Successful Pilot of DIAL Digital & Interventionless Gas Lift Production Optimization System Offshore Malaysia

2021 ◽  
Author(s):  
Zaidi Awang@Mohamed ◽  
Jagaan Selladurai ◽  
Siti Nur Mahirah Mohd Zain ◽  
Juhari Yang ◽  
Badroel Rizwan Bahar ◽  
...  
Keyword(s):  
Real Time ◽  
Continuous Production ◽  
Gas Injection ◽  
Value Added ◽  
Lessons Learned ◽  
Production Optimization ◽  
Design Stage ◽  
Optimization System ◽  
The Impact ◽  
Gas Lift

Abstract Objectives/Scope This paper describes a pilot installation of a digital intelligent artificial lift (DIAL) gas lift production optimization system. The work was inspired by PETRONAS' upstream digitalization strategy with five single and dual-string gas lift completions planned from 2018 to 2020, offshore Malaysia. The authors evaluate the impact of the DIAL system in terms of increasing production, optimizing lift-gas injection, reducing well intervention frequency, as well as OPEX and risk reduction. Methods, Procedure, Process DIAL is a unique technology that enhances the efficiency of gas lift production. Downhole monitoring of production parameters informs remote surface-controlled adjustment of gas lift valves. This enables automation of production optimization removing the need for well intervention. The paper focuses on a well installed in June 2020, the first in a five well campaign. The authors will provide details of the technology, and pilot program phases: system design; pre-job preparations; run in hole and surface hook-up; commissioning and unloading; and subsequent production operations. For each phase, challenges encountered, and lessons learned will be listed together with observed benefits. Results, Observations, Conclusions DIAL introduces a paradigm shift in the design, installation, and operation of gas lifted wells. This paper will compare the differences between this digital technology and conventional gas lift techniques. It will consider the value added from the design stage through installation operations to production optimization. The DIAL system's ability to operate at greater than 80-degree deviation enabled deeper injection while avoiding tractor interventions for GLV maintenance in the highly deviated section of the well. Built-in downhole sensors provided real-time pressure monitoring that enabled a better understanding of reservoir behaviour and triggered data-driven reservoir stimulation decisions. The technology also proved very beneficial for production optimization, with the intervention-less adjustment of gas injection rate and depth downhole, based on the observed reservoir response in real time. The variable port sizes can be manipulated by means of surface switch/control. Overcoming the completion challenges due to COVID-19 restrictions, the well was unloaded and brought online with the assistance of personnel located in Houston and Dubai using Silverwell's visualization software. The well continues to be remotely monitored and controlled ensuring continuous production optimization, part of PETRONAS' upstream digitization strategic vision. Novel/Additive Information First deployment worldwide of new and unique gas lift production optimization technology in offshore highly deviated well. The technology deployment was the result of collaborative work between a multi-discipline engineering team in PETRONAS, Silverwell, and Neural Oilfield Service.

World'S First Successful Dual String Installation of a Digital Intelligent Artificial Lift DIAL - Interventionless Gas Lift Production Optimization System, Offshore Malaysia

2021 ◽  
Author(s):  
M Haziq M Ghazali ◽  
M Rizwan Rozlan ◽  
M Farris Bakar ◽  
M Faizatulizuddin Ishak ◽  
Orient Balbir Samuel ◽  
...  
Keyword(s):  
Continuous Production ◽  
Value Added ◽  
Lessons Learned ◽  
Production Optimization ◽  
Design Stage ◽  
Production Operation ◽  
Optimization System ◽  
Artificial Lift ◽  
Degree Deviation ◽  
Gas Lift

Abstract PETRONAS completed well H-X on B field in Malaysia with a digital intelligent artificial lift (DIAL) gas lift production optimization system. This DIAL installation represents the first ever successful installation of the technology in an Offshore well for Dual String production. This paper provides complete details of the installation planning and operational process undertaken to achieve this milestone. DIAL is a unique technology that enhances the efficiency of gas lift production. Downhole monitoring of production parameters informs remote surface-controlled adjustment of gas lift valves. This enables automation of production optimization removing the need for well intervention. This paper focusses on a well completed in November 2020, the fourth well to be installed with the DIAL technology across PETRONAS Assets. The authors will provide details of the well and the installation phases: system design, pre-job preparations, improvements implementation, run in hole and surface hook-up. For each phase, challenges encountered, and lessons learned will be listed together with observed benefits. DIAL introduces a paradigm shift in design, installation and operation of gas lifted wells. This paper will briefly highlight the justifications of this digital technology in comparison with conventional gas lift techniques. It will consider value added from the design stage, through installation operations, to production optimization. This DIAL system installation confirms the ability to be implement the technology in a challenging dual string completion design to enable deeper injection while avoiding interventions on a well with a greater than 60-degree deviation. With remotely operated, non-pressure dependent multi-valve in-well gas lift units, the technology removes the challenges normally associated with gas-injected production operation in a dual completion well – gas robbing and multi-pointing. Despite the additional operational & planning complications due to COVID-19 restrictions, the well was completed with zero NPT and LTI. Once brought online, this DIAL-assisted production well will be remotely monitored and controlled ensuring continuous production optimization, part of PETRONAS’ upstream digitization strategic vision.

scholarly journals The impact of the COVID-19 pandemic on digital globalization

2021 ◽  
Vol 129 ◽  
pp. 06008
Author(s):  
Maria Loredana Popescu ◽  
Svetlana Platagea Gombos ◽  
Sorin Burlacu ◽  
Amza Mair
Keyword(s):  
Global Economy ◽  
World Economy ◽  
Value Added ◽  
Digital Transformation ◽  
Lessons Learned ◽  
Health Crisis ◽  
Main Research ◽  
Documentary Analysis ◽  
The Impact

Research background: After more than a year of the Covid-19 pandemic, we can investigate whether it caused a shock to the global economy, pushing for deglobalization, or on the contrary, it was a challenge for digital globalization and digital transformation of economies. Through this research we join the research contributions that examine the process towards digital globalization that characterizes the world economy, its impact on businesses, consumers, and governments. We also discuss the challenges posed by the crisis caused by the coronavirus pandemic to globalization and perhaps the acceleration of the digital transformation of economies. Purpose of the article: The aim of this research is to highlight the impact of the COVID-19 pandemic in the age of digital globalization. Methods: Documentary analysis, as the main research method, is doubled by a case study that allows us to highlight the specific characteristics of digital globalization. Findings & Value added: The findings of the research allowed us to highlight the essential aspects of digital globalization that were perhaps exacerbated by the Covid-19 pandemic, but which contribute greatly to understanding the phenomenon of globalization. Our research also reveals four lessons learned in the COVID-19 pandemic. We also present some considerations regarding the globalization after the health crisis.

scholarly journals Significant production improvement using optimization of completion and artificial lift: case studies from South-West Iran

2020 ◽  
Author(s):  
Rahman Ashena ◽  
Mahmood Bataee ◽  
Hamed Jafarpour ◽  
Hamid Abbasi ◽  
Anatoly Zolotukhin ◽  
...  
Keyword(s):  
Case Studies ◽  
Gas Injection ◽  
Field Tests ◽  
Production Optimization ◽  
South West ◽  
Artificial Lift ◽  
Production Improvement ◽  
Artificial Gas Lift ◽  
Gas Lift ◽  
Standard Gas

AbstractProductivity of wells in South-West Iran has decreased due to completion and production problems in recent decades. This is a large risk against sustainable production from the fields. To allow stable production, an important measure is completion and production optimization including artificial lift methods. This was investigated using simulations validated by pilot field tests. Several case studies were considered in terms of their completion and production. Five scenarios were investigated: natural production through annulus and tubing (scenario-1 and 2), artificial gas lift production through annulus (scenario-3), through tubing using non-standard gas lift (scenario-4) and using standard gas lift (scenario-5). Scenario-1 is currently the case in most wells of the field. To find the optimal scenario and completion/production parameters, simulations of 11 wells of an oilfield in the region were carried out using nodal and sensitivity analysis. The optimized parameters include wellhead pressures (WHPs), tubing dimensions, maximum tolerable water cuts and gas oil ratios and artificial gas injection rate. Simulation results were validated by pilot field tests. In addition, appropriately selected wellhead and Christmas trees for all scenarios were depicted. Simulations confirmed by field pilot tests showed that optimization of completion and production mode and parameters can contribute largely to production improvement. The results showed that the current scenario-1 is the worst of all. However, production through tubing (scenario-2) is optimal for wells which can produce with natural reservoir pressure, with an increase of 800 STB/Day rate per well compared with scenario-1. However, for wells requiring artificial gas lift, the average production rate increase (per well) from the annulus to tubing production was 1185 STB/Day. Next, using the standard gas lift (scenario-5) was found to be the optimal mode of gas lifting and is strongly recommended. WHPs in scenario-5 were the greatest of all, whereas scenario-1 gave the lowest WHPs. The optimal tubing diameter and length were determined. The greatest maximum tolerable water cut was obtained using scenario-5, whereas the lowest was with scenario-1. The maximum tolerable GOR was around 1900 scf/STB. Changing of scenarios did not have significant effect on maximum tolerable GOR. The optimal artificial gas injection rates were found. This validated simulation work proved that completion and production optimization of mode and parameters had considerable contribution to production improvement in South-West Iran. This sequential comprehensive work can be applied in any other field or region.

scholarly journals Shell U.K. Exploration and Productions Experience With Large Gas Injection Compressors on the Northern North Sea Platforms

1981 ◽  
Author(s):  
J. Suyderhouds
Keyword(s):  
North Sea ◽  
Gas Injection ◽  
Lessons Learned ◽  
Design Stage ◽  
Offshore Platforms ◽  
Northern North Sea

This report highlights many difficulties, covering a period of two years, of gas compressor commissioning in the Brent Field. It is intended to give an insight of the problems encountered, with the objective to, wherever possible, avoid repetition. It is in most cases the DESIGN STAGE, where the lessons learned should be implemented, because it is very often too difficult and sometimes impossible to make improvements in compressor modules of offshore platforms.

Real-Time Gas Lift Well Optimization Using Surface Read Out (SRO) System in Bunyu Field

2021 ◽  
Author(s):  
C. F. Amiin
Keyword(s):  
Real Time ◽  
Gas Injection ◽  
Injection Rate ◽  
Performance Model ◽  
Rate Variation ◽  
Production Test ◽  
Total Production ◽  
Well Performance ◽  
Production Forecast ◽  
Gas Lift

Gas lift optimization is required to sustain production in Bunyu Field. There are 35 gas lifted wells from total of 61 production wells, which contribute to2916 BOPD from the total production of 6000 BOPD or around 49% of the total production. The performance of these wells are pivotal to ensure production target is achieved. An optimum gas injection rate in each well is essential to maximize the oil production by reducing the Flowing Bottom Hole Pressure (FBHP). Previously, a conventional downhole Pressure – Temperature (P-T) gauge was used to record well response to gas lift injection rate variation to determine the optimum point. However, this method is considered time consuming since the adjustment to determine the optimum gas injection rate can only be done after the data has been downloaded and being analyzed . Thus, the measurement program should be repeated several times until the optimum gas injection rate is determined. This paper presents an approach to optimize the production of gas lifted well by selecting the optimum gas injection rate using a real-time downhole data monitoring system, called Surface Read Out (SRO). This system is used to evaluate the changes in the downhole pressure and temperature in a real-time. When the downhole P-T gauge reaches the perforation depth, a Multi-Rate Test (MRT) is carried out with variation in gas injection rate to find the optimum rate. Optimum gas injection rate is then determined based on the lowest FBHP observed and the highest production test result during the MRT. This optimization method has been proven effective to quickly increasing well production because gas injection rate adjustment can be done during the measurement program based on the real-time analysis. In addition, calibration of well performance model based on the actual Gas Lift Performance Curve (GLPC) of the MRT result can provide more accurate production forecast.

Managing the Impact of in Situ Fines Migration in Production Optimization – A Case History from a Niger Delta Field

2021 ◽  
Author(s):  
Tamunomiete Oruambo ◽  
Elias Arochukwu ◽  
Felix Okoro ◽  
Linda Dennar ◽  
Olalekan Otubu
Keyword(s):  
Oil And Gas ◽  
Production Optimization ◽  
Volume Estimation ◽  
Fines Migration ◽  
Matrix Acidizing ◽  
The Right ◽  
The Impact ◽  
Additional Stimulation ◽  
Gas Lift

Abstract In the oil and gas business, a key strategy of well management is the deployment of the right tools and knowledge to enable continuous and optimized production. One of such tools is Matrix acidizing - A stimulation activity designed to remove wellbore damage and improve well inflow. The ability to sustain optimal production from most wells after acidization is often hampered with further fines migration problems and this requires specialized treatment to mitigate. WELL-001 quit production and was re-entered for a workover in 2018, to recomplete shallower on the same reservoir sand and restore production, however, post workover and subsequent clean up, the well failed to sustain flow. Two additional stimulation operations were also unsuccessful despite gas lift assistance. An Integrated review was held which identified key damage mechanisms impeding flow; deep fines migration which are not well handled by conventional stimulation recipes, emulsion and impairment from Loss Circulation Material (CaCO3 + XCD Polymer). A Novel solution was identified which included an Ultra-Thin Tackifying Agent (UTTA) as part of the stimulation cocktail with the primary purpose of stabilizing the fines at source and preventing further migration with the flowing fluids. The treatment was deployed successfully and the well lifted immediately, achieving a rate of 800 bopd vs a planned potential of 650 bopd. The impact of this success is not only evident in production but also in resource volume estimation and booking.

scholarly journals A decade of the Clinical Trials Transformation Initiative: What have we accomplished? What have we learned?

2018 ◽  
Vol 15 (1_suppl) ◽  
pp. 5-12 ◽  
Author(s):  
P Tenaerts ◽  
L Madre ◽  
M Landray
Keyword(s):  
Clinical Trials ◽  
Best Practices ◽  
Value Added ◽  
Project Selection ◽  
Project Team ◽  
Lessons Learned ◽  
Advanced Planning ◽  
Critical Issues ◽  
Multi Stakeholder ◽  
The Impact

The Clinical Trials Transformation Initiative reflects on 10 years of working to improve the quality and efficiency of clinical trials. This article highlights many of the Clinical Trials Transformation Initiative’s accomplishments and offers examples of the impact that the Clinical Trials Transformation Initiative has had on the clinical trials enterprise. After conducting more than 25 projects and issuing recommendations for specific strategies to improve the design and execution of clinical trials, some common themes and lessons learned have emerged. Lessons include the importance of engaging many stakeholders, advanced planning to address critical issues, discontinuation of non-value added practices, and new opportunities presented by technology. Through its work, the Clinical Trials Transformation Initiative has also derived some operational best practices for conducting collaborative, multi-stakeholder projects covering project selection, project team dynamics and execution, and multi-stakeholder meetings and team discussions. Through these initiatives, the Clinical Trials Transformation Initiative has helped move the needle toward needed change in the clinical trials enterprise that has directly impacted stakeholders and patients alike.

Machine-Learning Techniques Assist Data-Driven Well-Performance Optimization

2021 ◽  
Vol 73 (10) ◽  
pp. 63-64
Author(s):  
Chris Carpenter
Keyword(s):  
Machine Learning ◽  
Real Time ◽  
Performance Optimization ◽  
Production Optimization ◽  
Data Driven ◽  
Machine Learning Techniques ◽  
Well Performance ◽  
Learning Techniques ◽  
Expected Performance ◽  
Gas Lift

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 201696, “Robust Data-Driven Well-Performance Optimization Assisted by Machine-Learning Techniques for Natural-Flowing and Gas-Lift Wells in Abu Dhabi,” by Iman Al Selaiti, Carlos Mata, SPE, and Luigi Saputelli, SPE, ADNOC, et al., prepared for the 2020 SPE Annual Technical Conference and Exhibition, originally scheduled to be held in Denver, Colorado, 5–7 October. The paper has not been peer reviewed. Despite being proven to be a cost-effective surveillance initiative, remote monitoring is still not adopted in more than 60% of oil and gas fields around the world. Understanding the value of data through machine-learning (ML) techniques is the basis for establishing a robust surveillance strategy. In the complete paper, the authors develop a data-driven approach, enabled by artificial-intelligence methodologies including ML, to find an optimal operating envelope for gas-lift wells. Real-Time Well-Performance Optimization Wellsite Measurement and Control. - Flow Tests. - Past tests include sporadic measurement of multiphase rates and the associated flowing pressure and temperature, collected at various points of the production system, from bottomhole to separator conditions. Flow tests are also known as well tests; however, the authors use the term “flow test” in this paper to avoid confusion with well testing as used in pressure transient tests, including temporary shut-in pressure buildups (for producers) and pressure falloff tests (for injectors). Normally, a well would have limited data points from the past well tests (i.e., less than 50 valid flow tests in a period of 5–10 years). This data is the basis of creating ML models. Continuous Monitoring. - Every well should have adequate instrumentation, and its supporting infrastructure should include reliable power supply, minimum latency telemetry, and desktop access to production parameters. Alignment among real-time data and relational databases is required. Remote Control and Automated Actuation. - In addition to controllable valves, every well should be enabled with actuators to control the process variables. Remote control allows the operator to make changes to the current well-site configuration. Regulatory and Supervisory Control. - The value of automated closed-loop regulatory and supervisory control is to sustain optimal production while providing high well availability. Real-Time Production Optimization. - Continuous production optimization means that expected performance is challenged frequently by updating an optimal forecast with upper-level targets and current asset status. This is achieved by applying actions that close the gap between actual and expected performance. Faster surveillance loops compare actual vs. expected performance to determine minute, hourly, and daily gaps. A slower surveillance loop updates the asset’s expected performance. Well-Management Guidelines. - These are established, known limits to address and honor restrictions such as concession-contract obligations and legal limits, optimal reservoir management, flow assurance, economics, safety, and integrity.

Design of the Greater Plutonio Riser Tower

2009 ◽  
Author(s):  
Francis Djia ◽  
Charles Zimmermann ◽  
Daniel de la Cruz ◽  
Gre´goire de Roux ◽  
Jean-Luc Legras
Keyword(s):  
Water Depth ◽  
Total Mass ◽  
Gas Injection ◽  
Water Injection ◽  
Lessons Learned ◽  
Numerical Analyses ◽  
Global Behaviour ◽  
The Core ◽  
Gas Lift

The Greater Plutonio Riser Tower is installed in Angola in a Water depth of 1310 meters (4300 feet), and gathers 11 risers (two production loops, three water injection, one gas injection and three gas lift lines) and one gas lift umbilical. The total mass of this unique riser system is more than 4000 tons. This paper aims at describing the main challenges associated to the Riser Tower design. After a description of the riser tower main elements (flexible jumpers, buoyancy tank, guiding frames welded to the core pipe, gas lift manifolds...), numerical analyses are presented (in place extreme and fatigue analyses). Assessment of the friction developed by the risers against the guiding frames and associated effects on the global behaviour of the riser tower are detailed. Various sources of conservatism, lessons learned and ways of improvements are also shared for future projects.

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