bluuebunny/crossref_metadata_2025_split huggingface dataset:
Kuwait's First Successful Implementation of MPD in Deep Jurassic Reservoirs of Abdulyiah Field in West Kuwait
Authors: Al Moraikhi Rasha , Kulkarni Nitin , Patil Dipak P. , Sounderrajan Mahesh , Verma Naveen K. , Quttainah Riyad , Al-Kandari Eman , Al-Mohailan Mohannad 
Published: November 2017

Abstract
Jurassic Reservoirs in Abduliyah field of West Kuwait are characterized by abnormal pressure variation within and across Jurassic formations, which cause profound drilling problems such as well kicks and mud losses resulting in increased drilling time, cost and materials in addition to reservoir damages.
The development of Najmah –Sargelu (NJ/SR) unconventional fractured reservoir requires drilling through high-density fracture swarms to ensure well productivity, which in many instances result in "alternate loss & gain scenario," occasionally, making the well control options limited. On the other hand, drilling through Marrat section encounters drilling difficulties such as mud loss and differential sticking in depleted middle Marrat layers juxtaposed to high-pressure layers of upper intervals. Keeping the above problems in mind, Managed pressure Drilling (MPD) was applied first time in both 9-1/4″ NJ-SR & 6-1/2″ Marrat reservoir sections in a deviated well of Abduliyah field. The Use of MPD in this well offered several advantages and improvements in drilling and completion performance as given below:
Reduction in Operation Time: Successfully drilled through Base Gotnia, Najmah-Sarjelu & Marrat Formations to Target Depth smoothly without any Non-productive Time (NPT)
Down hole problem avoidance: No downhole complications experienced during drilling to Target Depth.
Implementation of new casing design: Drilled Najmah-Sarjelu, Dharuma, Up. Marrat and Upper part of Middle Marrat in the same section for the first time in Abduliyah field which allows future re-entry sidetracking using 6 ½″ horizontal wellbores to enhance productivity for cost-optimal development of NJ-SR & Marrat reservoirs.
Reduction in drilling fluid density: The sections were drilled with lower drilling fluid density by 1.5-2.0 ppg resulting in optimum overbalance pressure to avoid formation damage while reducing the risk of differential stuck pipe, with savings in mud cost.
Health Safety & Environment (HSE) Improvement: The MPD sections were drilled without any incident indicating improved HSE performance.
Reduction in overall well cost: Significant cost reduction was achieved by using MPD for drilling the sections.
The paper aims to share the successful case study of drilling through Jurassic reservoir sections of Abduliyah deviated well using MPD technology along with lessons learned and benefits for its future implementation in similar wells across all KOC assets
Optimized Engineering Under Current O&G Industry Scenario
Authors: Moro Sudhakar , El-Sawah Mohamed , Shabaka Ashraf , Mentheri Ibtihaj Al 
Published: November 2017

Abstract: Optimized Engineering under current O&G scenario:

Context
Optimization, price reduction, efficiency, leaner, fit-for-purpose, etc., are the buzzwords doing the rounds in any Oil and gas Industry meet nowadays. Automation by means of well-engineered Instrumentation and Control is a major asset in any production facility. This papers raises awareness on how optimization can be achieved in Instrumentation & control items during detailed engineering, without compromising on safety and operation requirements of any O&G asset.

Objectives/Scope
The current market scenario mandates the need to discuss and understand the various cost saving or value engineering items related to O&G industry. It is only wise that when the best of experts in industry meet, we deliberate on same. During the presentation, we would like to instigate the participants to a healthy discussion and finally carry forward a list of major cost savers in Instrumentation and control, which could be implemented in O&G projects.

Methods and Processes
Automation through state of the art technology is still the best bet for optimization and economics of operation and maintenance in Oil & Gas industry. However the methods and processes of below optimization items need stringent review prior to implementation. The brown field projects have various challenges of structural extension, weight concerns, Power, Utility adequacy, huge barge costs, etc. Is it not time we had strict gates during design stage and include only the mandatorily required equipment and cut away the frills.
Package type equipment like Flare system, Compressors, Electro chlorination unit, etc. which are vendor specific design is another vast area where good optimization can be worked out. Footprints can be optimized leading to major reductions in project cost.

Results, Observations, Conclusions
Optmization in Instrumentation items always have a chain effect on other areas like power, cable, spares, replacement throughout the lifecycle of the plant, etc. The resultant list of cost savers will be much longer definitely. To conclude we recollect one old quote "Beware of little expenses, a small leak will sink a great ship" and we propose to reevaluate our basis of design and justify every expenditure.

Novel/Additive Information
During the presentation we want to kindle the out of box thinking, for novel and innovative but safe ways to save every dirham in our business today.
Pressure Build-Up Test Interpretation Studies: Models, Numerical Simulation, and Field Test in the Huabei Oilfield
Authors: Miao Y. , Li X. , Zhou Y. , Li H. , Shi J. , Chen Y. 
Published: November 2017

Abstract
Accurate pressure build-up test interpretation technologies for both conventional and unconventional reservoir development have been highly applied in oil and gas industries in recent years. However, for the late development stage of wells, current well test interpretation methods lose their accuracy to characterize fluid flow behavior and fracture properties etc. due to the complex underground situation and interference among adjacent wells. Novel pressure build-up test interpretation methods should be developed with the incorporation of these effects.
We developed a novel model to interpret formation pressure and formation physical properties, during the process of pressure build-up test, by incorporating stress interference among adjacent wells and two-phase flow of oil/water directly into the model. Trial approach was utilized to iteratively correct average formation pressure and permeability of oil and water phase, depending on the complexity of well interference systems. A simulation was developed based on this semi-analytical model which is capable of interpreting formation pressure and formation physical properties during the process of pressure build-up with much higher accuracy compared with traditional methods.
A numerical simulation in Eclipse was utilized to validate our model. Our interpretation results, including formation pressure, skin factor and permeability etc., are in fair agreement with the numerical simulation. We applied our model to conduct pressure build-up interpretation tests for testing wells in the Huabei Oilfield, and the precision of our model can reach up to 35.15% which has greater accuracy compared with traditional methods.
This novel model exhibits high efficiency and accuracy for pressure build-up test interpretation for the case with interference among adjacent wells and oil and water two-phase flow. This work provides an effective framework for pressure build-up test interpretation in fractured reservoir development.
Building Synergies, Strengthening Fundamentals, and Driving Leadership in Investment Decision Process within Petroleum Fields
Authors: Kenzhetayeva Z. , Fleming R. 
Published: November 2017

Abstract

Objectives/Scope
Development of the oilfields today contains significant complexity owing to competing technical, commercial, and risk requirements, requiring smart investments to yield positive returns. Tougher capital allocation and sustained low prices expose reservoirs' challenges, countries' risk and contractual issues bringing into a spotlight shortcomings of the decision-oriented process used by shareholders. The current paper presents a balanced approach to reduce overconfidence and bias in decision-making, strengthen financial position to meet new investment thresholds, and maximize the value from existing operations to sustain the ventures through a turbulent time.

Methods, Procedures, Process
The overall methodology represents a structural process for option evaluation and selection, providing end-users with the unified toolbox including visualized framework, recommendations, decision trees and diagrams. The proposed method 1) balances intuition and rules of thumb with conventional capital-budgeting methods and quantitative modeling, 2) supports an investment decision process focusing on implications of different sets of decisions, 3) applies probability theory with emphasis on the concept of expected value (EV), 4) detects areas to reduce risk and develop economic opportunity cost of capital, 5) finally, helps to form an understanding of different project variables, their interdependencies and influence on the overall result.

Results, Observations, Conclusions
The case study suggests that the initial set of decisions required an evaluation of 100 alternatives with hours of manpower and computer runs per outcome. By pairing down some of the constraints, we were able to generate a solution with 35 outcomes. This data was used to build technical scenarios and screen options in terms of economic attractiveness and ability to sanction. The 5 workable solutions with the highest ability to deliver value were scrutinized to select a development option. Further simulation has advised on specific areas that should be progressed to optimize the selected strategy, resulting in a reduction of upfront expenditures by 20% from the initial threshold and potential to deliver financially 43% of NPV growth, making a protracted and laborious process much simplified and rational.

Novel/Additive Information
The novelty of the concept is in its ability to tackle complex disparate issues by being a holistic and balanced in nature as well as equally efficient at different stages of a project. This allows an early focus on areas that have a genuinely significant impact on project commerciality. The findings will stimulate new progress - streamlining of proposed practice is key to drive robust engineering decisions in petroleum industry and enhance the value of decision process making it more flexible and accurate, and thus more attractive.
Evolution of the West Alboran Basin, Mediterranean, Offshore Morocco: Implications for Hydrocarbon Prospectivity
Authors: Aitken John F. , Beach Alastair , Al-Mansoori Khalfan 
Published: November 2017

Abstract
The West Alboran Basin, lying in the westernmost Mediterranean between Morocco and Spain, contains a thick (≥ 10 km), Tertiary sedimentary fill with abundant structures and excellent coverage by vintage 2-D seismic datasets. There are good indications of a working petroleum system yet the basin is highly under-explored with only a single well on the Moroccan margin and three wells offshore Spain.
It is a young basin (at oldest, latest Oligocene) and lies between the Betic and Rif fold and thrust belts, part of the Gibraltar Arc. The West Alboran Basin has typically been interpreted as a back-arc basin, however, by integrating all available data, it is proposed that it is more probably a fore-arc basin.
Hydrocarbon seeps from mud volcanoes indicate the presence of thermogenic hydrocarbons. Biomarker analysis suggests oil-window maturity of the oil seeps, indicating a Lower to Middle Miocene source. Although there is strong evidence for the presence of a mature oil source rock, the areal distribution, quality, age and type of the source rock remain largely unknown. Basin modelling suggests that the Middle and Lower Miocene are mature and capable of generating substantial hydrocarbons. The distribution of suspected oil seeps is best matched by a Middle Miocene oil-prone source while biogenic gas migration modelling results in a good match between predicted pools and known gas seeps.
Potential reservoirs are interpreted to comprise the deposits of various deep water environments, including turbidite fans, turbidite channels and mass transport complexes. Seismic geometries suggest the presence of such features.
Numerous leads at various stratigraphic levels have been identified. The majority of these are related to mud diaper traps but, in addition, a few 4-way dip closures as well as several stratigraphic trapping configurations also occur. Overall, the well-developed structures and good indications for a working petroleum system mean that the West Alboran Basin has significant potential as a new hydrocarbon province. The next logical step is to acquire high quality 3-D seismic data to further derisk the basin.
Electric Submersible Pump Performance and Numerical Modeling in Two- Phase Flow
Authors: Rutter Risa , Ye Zheng , Lack Ryan 
Published: November 2017

Abstract
Differential pressure (DP) between stages of multi-stage diffuser type centrifugal pump of an electric submersible pump (ESP), system was measured in a two-phase flow environment. The test results were used to improve existing numerical models and bubble size models for better prediction and to improve the design process. This paper details the comprehensive testing and model validation process for ESP pump stages.
Various sizes and types of ESP pump stages were tested in a high-pressure two-phase flow loop. Each stage performance was monitored using high-precision DP transducers. Test results were used to calibrate numerical simulation in two-phase flow. The correct bubble size for individual test conditions was calculated based on the test results. The bubble size calculation was crucial for good model prediction in two-phase flow. After several types and sizes of ESP stages were validated, same bubble size model could be used on other pump stages that have similar sizes and designs.
Presented in this paper are the actual gas volume fraction (GVF) handling capabilities of typical ESP stages, including the effects of flowrate, GVF, pump speed, inlet pressure, flow mixing and inlet/outlet effects.
After the lab test was complete, computational fluid dynamics (CFD) was used to investigate the hydraulic performance of the same stages and conditions tested in the lab. Simulation results were compared with test results and optimized for the correct bubble size of the secondary phase. The current bubble size model predicted very well for the lower GVF combined with large flow rate pump. The low flow pump had DP errors in excess of 10% for GVF values over 40%.
The validated numerical model can be used to improve pump modeling and enable improvements in pump design that could increase the gas-handling capabilities of pump stages of similar size and styles.
Implementation of a Successful Talent Management & Succession Planning Governance Framework
Authors: Khare Naveen , Koyadan Santhosh 
Published: November 2017

Abstract

Objectives/Scope
It is crucial for an integrated talent management and succession planning strategy to have close ties to organizational strategy and buy-in from the senior leadership. However, often the onus of applying these processes lies solely with the human resource function thereby not involving the line managers in the process. The purpose of this paper to present a best practice model to effectively integrate management personnel in the talent management and succession planning framework thereby fully utilizing them in ensuring optimal development of the talent pipeline.

Methods, Procedures, Process
In order to make the senior leadership active stakeholders in driving the process, we instituted ‘Talent Review Committees (TRC)’ at various levels to drive Talent Management and succession planning. The brief structure and role is as follows:
ADNOC Group level - chaired by ADNOC Group CEO with all Directors as members. Key positions considered - Directors and Group Company CEOs
Directorate level (one per directorate) - chaired by the director with all related group company CEOs as members. Key positions considered - SVP & equivalents
Group Company level (one per group company) - chaired by the Group company CEO with all SVPs as members. Key positions considered - up to VPs and technical positions
These committees review and approve the key positions, select potential successors, review their level readiness and recommend and monitor development activities. The output of these TRCs is combined at the corporate level to deliver a coherent talent management solution.

Results, Observations, Conclusions
Since ADNOC is a group of independent companies it is necessary to unify the talent management strategy in order to have a group-wide talent pool so that the need for capable leaders and specialists across the Group is continuously met. Multi-level governance structure to drive the talent management and succession planning process helps us in efficient identification and utilization of talent, making succession planning effective and accurate. The key results and conclusions are as follows: Identification, assessment and development of group-wide pools of internal candidates to improve their readiness to compete for future openings in key positionsAvailability of qualified successors and improved readiness & performance in target positionAccurate data availability to facilitate cross function/ company mobility and development opportunitiesEnsure that leadership continuity is in place and that strategic and operational capacity is sustained.

Novel/Additive Information
The paper offers an insight into the framework of multi-level talent review committees (TRCs) instituted across the ADNOC group as an effective model for integrating senior leadership into the talent development and succession planning framework.
Resolving Shale Drilling Instabilities in the Middle East: A Holistic & Pragmatic Geomechanical Method
Authors: Singh Hemant , Yadav Prahlad , Imtiaz Saad , Perumalla Satya 
Published: November 2017

Abstract
In the Middle East, a significant amount of Non-Productive Time (NPT) has been associated with controlling wellbore instability caused by weak shale before reaching the reservoir. Due to limited availability of pad locations and complex well trajectories, operators are now forced to drill high angle wells through shale as compared to vertical or low angle wells in the past. This has resulted in a substantial increase in drilling complications in terms of controlling shale instability.
Comprehensive geomechanical studies from various fields of Middle-East have helped to determine most plausible root causes of shale rock instability and to draw a holistic geomechanical approach to solve the problem. Shale samples (core and cuttings) were collected from multiple fields, and various types of lab tests were performed on these samples including XRD, XRF, chemical tests, rock mechanical tests etc. Geomechanical modeling and drilling analysis were performed to compare the drilling events to the shale characteristics in order to determine the mechanisms of rock failure. Chemoporoelastic and plane of weakness modeling techniques were also performed to understand some less-common failure mechanisms that were driving instability within these shales.
It was noted from the analysis that not all shales behave in a similar fashion. A potential solution that may solve instability problem in a particular field/region might not be effective in the other field/region. Geomechanical analysis suggested that a range of shale instability mechanisms ranging from stress induced failures and planes of weakness to complex rock-fluid interaction were responsible for hole instability, and different mud and drilling parameters are required to keep the hole stable in different shales. Raising the mud weight exclusively during drilling of these shales with multiple failure mechanisms was found to be ineffective and potentially counter-productive. A customized solution along with real-time geomechanics monitoring can help to mitigate shale instability in drilling of high angle wells.
A customized methodology for shale stability has been proposed in this paper based on integrated mechanical and chemical characteristics of most commonly encountered shales in the Middle East. This approach has helped to devise a comprehensive as well as practical approach to enhance drilling efficiency through shales in various fields in the region.
Development of Novel Foaming Agents for High Temperature Steam Applications
Authors: Sanders Aaron , Nguyen M. N. , Ren Ginger , Westemoreland Dana , Nguyen Quoc , Dong Susan , Rojas Carolina 
Published: November 2017

Abstract
The development of a new class of surfactants for high temperature steam foam applications has been investigated using both a new bulk foam screening test and core testing in the presence and absence of bitumen. A new screening methodology utilizing a high pressure cell fitted with viewing windows is described. Data is presented for the initiation and degradation rate of bulk foams for a number of surfactants at 190°C and 250°C.
Two surfactants Agent X and Agent Z were examined in core flood in the presence and absence of bitumen. At both 190°C and 250°C, the foaming agents were capable of creating stable foam. Core flood results in ~15 D sand pack at 250°C show that in the absence of bitumen, Agent X and Agent Z were capable of creating apparent foam viscosities of 3.9 and 17.7 cP, respectively. In the presence of bitumen the foaming ability was decreased, but foams created by both surfactants still maintained apparent viscosities of &gt;1 cP. Both surfactants produced foams that have shown shear thinning behavior under the conditions tested. Potential applications for high temperature foams are discussed in light of the results.