Abu Dhabi Company for Onshore Oil Operations

Abu Dhabi, United Arab Emirates

Abu Dhabi Company for Onshore Oil Operations

Abu Dhabi, United Arab Emirates
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Flahive T.,Abu Dhabi Company for Onshore Oil Operations
Society of Petroleum Engineers - SPE Kuwait Oil and Gas Show and Conference | Year: 2015

The purpose of this study is to carry out a participant Return on Investment (ROI) on one of ADCO's (Abu Dhabi Company for Onshore Oil Operations) Talent & Capability Management Division's (T&CMD) most important in-house programme - Leading People Performance (LPP). This programme is delivered by instructors from T&CMD. It is run over 2 modules of four days each. The LPP is designed to enhance the skills of managers by focusing on their ability to create and develop high performing teams and enabling these teams to function at optimal capacity. The programme is targeted at people who predominantly engage in people management responsibilities. Typically the participants will have between 5 to 10 years of relevant work experience and less than 5 years of relevant management experience. Participants are at grade 15 - 17 in a management / team leadership role. An overview of the programme can be found in appendix 1. This study will not only carry out an ROI from Level 1 (reaction) to Level 4 (impact), but will also introduce a Level 5 component (Transfer Climate), which identifies the environmental factors that help or hinder a learner from applying their new knowledge and skills when back on the job. For the purpose of this study the population comprised of LPP attendees from the last three delivery cohorts i.e. 12, 13 and 14. These programmes ran during 2013 and the first half of 2014. The total number of attendees (participants) was 47. © Copyright 2015, Society of Petroleum Engineers.

Abdallah D.,Abu Dhabi Company for Onshore Oil Operations
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference 2012, ADIPEC 2012 - Sustainable Energy Growth: People, Responsibility, and Innovation | Year: 2012

Gas injection is one of the most common methodologies for Enhanced Oil Recovery (EOR) in the oil and gas industry. One of the challenges associated with gas injection, e.g. natural gas, CO2 and N2, is potential asphaltenes precipitation and subsequent deposition causing blockage throughout the production system. It is crucial that precipitation of asphaltenes is identified early in the planning stage of any EOR project so that mitigation strategies are put in place to avoid negative impact on well performance. A line-drive pattern CO2 pilot is planned in a super giant field A onshore Abu Dhabi and hence single phase bottomhole samples were collected from a nearby well to evaluate asphaltene stability under CO 2 gas injection. This paper presents the results of the lab work that clearly indicate no asphaltene deposition problems during natural production; however, asphaltenes will precipitate when CO2 is mixed with the crude at mole fractions as low as 0.2. Based on the experimental results and on field results from another CO2 pilot in field B, which experienced asphaltene deposition problems, it was deemed necessary to include provisions for continuous downhole chemical injection of asphaltene inhibitors in the CO2 pilot producers for field A. The challenge is to combine the requirements to prevent CO2 corrosion and to prevent asphaltene deposition in the well. The paper describes the different completion design options that can be used to achieve the desired target taking into account the cost impact. The designs incorporate combinations of different tubing materials and chemical injection options with pros and cons to using each, keeping in mind the reservoir monitoring requirements that can add more constraints to the completion design. Copyright 2012, Society of Petroleum Engineers.

Subaih A.B.,Abu Dhabi Company for Onshore Oil Operations
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference 2012, ADIPEC 2012 - Sustainable Energy Growth: People, Responsibility, and Innovation | Year: 2012

This paper shows how individual employee needs and dynamic interactions, relationships and team building initiatives, implemented by ADCO with their EPC CONTRACTOR, have contributed to successfully managing one of their recent projects. The paper looks at the 'Joining Effort' of all personnel for a single interactive dynamic team, whilst considering the Project Management areas of Leadership, Management Structure / Change and Conflict Resolution. An added parameter was to ensure the technical production was to a high standard. From previous projects, major challenges experienced in project management have been many. The issues were all listed with the possible effects project wide. After all the challenges to the 'health of the project' were listed, solutions were identified in the following areas; install strong leadership, management structure/tools in place, one integrated team, taskforce champions, document composition for complex documents, aligning the document production with time, identifying resources shortfall, identifying quality issues, containing cost through design, employee needs and recognition, team building exercises and conflict resolution. Various theories (Maslow, Hertzberg & others) involving emotional, psychological and motivational areas were investigated. These verified that the solutions put in place should work. The results proved positive. Primary points were; attitude change (self esteem/self-actualization), strong trust and low conflict. These aspects led onto many more beneficial results, especially within the team framework. The added 'Technical' parameter looked into the effect of having a technically sound project as compared with a not so technically sound project. There is no Magic for creating the project success that everyone is trying to achieve. But probably it could be described as a magic dynamic formula involving the employee, the team and the technical. The project is on time, to budget, of good quality and with safety covered. Being pro-active and identification of possible problems up front, allows solutions to be put in position. Bringing all personnel (the project teams) together, to act as one unit, is a pre-requisite for this to happen. Copyright 2012, Society of Petroleum Engineers.

Reddicharla N.,Abu Dhabi Company for Onshore Oil Operations
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference, ADIPEC 2015 | Year: 2015

The rise in important initiatives such as asset modelling & well integrity assessment in ADCO has clearly identified the need for effectively managing the down-hole completion data across drilling and assets. The down-hole completion data has become more strategic to ADCO. The completion schematic standards, data visualization, phase-out legacy systems for preparation of down-hole schematic, data ownership & data integration amongst other challenges which were addressed as part of this automation project. The previous/old workflow utilizes third-party visualization software to display downhole completions equipment. However, well schematics being generated by these workflows displayed are standardized images and are not data-driven. The engineer will essentially build up the image separately and then enter the data into well-schematic as primarily text-based data entry. This leads to creation and maintenance of multiple reports, spreadsheets and other sources of data to inform the engineer as to the current status of downhole equipment in the wellbore. Well integrity assessment (such as MAASP calculations⋯etc) and well performance modelling (Inflow performance calculation) has clearly impacted due to unavailability of completion data at right time. The new prescribed workflow acts as a bridge between the drilling and assets. This automated workflow enhanced the data quality by using standard data entry template and visualization solution using standard completion templates (single, dual, smart completion⋯etc) and completion symbols which involves managing the time required from the drilling engineers, completion engineers and drilling supervisors. There are guidelines for data quality checking through the use of data validation rules and verification using visualization has been established in this automated workflow. The workflow has identified the business and data interfaces required to be considered for automation. The petroleum engineers are notified in their real time optimization solution when a new well completion has been added and whenever there is a change in existing well configuration & completion design and prompt them to create or update the well performance models. The data is also retrieved for well integrity purposes as well with notifications. The Engineers are required to understand mechanism and workflows governing the usage of this automated workflow, so that they generate reliable and sustainable well-schematics templates in a self-sufficient process, certain tasks may be performed in advance to increase efficiency of the workflow and reduce overall time spent in data preparation and generating a complete well-schematic for the hand-over. The templates that satisfy business and technical criteria, an engineer can make huge time gains while generating well-schematics. This workflow automation further facilitated as common access point for all required completion data with clear data ownership, governance, standard visualizations & schematics & ensures the availability of the data at the right time. Copyright 2015, Society of Petroleum Engineers.

Caicedo S.,Abu Dhabi Company for Onshore Oil Operations
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference, ADIPEC 2015 | Year: 2015

During the pump sizing, artificial lift (AL) engineers usually deal with the problem of deciding the setting depth of the pump and the target production rate. There is a trade-off regarding the pump's depth; the deeper the pump, the lower the free gas, the higher the potential rate, the higher the submergence but the higher the cost, and the higher the temperature. The present paper shows a method to suggest setting depth and target rate simultaneously. Sometimes there are so many constraints that the setting depth is imposed by the reservoir, well completion, integrity or safety conditions. In other circumstances, there can be a wide range of possibilities, which will be discussed in this paper. One of the most important parameters to evaluate is the free gas into the pump because it will greatly affect the performance of the pump, besides requiring more volume capacity, the free has other consequences such as locking the ESP, affects the PCP elastomer, reduces the compression ratio in SRP and increases the required power fluid pressure and/or rate in JP. The free gas limits and solutions vary for each method, but all of them require knowing the actual value, independently of the pumping method (i.e. ESP, PCP, SRP or JP). The engineer has to start by imposing the pump's depth and after some computations check if that depth is feasible or not for the target rate. If it is not feasible two actions can be done: to reduce the target rate and/or to install the pump deeper. On the other hand, if the pump can handle the free gas then a question arises: could the pump be installed shallower keeping the same target rate? This question can only be answered by computing free gas and displaying it in some way together with the reservoir inflow. In order to avoid this trial and error process, this paper defines and suggests the Enriched Inflow Performance Relationship (EIPR) curves at pump intake for different setting depths, each one showing points highlighted using a colour scale to indicate free gas conditions into the pump. The free gas displayed mainly depends on the Pump Intake Pressure, Bubble Point Pressure, GOR, Water Cut, downhole gas separation efficiency. Since the reservoir performance is included, these EIPR Curves easily allow simultaneous selection of target rate and pump setting depth while visualizing free gas conditions which avoids the trial and error process showing a more realistic application window of the method. All previous papers just display standard inflow curves. There is no previous work showing additional attributes in the IPR curve that helps the engineer to visualise the corresponding conditions of the pump. Copyright 2015, Society of Petroleum Engineers.

David R.M.,Abu Dhabi Company for Onshore Oil Operations
Proceedings - SPE Annual Technical Conference and Exhibition | Year: 2016

Exploration and Production companies are increasingly instrumenting their fields with the objective to proactively monitor and surveillance of its wells, reservoir, and facilities for safe and better operations. With this scenario, there is ever increase in the volume and variety of data being generated to support workflows such as real time drilling operations, production surveillance and reservoir monitoring. Data Analytics enables to get most value out of the vast volume of data being generated. In order to extend the present limits of digital oil field envelope from operations monitoring, companies need to harness data analytics to identify patterns, trends, correlation, forecasting out of its vast petroleum data. This includes exception based surveillance, case based reasoning, and condition based monitoring in order to facilitate advanced monitoring, and to support tactical and strategic decision-making process. To establish data analytics environment it requires systematic way of capturing, storing and managing data, integrating and embedding data analytics into the mainstream sub-surface, drilling, production and operations workflows which includes integrated reservoir monitoring, drilling and production optimization. Data analytics technology blends traditional data analysis with sophisticated algorithms and business rules for processing large volumes of diverse types through an Integrated Data Analytics Environment (IDE). Data governance is a vital part of IDE to ensure there is clear ownership and responsibilities as the accuracy of the results are as good as the quality of the data. IDE environment enables systematic harvesting of operational event, lessons learnt and best practices to enable knowledge based operations decisions. The integrated data analytics platform enables integrating E&P workflows and data analytics to enhance operations monitoring, predict well productivity, identify performance patterns and KPI, improve reservoir recovery factor, and predict equipment failure, towards achieving the objective of continuous optimization of oilfield performance. Copyright 2016, Society of Petroleum Engineers.

Kannan J.,Abu Dhabi Company for Onshore Oil Operations
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference, ADIPEC 2015 | Year: 2015

Artificial lift ESP's were installed in ADCO SHAH Field in the year 1994 to enhance recovery and sustain production. As of September, 2015 Shah Field has a total of 60 oil producers with ESP's, mostly characterized by applications with high water cut and low intake pressures. Additional wells are being drilled to enhance production. High water cut and low intake pressures possessed a challenge, resulting in premature ESP failures thus impacting field performance indicators and cost of work over for ESP replacement. To overcome these challenges ADCO has adopted optimization strategy to enhance oil production in a mature field by understanding the ESP system & reservoir conditions as an integral unit. Shah Field has achieved one of the highest ESP run life of more than 15 years (Well no Sy-32 still running) and 6 more wells operating beyond the MTTF indicator. The objective of this paper is to share ADCO's successful optimization strategy to increase ESP life. Copyright 2015, Society of Petroleum Engineers.

Shaluf I.M.,Abu Dhabi Company for Onshore Oil Operations | Abdullah S.A.,Abu Dhabi Company for Onshore Oil Operations
Journal of Loss Prevention in the Process Industries | Year: 2011

Storage tanks are important facilities for the major hazard installations (MHIs) to store large quantity of crude oil. There is several fire types can occur with large diameter open top floating roof storage tanks. Boilover is considered one of the most dangerous fires in large-scale oil tank. The world has witnessed many incidents due to boilover in floating roof storage tank. Boilover problem has been studied in experiments and by models to understand how to control the boilover phenomena. An experimental study has been carried out in Jebel Dhanna (JD) terminal area by Abu Dhabi Company for Onshore Oil Operations (ADCO) with support of Resource Protection International (RPI) consultant. 2.4. m diameter and 4.5. m diameters pans have been used to study the characteristics of the large oil-tank fires (i) to gain more knowledge of the boilover phenomenon of crude oil (ii) verify if the crude oil stored by ADCO would boilover (ii) estimation of rate of hot-zone growth and the period needed from ignition to boilover (iii) estimation of radiant heat and consequences of boilover. This paper presents an overview on the floating roof storage tank boilover. The paper also presents briefly boilover experimental research study carried out by ADCO. © 2010 Elsevier Ltd.

Whelan J.,Royal Military College of Canada | Abdallah D.,Abu Dhabi Company for Onshore Oil Operations | Wojtyk J.,Royal Military College of Canada | Buncel E.,Queen's University
Journal of Materials Chemistry | Year: 2010

Despite the recognition of the importance of Spiropyran (SP)-Merocyanine (MC) photochromic materials in molecular switching, the majority of studies have been reported in solution with relatively few in the solid-state as required in modern displays and other devices. In contrast, the present work bridges solution, condensed phase and solid-phase media and is to our knowledge the first micro-environmental study on electronic and kinetic effects for the SP-MC system. Expanding on our previous work we have investigated the photochromic properties of an SP molecule (1b) attached to a 100 μm commercially available polystyrene micro-particle (Wang Resin). The thermal MC → SP reversion kinetics (5a,b → 4a,b and 2a,b → 1a,b) which reflect the critical lifetime of the open MC form were measured. Reduction in k obs of thermal reversion, MC → SP, up to two orders of magnitude, and a blue-shift up to 58 nm was observed with the potential for tailoring or fine tuning. The use of polymeric micro-particles in controlling both electronic and kinetic properties of photochromic molecular switches has been highlighted. © The Royal Society of Chemistry 2010.

Sirat M.,Abu Dhabi Company for Onshore Oil Operations
Arabian Journal of Geosciences | Year: 2013

Artificial neural networks (ANNs) were applied to data taken from 1,302 domestic and rural hydraulic wells in the Mid-continent of the USA including Illinois, Iowa, and other 12 States to predict the contamination of the groundwater with pesticides. Preliminary hydrogeological and geostatistical analyses were carried out to assess groundwater vulnerability and data variability and weight, where data attributes were pre-processed and grouped into three main categories: hydrologic, human interaction, and climatic groups. ANNs are computer parallel-based systems that are characterized by their topologies, transfer functions, and learning algorithms. The backpropagation network (BP-NN) learning algorithm, used here, involves incremental adjustment of a set of parameters to minimize the error between the desired output and the actual output. Sensitivity analysis of the main BP-NN attributes was conducted to improve the BP-NN performance. Results of several trials demonstrated that the BP-NN have predicted the contaminated wells within each minor group in high precision. Sensitivity analysis revealed that BP-NN topologies and transfer functions were the main factors that affected its performance. It is evident that BP-NN is a powerful tool to predict the groundwater contamination over a wide area with limited data availability, which can provide an alternative cheap and effective tool to assess groundwater contamination worldwide. © 2012 Saudi Society for Geosciences.

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