - MSF system. The technology had to overcome many challenges before it could be deployed. Pre-deployment stages of this technology have two main components;Standard tool design including material selection, NACE compatibility, dimensions, API standard compliance, testing, and prototypingCompletion construction design, installation challenges & force analysis
The candidate well was drilled horizontally to achieve enough formation contact in a tight HPHT formation. Wells with similar poor development have been seen to require upwards of current OH MSF completions reaching to their limits of 10K psi differential pressure downhole to successfully complete with proppant fracturing. Candidate well was planned to be trial tested with 15K OH MSF completion to solve the challenge of high breakdown pressures and to capitalize on the greater productivity of open hole completions across this tight HPHT formation.
The proppant fracturing operations resulted in the successful completion of five stages of proppant fracturing in this formation. A total of more than 1.2 million lbs of proppant was placed during hydraulic fracturing operations exceeding 10K differential pressure across the MSF completion. The well showed an excellent post frac flowback results exceeding expectations. Previous wellbore completion pressure limitations in many instances acted as a constraint to reach job objectives has been surmounted.
The implementation of 15K OH MSF completion system has helped pave the way to attend tighter formations in an efficient and cost effective manner. Engineering approach and design to develop this completion system and utilization in the right candidate confirmed the benefit of the completion for field development options. The implementation of this technology will improve and diversify the efforts in exploiting tight HPHT formations.
A Numerical Study of the Influence of Nonlinear Fluid Flow Mechanism on Dynamic Production in Tight Gas Reservoirs
Authors: Dong Jiaxin , Ran Qiquan , Peng Hui , Wang Zhiping , Xu Mengya , Wang Cong 
Published: November 2018

Abstract
The Fluid flow mechanism in unconventional reservoirs is much more complicated than that in conventional reservoirs mainly because of the co-existence of various sized micro-nano pores and natural / artificial fractures in the same reservoir. Due to the various flow patterns and seepage mechanism among different-sized media, and also among different production periods in the same medium, the dynamic production is influenced by both the spatial variable and time variable. The capacity of the tight gas reservoirs is also thus greatly influenced.
In this paper, numerical simulation is used to automatically identify the flow pattern according to the critical criteria of flow in different media, and to simulate the dynamic production process with kinetic equations. The simulation is mainly focused on the following characteristics shown in the production process of tight gas reservoirs: I) high-velocity nonlinear, quasi-linear and low-velocity nonlinear flow regimes; II) the slippage effect and diffusion effect under low porosity, low pressure and low permeability conditions; and III) start-up pressure gradient, desorption effect and other seepage mechanism.
The simulation results reveal that: a) as the start-up pressure gradient increases, the production gradually decreases; b) the higher the high-velocity non-Darcy coefficient, the lower the production; c) the production increases along with the slippage effect on conditions that the pore pressure remains unchanged; d) the free gas content and the cumulative production are inversely related to the content of adsorbed gas; e) the greater the diffusion coefficient, the higher the production; and g) the higher the Langmuir pressure, the lower the curvature of the adsorption isotherm curve and the higher the gas production
Based on the above analysis, a better understanding about the influence of the flow state and seepage mechanism on dynamic production and productivity is obtained, which will help optimizing the development method and improving the accuracy of gas well productivity forecasting.
An Applied Machine Learning Approach to Subsea Asset Inspection
Authors: Bertram Stephen James , Fan Yilun , Raffelt David , Michalak Pawel 
Published: November 2018

Abstract
Subsea infrastructure inspection campaigns are conducted on a fixed time schedule to ensure the integrity of offshore assets while guaranteeing compliance with government and other stakeholders’ legislation. These thorough assessments of subsea assets are achieved by acquiring and processing survey results alongside the relevant engineering data and environmental conditions.
The current approach is not ideal. The infrastructure operators would prefer to have more frequent, on-demand field visits and base the assessments on an up-to-date high resolution, precise asset model. Unfortunately, this has historically not been technically feasible. The underwater inspection vehicles moved relatively slow, the positioning accuracy was limited, and the underwater sensors’ accuracy and resolution was not comparable with those used in air.
This is not the case anymore. We now operate inspection vehicles traveling with speeds over six knots! We can control them remotely from the office-based command center. Next to the acoustic technology, the vehicles are additionally equipped with optic sensors, dynamically collecting point clouds, images and videos of unprecedented resolution. Gigabytes of data hits the vessel every few minutes. And that's where it used to end…
Processing and, so called, "Digital Twin" modelling from this data has traditionally been taking weeks for every day of inspection. In many cases it was simply not technically possible since the data files were prohibitively big. Data required subsampling, more data processors had to go offshore, asset operators had to wait longer.
Given the increasing capacity of satellite links, limitless potential of commoditized cloud computing and sophisticated Deep Learning algorithms, we are now able to move subsea asset management to the new era. Through one of their latest research & development programmes - Roames, Fugro has been able to revolutionize the traditional workflows using the state-of-the-art digital technology. The resultant product is a bespoke, web-based service that enables asset (initially pipelines) inspection data to be uploaded to the secure cloud environment, processed using Machine Learning, verified by experts on shore and visualized in an intuitive 4D web viewer. All delivered to the geographically spread stakeholders, operators and decision makers in near real time. This approach greatly reduces the cost of infrastructure management practices, lowers the risk exposure and contributes to extended life of the asset.
The Roames, Machine Learning based methodology was validated using a vast archive of survey data prior to testing the workflow on a live project. Detailed method statement and field results are presented in this paper.
Quality Control of 3D GeoCellular Models: Examples from UAE Carbonate Reservoirs
Authors: Gomes Jorge , Parra Humberto , Ghosh Dipankar 
Published: November 2018

Abstract
3D geocellular static models are the key input for fluid flow simulations with the main aim to predict the future reservoir performance for a particular recovery scheme. Since the predictability of the dynamic model depends on the quality of the geocellular model, it is imperative that the input data, the modelling workflow, methodologies and approaches are verified and validated prior to the sanction of the geocellular model. The objective of this paper is therefore to discuss the process of performing quality assurance and quality control (QA/QC) of 3D geocellular models exhibiting real field examples from the Middle East carbonate reservoirs.
3D static models are built using data from multiple sources, at different scales and with different degrees of uncertainty. The validation and reconciliation of all the data is of paramount importance. The procedure to build any geological model is very similar provided all the data is available. Some variations in the procedure are expected depending on the complexity of the phenomena to model, but must of the time workflows divert based on data quality and data availability. In this paper we discuss the use of key validation checks for each step of the modelling process taking into account the data quality and field maturity, namely for the 1)- structural framework modelling, 2)- facies modelling, 3)- porosity modelling, 4)- permeability modelling, 5)- rock type modelling, 6)- water saturation modelling, 7)- upscaling and 8)- uncertainty analysis. The use and validation of the applicability of secondary variables in the petrophysical modelling, such as acoustic impedance from seismic inversion, is also addressed.
From the analysis of multiple geocellular models, inconsistencies were detected at different stages of the modelling process, starting from the well surveying with implications to horizontal well positioning within the framework, to the modelling of facies and petrophysical properties, with inconsistencies on variogram model parameters. Also, the validation of the velocity modelling and time-depth conversion used for the structural framework was validated by comparing FWLs depths against spill points. Furthermore, the quality of the facies model could be verified against regional facies belt maps (similar variogram azimuths are expected) while the validation of the permeability scale-up at well level could be achieved by reconciling with well test kh data. These are just a few examples of the material discussed in this paper.
The novelty of the quality assurance process pertained to 3D geological models is the identification of appropriate metrics with key performance indicators for each step in the modelling workflow. At the end of the QA/QC process the models are ranked in quality and technical gaps identified for subsequent model improvement. Guidelines and best practices are also presented in this paper.
Business Process Improvement in ADNOC Gas Processing through Lean Kaizen Approach
Authors: Balbahaith Amal 
Published: November 2018

Abstract
In the past decade, the expansion of global market has significantly changed and has showed remarkable growth. This has also led to more challenges and competition like never seen before. The competition became tougher as the range and quality of goods and services available broadened. Hence to thrive in such cut-throat competition companies now need to focus on providing quality service and products at competitive prices. This distinctive change in the market also resulted in change in the approach; from a solely profit based approach to quality based approach. The word "kaizen" in japenese refers to improvement. kaizen lean in business philosophy refers to removal unuseful contents. It means to change for the better. In order to improve continuously and persistently all that is waste must be eradicated. The concept of lean and kaizen go against the traditional belief of just making improvement, amendments or addition to the existing system instead of time and again focusing on removing the waste and what is no longer required.
Turning a High-Pressure, High-H2S Oil Carbonate Reservoir Development Viable Through Miscible Gas Injection in the Sultanate of Oman
Authors: Mourad Ahmed , Awadhi Mahmood , Calvert Stephen , Djermouni Karima , Hattali Ahmed , Nabhani Abdullah , Noirot Jean-Christophe 
Published: November 2018

Abstract
The development of low porosity, low permeability carbonate oil reservoirs remains a challenge in the industry. Identifying a technically and economically viable development is further complicated when high pressures, high temperatures & high H2S concentrations are encountered at large depths. For such reservoirs, depletion developments are typically the only economically justifiable option but typically result in very low Hydrocarbon Recovery Factors. This paper presents a case study of a complex field located in the south of the Sultanate of Oman that includes a carbonate stringer reservoir encased in the Ara Salt. A viable Miscible Gas Injection (MGI) development scheme has been identified and turned into an economical option for this field.
The field X A3EC was discovered in 2011 within the Greater Birba area. Since it was put on production in 2013, the performance of this carbonate stringer has been relatively poor compared to other analogue fields. No feasible technical solution could be identified to develop the field beyond the very low estimated ultimate Recovery Factor (~6%) achievable under depletion. Alternative developments could not be sanctioned mainly because of poor economics resulting from limited expected incremental recovery. Moreover, the drillability of additional wells could not be confirmed following subsurface re-interpretation & dynamic history matching of the available pressure data.
In 2017 a study was carried out that incorporated newly collected pressure data, seismic and geological interpretations, as well as static & dynamic modeling. A new approach to history matching was also applied. This study turned further field development from technically unfeasible into an economically attractive & doable project. Moreover, new appraisal and well stimulation plans were identified to address the remaining field uncertainty on the in-place volume and well productivity. The proposed technical solution for further development of Field X A3EC involves a phased implementation of a MGI scheme which will increase the expected Recovery Factor in the target zone by more than 35 %. The drillability of the targeted field area was established by reducing the uncertainty on the reservoir pore pressure through extensive dynamic simulation work supported by newly collected long-term pressure build-up data. Field X A3EC development will feed into and benefit one of the largest projects in the Middle East - the Rabab Harweel Integrated Project (RHIP) that is currently under construction, further adding to the value of this large integrated facility.
This paper highlights the challenges faced whilst developing complex contaminated oil carbonate reservoirs and identifies technically feasible solutions for further development of such fields via an integrated approach.