bluuebunny/crossref_metadata_2025_split huggingface dataset:
Predicting Relative Permeability from NMR Relaxation-Diffusion Responses Utilizing High Resolution Micro Xray-CT Images
Authors: AlGhamdi Tariq M. , Arns Christoph H. 
Published: November 2012

Abstract
NMR relaxation measurements are routinely used in the petroleum industry to estimate permeability and to partition fluids to estimate irreducible water saturation. The shape of the relaxation time distribution is controlled by many mechanisms like pore-coupling in the presence of heterogeneity, internal gradient effects, and signal to noise ratio. However, given an anchoring of the relaxation time distribution, the logarithmic average of the NMR T2 distribution is a relatively robust measure and for rocks where a correlation between pore and throat size exist, a reliable estimate of permeability can often be made. In this work we utilize high resolution X-ray CT images Berea and Bentheimer sandstone and simulate the NMR relaxation-diffusion responses for the case of drainage by a non-wetting fluid at different magnetic field strength (2MHz, 12 MHz, and 400 MHz), calculating internal magnetic fields explicitely. The T2-D responses are projected onto the relaxation axis for each fluid and the SDR model used to predict absolute and relative permeabilities. The resulting correlations between NMR response and relative permeability are surprisingly strong. In particular, reasonable correlations exist between lattice Boltzmann derived relative permeability and NMR estimated relative permeability even for the effective permeability of the oil. This suggests that internal fields help in establishing a surface related/weighted relaxation mechanism for the non-wetting fluid. This methodology allows testing the applicability of SDR type relative permeability estimates for the purpose of log analysis. A variety of cross-correlations including resistivity information can be considered and correlations between relative permeability and NMR response are optimized by finding the best NMR acquisition sequence and interpretation (e.g. choosing optimal cut-offs).
Optimizing Oil-Rim Development of a Tight Reservoir with Large Gas Cap by Minimizing Gas Cusping Phenomenon C"Case StudyC"
Authors: El Gazar Ashraf , Bin Sumaidaa Saleh , El Mahdi Ahmed , Basioni M. , Aoub M. , Dawoud Ahmed , Arslan Izzet 
Published: November 2012

Abstract
This paper presents a case study of developing a significant volume of oil rim with a large gas cap reservoir in Abu Dhabi-UAE.
The reservoir is a low relief heterogeneous carbonate located in a complex environment represented by natural and artificial islands in the surface, shallow and medium water marine areas. The reservoir rock properties showed lateral and vertical heterogeneities as well as variation in reservoir fluid properties.
The static and dynamic data were utilized to construct representative geological and dynamic models for the reservoir. The field development objective focused on producing the oil rim while maintaining the gas cap as long as possible to save the reservoir energy and benefit from the gas cap pressure support.
Five years production dynamic data were available from two oil producers in addition to well testing and MDT data during the appraisal phase "13 wells". These data were used to quality control the initialization and history match phases.
The development options included pressure support using water injection, lean gas injection, miscible gas injection and miscible WAG injection. The predicted reservoir performance of the oil rim indicated considerable gas cusping from the gas cap in all the development options.
It was a challenge to reduce the amount of gas production from the gas cap in all the development options. A new development option was introduced to perform miscible gas / WAG injection underneath the gas cap accompanied with optimization of the wells and completion intervals locations for producers and injectors to minimize the gas cusping from the gas cap. This resulted in significant enhancement of minimizing gas cusping with minor impact of the recovery factor.
The development of the oil rim was suggested to be in phases focusing on the lowest uncertainty segment of the reservoir. This paper provides the methodology followed to guide the development plan to fill in the uncertainty gap by a detailed data acquisition and monitoring programs to better understand the reservoir behavior.
Mega Projects Integrated Readiness Assurance Process
Authors: Nossair Ahmed , Al Tamimi Ali , Al Amri Ali , Al Katheeri Khaled , Hann Tom , Finigan Tim 
Published: November 2012

Abstract
Mega projects development with major increase in the number of assets, facilities, infra-structures and new technologies additional to current existing running facilities, require numerous efforts to ensure organization readiness for these mega projects future operation and support, with least minimum impact on the running business. Therefore well organized, innovative and systematic approach must be established to manage these mega projects readiness from all perspectives, controlling expansion and interfaces across the company towards future operation requirements. This readiness approach should captures major key operation readiness elements, activities, internal interfaces among the company and external with stakeholders achieving operation readiness and ensuring operation experience to be embedded during project development. A Readiness Assurance Process was developed based on previous experience, best practices, lesson learnt and available guide lines, covering 16 main elements of operation readiness which are Operations, Maintenance, Integrity, HSE, Procurement, Inventory, Commissioning, Agreements, Logistics, Human Capital, Automation, Services, Drilling / Reservoir, Finance and Brown Field. This assurance process covers most of the activities across the company and requires heavy involvement of all business units and divisions within the company therefore the word "Integrated" has been added to the title reflecting the reality. Each element of the Integrated Readiness Assurance Process (IRAP) is divided into sub-elements that have comprehensive list of activities, prerequisite documents and definite deliverables scheduled through the "Project Development Value Assurance Process". Integrated Readiness assures the full readiness of the organization from all aspects to company management and shareholders and supports the requirements of the project development; also it will ensure operation disciplines involvement through the mega project life cycle through well-established methodology. Deployment success of the readiness process relies on well-structured deployment methodology through establishment of sub-committees across the company organization with clear roles and responsibilities, Sub-committees consists of accountable focal points having relevant experience and knowledge to ensure well comprehending the readiness requirements and assuring their commitment for implementation. Subcommittees’ meets on quarterly basis to report the execution progress, and identify forthcoming activities, major achievement verses major challenges and any area of concern along with mitigation strategies to a steering committee on six monthly basis looking for their directives on strategic decisions. Maintaining the deployment success requires monitoring and control techniques that enable proactive approach and progress measurement through performance indicators and balance score cards.
Planning for Successful Jarring Operations - Effective Use of Drilling Impact Systems Helps Release Stuck Pipe
Authors: Mercado Jose L. 
Published: November 2012

Abstract
Jarring is a cost effective alternative to free stuck pipe. Impact tools have been used in drilling industry for many decades and the technology has helped operators save significant amounts of time and money. To keep improving this technology, a new Drilling Impact System (DIS) has been developed. The DIS uses innovative double-acting hydraulic Drilling Jar/Drilling Accelerator and BHA analysis software. The unique modeling program enables engineers to identify/recognize the optimum impact/impulse values and key operational considerations during the BHA design process. The optimized BHA with accelerator amplifies the energy created by the drilling jar. As a consequence, it increases the probability of freeing a stuck BHA.
This paper focus on the drilling bottom hole assembly (BHA) design process and best operational practices to ensure a successful drilling operation. The author will discuss effectiveness of the impact system and proper pre-job analysis procedures for optimum jar placement to avoid lost-in-hole (LIH) situations. The planning process includes: 1) operational considerations; 2) QA/QC system and; 3) software analysis. Case studies are presented to illustrate how the utilization of the drilling impact system culminated in the successful execution of a jarring operation to free stuck bottom hole assemblies.
Performance of Inline Separation Technology in Unlocking Restricted/ Shut Down Wet Gas Wells
Authors: Vissers A. J. , van Asperen V. , Akdim R. , Boudi A. A. 
Published: November 2012

Abstract
Inline separation technology has attracted the attention of oil and gas field operators due to the considerable weight, space and cost savings that can be achieved. In addition, inline separation technology can play a major role in de-bottlenecking and upgrading of existing production facilities. In this regard, inline separation technology has been evaluated in separation efficiency and its contribution to an upstream wet gas field development, to unlock the restricted/shut down wet gas wells.
The FMC/CDS InLine DeLiquidiser (Ultra-Compact Cyclonic Gas-Liquid Separator) was trial tested in a remote location of a Saudi Aramco mature gas field to unlock production from restricted or shut-in gas wells currently suffering from high water cut, which was resulting in limited gas production. More importantly, this technology will significantly contribute in developing Saudi Aramco gas fields already restricted or unexploited due to water production increase associated with gas production.
This paper discusses the concept, objectives and results of the commissioning of the Inline Separator application in the Saudi Aramco wet gas field. Furthermore, during the commissioning, noise measurements were executed to determine the noise level of the Inline Separator in the field, which will also be highlighted.
Pitfalls of Oversizing Plant Rotating Equipment
Authors: Soliman Mohamed 
Published: November 2012

Abstract
Many Engineers overdesign (oversize) plant rotating equipment, valves and pipes to account for uncertainty even though they have designed the same equipment a hundred times. An acceptable and encouraging name is given to the overdesign factor for example, safety margin or design factor. It starts with the proponent (operating company), through the design contractor and finally the vendor. It is the mentality of, "the bigger the better." If it is oversized, it will work. However, if it is undersized, it will not and everyone will hear about it and it will be a lesson learned to everyone. Equipment oversizing will increase plant overall energy consumption, equipment corrosion and maintenance cost. Avoiding plant/GOSPs equipment oversizing will not only save the CAPEX but also will save billions of dollars in plant operating costs. Adequately sized plant equipment will improve plant reliability, minimize energy consumption, minimize plant maintenance and improve plant safety through minimizing equipment corrosion.
In this paper, the reasons for adding an overdesign factor and the consequences of overdesigning the plant rotating equipment, pipes and valves will be discussed includingreal life case studies. Also, systematic approach to avoid oversizing will be addressed in details. Furthermore, this paper will focus on a detailed case study of Oversizing the crude charge pump in one of the Gas Oil Separating Plant (GOSP). The oversizing was not only a waste of energy, but it also interrupted the plant operation and caused a continuous opening of off-spec valves.
One of the main reasons for overdesign factor is attributed to the lack of clear guidelines and instruction from the proponent to take responsibility of not adding this factor. The design factor not only increases the capital cost but also increases the operating costs and consequently reduces the plant profitability in addition to the plant safety. Optimization of plant operation starts from early plant design by reducing the overdesign/oversizing factor of the plant rotating equipment.
Offshore First Fiber Optic Enable Coil Tubing Application for Water Shutoff, Cementing and Perforation Operation - Malay Basin Historical Milestone
Authors: Shahril Shakri Shaifi , Abd Rahim Parveen , Fakhrurazi Ishak M , Kasim M Heikal , Ayob Adzlan 
Published: November 2012

ABSTRACT
Dulang is one of the aging fields in Peninsular Malaysia that started its first oil production in March 1991. After 10 years in operations, the field started to show a rapid declination in production. Since then, a lot of Production Enhancement & Idle Well reactivation activities have been conducted despite the presence of high CO2 that post challenges for well intervention jobs. The number of activities keeps increasing over the years in hope to boost production and with a time constraint, each job is planned with a very limited window for execution. The engineers constantly have to find more efficient ways to ensure all these planned activities are completed on time despite these challenges.
One of the Idle Well reactivation that was successfully conducted at Dulang is at Well A-40ST1. The well was 100% watered out from the lowest zone J-36 and uncertain production from the upper zone J-32. Based on the survey data, there is a potential reserve at a new zone that has been identified in above the current zones, namely upper J-32. Amongst the challenges in this well is the interval of each zone is so close and it is located at the highest slope of the well at 74°.
Conventional method to execute such job normally takes 2 months which involved Electric-line and Coiled Tubing packages alternately. The other option is to use electric-coil tubing which can save operation time but with higher cost. Ultimately, field operator has taken fresh new application that can provide more benefits in term of time, cost and deckspace layout.
This paper will describe the details of the complexity of the operation which involves milling, water shut-off, cementing, and perforation at remote platform location. Prior to that, detail evaluation is performed to weigh the pros and cons of conventional method and real-time fiber optic application.
Formation Flow Impairment in Carbonate Reservoirs Due to Asphaltene Precipitation and Deposition during Hydrocarbon Gas Flooding
Authors: Syed Fahad I. , Ghedan Shawket G. , Hage Ahmed R. , Tariq Syed M. , Shebl Hesham 
Published: November 2012

Abstract
Hydrocarbon gas injection has proven to be one of the most efficient Enhanced Oil Recovery (EOR) methods, especially for tight and heterogeneous reservoirs with light to medium API oil, where water flooding is expected to be inefficient. Asphaltene precipitation and deposition, however, might occur due to pressure and fluids compositional changes with the gas injection. This complex phenomenon requires experimental and numerical investigation to understand the conditions at which flow impairment due to asphaltene formation damage may occur, resulting in lowering well flow capacity and in turn lower ultimate oil recovery.
In this experimental study, low permeability carbonate rock core samples were flooded with hydrocarbon gas under reservoir conditions. The floods were conducted on core samples of two different lengths representing two different rock types based on average rock permeability and Pore Throat Size Distribution (PTSD). Additionally, these core samples were flooded at two different operating conditions to mimic the average reservoir and the wellbore flowing pressure conditions. As a prelude to these experiments, Asphaltene Onset Pressure (AOP) and Asphaltene Onset Concentration (AOC) of the oil under study with the injection gas were established through NIR, SARA and Titration analysis.
Flow impairment due to formation damage by asphaltene precipitation and deposition was analyzed through permeability measurements before and after gas flooding. In all cases permeability reduction was observed. Permeability reduction was found to be function of rock types, reservoir pressure, and length of composite core samples. We assume that pore throat bridging by the larger size asphaltene particles caused higher permeability reduction in the samples of poorer rock types. Experiments conducted at lower pressures showed more damage. This is consistent with the lower AOC at lower pressure. Longer core samples give more time for asphaltene flocculation resulting in more asphaltene formation damage and more permeability reduction. Scanning Electron Microscopic (SEM) images of core plugs before and after the gas flooding process were found to be not conclusive with respect to direct detection of asphaltene deposition in the core samples and further work is planned to positively identify asphaltene deposition in the rock samples.
Managing LNG Deliverability: An Innovative Approach Using Neural Network and Proxy Modeling for Australian CSG Assets
Authors: Biniwale Shripad , Trivedi Rajesh 
Published: November 2012

Abstract
Accurate prediction of individual well potential and estimation of field capacity are the key for managing Coal Seam Gas (CSG) wells and its deliverability to Liquefied Natural Gas (LNG) plant. Because there are no downhole gauges in these wells there is limited reservoir data. The associated uncertainty, the absence of fast predictive wellbore models and challenges in generating accurate well performance predictions add to the deliverability challenge.
This paper presents a method used to estimate CSG well performance for Australian CSG assets using neural network (NN) and proxy modeling. Traditional methods for prediction of well potential, such as numerical simulation or statistical techniques, have significant limitations. Numerical prediction is traditionally accurate but very complex in setup and computation; statistical techniques have the advantage of being fast but often lack accuracy.
The approach starts with the automatic acquisition, validation, and quality control of static and dynamic production parameters in proxy modeling. Based on the relationship and similarity of key performance indicator (KPI) profiles, the wells are grouped into various clusters using a NN self-organizing map (SOM) technique. For each cluster group, a workflow is defined to estimate various well parameters used to predict individual well potential. A generic proxy model can be designed for each cluster for future prediction and capacity modeling. The workflow also allows tracking of capacity at different operating points on a daily basis for wells, group of wells, and fields and can be leveraged further by generating scenarios for various constraints on production parameters and facility controls. The entire workflow process can be standardized, scheduled to run automatically, and stored in a workflow library for secure deployment and sharing across the organization.
Persistent Approach to Improve Well Performance and Production Sustenance
Authors: Raju Mankala , Al-Sirri Dalal , Al-Husaini Mohammad Harier , Al-Hajeri Nasser , Chetri H B , Al-Ajmi Hussain 
Published: November 2012

Abstract
Sabiriyah Lower Burgan is a clastic reservoir in North Kuwait on continuous production for the last 45 years. The reservoir, on active water drive, has its inherent problem of rapid increase in water cut, the production performance of wells declining drastically after water cut level of 40%. The well production improvement is continuous effort based on understanding of well fundamentals and actual analysis of well's historical performance. This can be enhanced with Well modeling based on latest field real time parameters to predict well performance and production forecast.
The persistent approach to improve well performance was implemented by dividing entire Field into segments based on water encroachment, pressure distribution and fluid properties as each well is located in a segment requiring specific approach and technique's to sustain well production and performance improvement.
To implement production sustenance and enhancement plan, huge well surveillance plan was adopted to acquire TDT/PNC, PLT, FBHP and SBHP, PGOR to get latest well and field data to implement following specific actions a) Quick wins: Rig less water shut-off jobs, additional and re-perforations in dry zones to improve well production; b) Rig work overs to cement squeeze the high water cut zones to reduce water cuts and improve well vertical lift performance on natural flow; c) Selective ESP in low pressure and high water cut field segments to sustain the existing production; d) Use of latest ICD design based on PLT results to sustain well production from the existing horizontal wells with less water cut; e) Recompletion of poor performance wells of other zones after critical evaluation.
The case history of Production management of this giant reservoir in North Kuwait leading to significant increase in production is a successful journey to be shared with International professional community.
A Novel Approach to Handle Continuous Wettability Alteration during Immiscible CO2 Flooding Process
Authors: Al-Mutairi Saad M. , Abu-Khamsin Sidqi A. , Hossain M. Enamul 
Published: November 2012

Abstract
Wettability has been recognized as one of the main parameters that control the remaining oil-in-place. Knowledge of wettability alteration during displacement is essential to understand the displacement mechanisms and to recover oil efficiently. Continuous alteration of wettability and other related properties need to be addressed properly for an effective approach to enhanced oil recovery (EOR). Review of the literature reveals that much laboratory work, including core and micro-model flooding, was conducted to investigate wettability alteration during CO2 flooding process. However, limited research on numerical and/or analytical modeling of such wettability alteration has been reported. Moreover, to the best of our knowledge, published numerical and/or analytical models are time-independent solutions. Ignoring this time dimension creates a significant knowledge gap between such solutions and reality. To mitigate this shortcoming, a novel approach was developed to handle wettability alteration on continuous basis during immiscible CO2 flooding process.
A mathematical model was developed to incorporate continuous time function for immiscible CO2 flooding process. During the development of the model equation, Cory relative permeability model was utilized. In this model, a new, modified Corey relative permeability model was incorporated to calculate the phase relative permeability as a function of wettability. A numerical, 1-dimensional, two-phase immiscible simulation scheme was built utilizing MATLAB program to solve the model equations. The results showed that inclusion of continuous wettability alteration model is believed to predict oil displacement and sweep efficiency more realistically.
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