Open-Hole Logging While Tripping LWT Through Drill Pipes, as a New Technology for Risk Mitigation and Cost Optimization in Abu Dhabi Onshore Fields

2019 ◽  
Author(s):  
Fathy ElWazeer ◽  
Hicham A. Chaker ◽  
Maarten Propper
Keyword(s):  
Risk Mitigation ◽  
New Technology ◽  
Cost Optimization ◽  
Abu Dhabi ◽  
Open Hole ◽  
Drill Pipes

scholarly journals Use of failure modes and effects analysis to mitigate potential risks prior to implementation of an intravenous compounding technology

2021 ◽  
Author(s):  
Agnes Ann Feemster ◽  
Melissa Augustino ◽  
Rosemary Duncan ◽  
Anand Khandoobhai ◽  
Meghan Rowcliffe
Keyword(s):  
Medication Safety ◽  
Failure Modes ◽  
Risk Mitigation ◽  
New Technology ◽  
Hazard Index ◽  
Mitigation Strategies ◽  
Investigational Drug ◽  
Workflow Optimization ◽  
Proactive Approach ◽  
Risk Mitigation Strategies

Abstract Disclaimer In an effort to expedite the publication of articles related to the COVID-19 pandemic, AJHP is posting these manuscripts online as soon as possible after acceptance. Accepted manuscripts have been peer-reviewed and copyedited, but are posted online before technical formatting and author proofing. These manuscripts are not the final version of record and will be replaced with the final article (formatted per AJHP style and proofed by the authors) at a later time. Purpose The purpose of this study was to identify potential failure points in a new chemotherapy preparation technology and to implement changes that prevent or minimize the consequences of those failures before they occur using the failure modes and effects analysis (FMEA) approach. Methods An FMEA was conducted by a team of medication safety pharmacists, oncology pharmacists and technicians, leadership from informatics, investigational drug, and medication safety services, and representatives from the technology vendor. Failure modes were scored using both Risk Priority Number (RPN) and Risk Hazard Index (RHI) scores. Results The chemotherapy preparation workflow was defined in a 41-step process with 16 failure modes. The RPN and RHI scores were identical for each failure mode because all failure modes were considered detectable. Five failure modes, all attributable to user error, were deemed to pose the highest risk. Mitigation strategies and system changes were identified for 2 failure modes, with subsequent system modifications resulting in reduced risk. Conclusion The FMEA was a useful tool for risk mitigation and workflow optimization prior to implementation of an intravenous compounding technology. The process of conducting this study served as a collaborative and proactive approach to reducing the potential for medication errors upon adoption of new technology into the chemotherapy preparation process.

First Application of Controlled Release Smart Tracer Technology for Inflow Monitoring in Offshore Abu Dhabi – Towards Cost Optimization and De-Risking Operation

2018 ◽  
Author(s):  
Ajay Samantray ◽  
Cai Kaiping ◽  
Thani Al Neyadi ◽  
Sultan Almazrouei ◽  
Mohamed Al Marzouqi ◽  
...  
Keyword(s):  
Controlled Release ◽  
Cost Optimization ◽  
Abu Dhabi

3LRM-3 Layer Risk Mitigation Modelling of ICT Software Development Projects

2016 ◽  
Vol 6 (1) ◽  
pp. 349 ◽  
Author(s):  
Salma Firdose ◽  
L. Manjunath Rao
Keyword(s):  
Software Engineering ◽  
Software Development ◽  
Risk Mitigation ◽  
New Technology ◽  
Development Project ◽  
Risk Modelling ◽  
Software Development Project ◽  
Critical Issues ◽  
Random Probability ◽  
Adoption Of New Technology

With the adoption of new technology and quality standards, the software development firms are still encountering the critical issues of risk modelling. With the changing dynamics of customer needs, potential competition has being mushrooming in the global IT markets to relay a new standard of software engineering which has higher capability of sustaining risk.  However, till date, it is still theoretical to large extent from research viewpoint. Hence, this paper presents a mathematical model called as 3LRM that is designed with the simple approach keeping in mind the real-time issues of risk factors in software engineering for ICT software development project. The study has also identified requirement volatility as one of the prominent source of risk and hence, the framework intends to identify a risk as well as mitigating the risk to a large extent. The paper is illustrated with some of the simple statistical approaches of random probability.

Evolution of Completion Techniques in the Lower Shaunavon Tight Oil Play in Southwestern Saskatchewan

2015 ◽  
Author(s):  
D. J. Schlosser ◽  
M.. Johe ◽  
T.. Humphreys ◽  
C.. Lundberg ◽  
J. L. McNichol
Keyword(s):  
Oil And Gas ◽  
New Technology ◽  
Oil And Gas Industry ◽  
Field Trials ◽  
Gas Industry ◽  
Point Energy ◽  
Horizontal Drilling ◽  
Oil Reserves ◽  
Coiled Tubing ◽  
Open Hole

Abstract The Oil and Gas industry has explored and developed the Lower Shaunavon formation through vertical drilling and completion technology. In 2006, previously uneconomic oil reserves in the Lower Shaunavon were unlocked through horizontal drilling and completions technologies. This success is similar to the developments seen in many other formations within the Williston Basin and Western Canadian Sedimentary Basin including Crescent Point Energy's Viewfield Bakken play in southeast Saskatchewan. In the Lower Shaunavon play, the horizontal multistage completion era began in 2006, with horizontal divisions of four to six completion stages per well that utilized ball-drop sleeves and open-hole packers. By 2010, the stage count capabilities of ball-drop systems had increased and liners with nine to 16 stages per well were being run. With an acquisition in 2009, Crescent Point Energy began operating in the Lower Shaunavon area. The acquisition was part of the company's strategy to acquire large oil-in-place resource plays. Recognizing the importance that technology brings to these plays, Crescent Point Energy has continuously developed and implemented new technology. In 2009, realizing the success of coiled tubing fractured cemented liners in the southeast Saskatchewan Viewfield Bakken play, Crescent Point Energy trialed their first cemented liners in the Lower Shaunavon formation. At the same time, technology progressed with advancements in completion strategies that were focused on fracture fluids, fracture stages, tool development, pump rates, hydraulic horsepower, environmental impact, water management, and production. In 2013, another step change in technology saw the implementation of coiled tubing activated fracture sleeves in cemented liner completions. Based on field trials and well results in Q4 2013, Crescent Point Energy committed to a full cemented liner program in the Lower Shaunavon. This paper presents the evolution of Crescent Point Energy's Lower Shaunavon resource play of southwest Saskatchewan. The benefits of current completion techniques are: reductions in water use, increased production, competitive well costs, and retained wellbore functionality for potential re-fracture and waterflooding programs.

15K Multistage Fracturing Completion System Addresses Operational Challenges, Improves Production Performance and Cost Savings in Openhole Environments

2021 ◽  
Author(s):  
Rasim Serdar Rodoplu ◽  
Adegbenga O. Sobowale ◽  
Jon E. Hanson ◽  
Beau R. Wright
Keyword(s):  
New Technology ◽  
Cost Savings ◽  
Cost Effective ◽  
Production Performance ◽  
High Rate ◽  
Field Development ◽  
Additional Equipment ◽  
Effective Manner ◽  
Open Hole ◽  
The Right

Abstract Multistage fracturing (MSF) ball drop completion systems have been utilized around the globe for effectively treating formations completed as open hole and cemented. Multiple, high-rate hydraulic fracturing stages are pumped through these completions while gaining efficiency during pumping operations. A challenge within the industry was developing systems that are capable of higher pressures (greater than 10k psi) while still being able to be deployed in challenging openhole environments with minimum equipment and intervention requirements. This paper will discuss the planning, deployment and fracturing execution operations of an improved version of one of these systems. To be able to effectively utilize any MSF completion system; formation properties, deployment environment, lateral length, openhole size, liner size, and tubing movements during fracturing should be thoroughly analyzed and equally considered. To create a reliable system, another important consideration is how the system will be deployed; a long string to surface, or will it be deployed as part of a liner hanger system? In the case of the latter, it should be compatible with the liner hanger system by accommodating multiple balls to set and release the hanger system and actuate the openhole packers. In tight formation environments, where treating pressure differentials reaches as high as 15,000 psi during fracturing operations, openhole packers that are capable of holding these pressures in challenging openhole conditions are needed. Not only the packers but also the remaining completion system components need to be capable of withstanding, including burst, collapse, and ball-to-ball seat differential while simultaneously accommodating the pressure with cooling and ballooning induced tubing movement caused by these high pressure treatments. Improving such a robust design with innovative solutions, such as dissolvable frac balls that can handle 15,000 psi differential, optimizes the overall process. The completion design, deployment, and subsequent fracturing operations on a well showcases how effective consideration of components operates as a system can create a reliable MSF system. It also demonstrates how close collaboration between reservoir management, production engineering, completion experts, and vendor results in a coordination of efforts that eliminates operational hazards, thus ensuring smooth operations. The successful deployment of an openhole MSF completion system that can handle 15,000 psi with dissolving frac balls and eliminating openhole anchors helped pave the way to deal with tighter formations in an efficient and cost-effective manner. With the help of this new technology, the well planners were able to address operational challenges that would have otherwise required additional equipment or would have limited deployment capabilities. The engineering approach and design to develop this completion system and utilization in the right candidate confirmed the benefit of the novel completion for field development options.

First Deployment of Motorized Casing Reamer Shoe in Abu Dhabi Offshore

2021 ◽  
Author(s):  
Hanifan Mayo Biyanni ◽  
Suhail Mohammed Al Ameri ◽  
Erwan Couzigou ◽  
Prashant Gohel ◽  
Adelson Jose Calleia De Barros ◽  
...  
Keyword(s):  
Technology Implementation ◽  
High Speed ◽  
Risk Mitigation ◽  
Lessons Learned ◽  
Minimum Requirement ◽  
Novel Approach ◽  
Open Hole ◽  
Finger Printing ◽  
Intermediate Solution ◽  
Pump Pressure

Abstract The paper will describe a novel approach of deploying casing through a problematic open hole. It involves a drillable hydraulic motorized casing reamer shoe that can rotate freely without aid of pumping, but once resistance is encountered, pump pressure can then be applied to engage the drive mechanism inside the tool. Thus it will turn into a high-speed reaming shoe that delivers sufficient reaming action. A market research was done to find a quick intermediate solution to tackle difficulty in deploying casing down to section TD. A turbine based motorized reamer shoe was then selected to encounter the challenge with some risk mitigation in place. The first deployment was run in the well where it was identified as a challenging well context and had experienced casing being held up in the first run. Despite the fact that a wiper trip has smoothened the hole condition, the parameters that were captured during the running, the finger printing, the cementing job, and the drilling out of the shoe had ticked some boxes to evaluate the suitability of the technology implementation in the field. Moreover, the lessons learned from the first run itself has also led to further testing and modification of the tool design/setup itself. The detailed analysis and operation feedback from casing running job and subsequent operation will be beneficial to provide other operators in assessing the minimum requirement and suitability of this technology utilization to overcome the drilling challenge.

Automated Reservoir Management Workflows to Identify Candidates and Rank Opportunities for Production Enhancement and Cost Optimization in a Giant Field in Offshore Abu Dhabi

2021 ◽  
Author(s):  
Carlos Mata ◽  
Luigi Saputelli ◽  
Dorzhi Badmaev ◽  
Wenyang Zhao ◽  
Richard Mohan ◽  
...  
Keyword(s):  
Machine Learning ◽  
Net Present Value ◽  
Cost Optimization ◽  
Production Performance ◽  
Added Value ◽  
Machine Learning Techniques ◽  
Abu Dhabi ◽  
Time Duration ◽  
Data Set ◽  
Infill Drilling

Abstract As the field matures and overall field production decline, an accelerated and advanced selection of existing wells for workovers and sidetracks would be critical to meet with the increasing demand for production. Traditionally, an intensive effort is required to identify the right candidates and to ensure the technical and economic success of well interventions, infill-drilling locations and sidetrack locations. An advanced workflow is developed to automate the repetitive and less added value tasks such as data gathering and validation. The data set included historical production performance, static and dynamic reservoir and fluid properties, events and issues encountered within the evaluated wells and regions. The proposed solution allowed an integrated assessment of production enhancement opportunities through various consistent analytic computations, as well as machine learning techniques including Bayesian networks and time-series forecasting models. The automated process generates a comprehensive list of future well interventions including sidetrack candidates, infill-drilling locations and behind casing opportunities with an advanced scoring system and several technical (production performance and reserves) and financial KPIs (i.e. net present value and unit technical cost). Several dashboards built and adjusted with the involvement of various company departments. Lastly, highly ranked opportunities are incorporated into the business plan in accordance to field development targets as well as the availability technical resources (rigs, materials, well availability). The developed solution was tested and validated in a giant mature carbonate field with over 700 well strings in Offshore Abu Dhabi. The solution identified 20 times more feasible opportunities than the typical multidisciplinary team review in 75% less time duration. The automated workflows considered re-evaluating and selecting prime candidates with a reduced risk of failure, therefore improving the technical and economic value by 34%. The workflows are scheduled on daily basis giving a time-dependent assessment and expert monitoring system, which can also notify the operator when problems encountered. Instead of computationally heavy traditional numerical simulation models, the assessment of a large number of well count can be done within hours instead of months. The combination of physics and machine learning based models lead to the development of automated workflows to rank and determine the best candidates via a successful cost optimization and production enhancement.

New Technology Yields High-Resolution 3D Modeling for Fracture Analyses

2021 ◽  
Vol 73 (11) ◽  
pp. 70-71
Author(s):  
Chris Carpenter
Keyword(s):  
High Resolution ◽  
United Arab Emirates ◽  
New Technologies ◽  
New Technology ◽  
Bedding Plane ◽  
Abu Dhabi ◽  
Foot Wall ◽  
Shelf Area ◽  
Carbonate Sediments ◽  
Artificial Lake

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 203108, “High-Resolution Fracture Analyses and 3D DMX DFN Modeling of Triassic Dolomites, Wadi Bih, Ras Al Khaimah, UAE,” by Janpieter van Dijk and Raffik Lazzar, GeoModl, prepared for the 2020 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, held virtually 9–12 November. The paper has not been peer reviewed. The complete paper outlines a high-resolution 3D fracture modeling exercise using the DMX protocol applied to Triassic dolomites of the United Arab Emirates. The outcropping rocks show a low primary porosity, are well bedded, and are highly fractured (jointed) up to centimeter scale. The exercise shows the relevance of applying new technologies to outcrop observations and shows several elements and related technologies that, to the authors’ knowledge, have not been presented previously. Introduction The focus area of the complete paper is a small outcrop situated in Wadi Bih in the territory of Ras Al Khaimah (Fig. 1) along a small road near a recently constructed artificial lake. This outcrop, which is approximately 150 m2 in size, shows well-bedded, highly fractured Triassic dolomites. Both section views and bedding-plane views can be observed. The outcrop was selected because it represents an analog of the Triassic Khuff formation, an important hydrocarbon-producing reservoir in the region. The outcrop is easily accessible and displays a clearly defined fracture (joint) network with recognizable sets, also showing truncation relationships between fractures, joints, and bedding that can be examined. Geological Context The area shows a complete series of Permian to Cretaceous, mostly carbonate sediments, outcropping in a series of north/south to north-northeast/south-southwest anticlines and synclines bounded by mostly west-vergent thrust faults. The Wadi Bih outcrop is situated on the moderately east-dipping flank of the north/south-trending Hagab Anticline, also called the Hagil Window after the area of the nearby Wadi Hagil, where the deepest Permian series are outcropping in the core of the anticline. This anticline is situated on the foot-wall of a major north/south-trending thrust fault. The geological history of the area is connected to the initial Mesozoic deposition of the series on the shelf area along the northeast flank of the Arabian shield. In the outcrop study, the focus is on the joint network. The authors write that this network is tilted together with the bedding as part of the flank of the anticline. No relation can be detected between the joint network sets and the fault and anticline axis pattern dominating the area. The joint network, therefore, most probably was formed in the early stages after lithification and dolomitization of the rock.

Integrated Optimization of SIMOPS (Drilling, Well Intervention, and Production) on Jackup Rig : a Case Study of Under Cantilever Operations at X-1 Platform in Mahakam Asset

2020 ◽  
Author(s):  
R. Hidayat
Keyword(s):  
Cost Optimization ◽  
Final Analysis ◽  
Hydrocarbon Production ◽  
Offshore Area ◽  
Integrated Optimization ◽  
Double Edge ◽  
Double Edge Sword ◽  
Open Hole ◽  
Initiative Process

Deliverability of a field shall be reflected through its hydrocarbon production. In offshore fields, the backbone for stability of production comes from drilling and well intervention operations. One makes new wells while the other maintains existing wells to minimize impact of the decline. Nevertheless, these operations may become a double-edge sword for production. For example, rig activities that shut in existing wells in an offshore platform create production loss of that field. This situation may be ludicrous, but it is a dire consequence for mature/sensitive wells, in which potential loss might be proportional to shut in duration required. This ironic situation prompts two (2) challenges which are to maintain production existing wells and to start production of new wells while respecting the safety aspect in operation. Thus, in order to overcome these challenges, an integrated optimization of SIMOPS between drilling, well intervention and production is ushered in X-1 drilling campaign where production activities continue and well intervention operates under cantilever of the jackup rig during the whole drilling campaign.PT Pertamina Hulu Mahakam (PHM) delivers one well in offshore area between 17-25 days in average, depending on the well type. As a continuous saving initiative process, every possible scenario was exercise to optimize cost and three (3) objectives were identified for cost optimization which are to reduce the shortfall of existing wells by re-perforation to revive well, optimize rig duration at respective wells safely through offline well intervention activities and accelerate the production of new wells. As a result, all three (3) objectives had been achieved during the complex campaign with deliverability including no LTI during operation, three (3) new wells , two (2) workover and sidetracked wells with longer open hole record at X-1, offline well intervention activities (perforation) of existing well at X-1, offline production activities to revive existing wells at X-1 through offload to atmosphere and offline well connection activities for new wells (earlier). In the final analysis, integrated SIMOPS optimization generates production gain and enhances cost effectiveness safely. This paper shall provide the methodology to design and prepare an integrated SIMOPS as well as the corresponding result and lesson learnt.

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