bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reviving a Complicated Idle Well: A Multi-Intervention Example from the Sultanate of Oman
Authors: Al Gheilani Hamdan , Al Sawwafi Khalid , Cruceru Dragos , Bezboruah Pearl , Charushin Anton , Al Maskari Said , Al Balushi Saja , Makawi Sami , Al Hatmi Hatem , Eltorabi Yousif 
Published: October 2022

Abstract
A well targeting deep a gas formation in the central part of the Sultanate of Oman was drilled in February 2010. At a later stage a fracturing operation was conducted but an integrity issue. This integrity issue consisted of a communication between tubing and casing annulus which led to the well having been isolated with cement plugs. This paper describes a successful work cycle of restoring well accessibility and reviving production from an idle complex well using different means of well intervention.
A Hydraulic Workover Unit attended the well to fix the integrity issue of the casing/ tubing annulus communication. An old casing was recovered and a new one installed. Next a coiled tubing unit attended the well; it encountered complicated well conditions characterized by the presence of metal junk left behind after a previous milling operation. In addition there were 3 cement plugs and 700 m of proppant which needed to be removed in order to establish access to the producing formation. We adopted an ""agile" approach and deployed a "super magnet" by slickline. Following the removal of the cement plugs we cleaned the well from proppant using coiled tubing with sand return management at surface.
The well which was originally planned to be abandoned due to the complexity of its integrity issues was successfully recovered. The integrity issue was fixed by installation of a new external casing patch using a hydraulic workover unit. The approach of using a combination of different well intervention methods enabled reviving the idle well and unlocking access to hydrocarbon reserves. Full passage to the target depth was confirmed which made the operation a full success. Challenges such as the presence of metal junk, logistics constraints to supply a large volume of water for long-interval milling and cleanout operations, management of abrasive sandy returns at surface were overcome through a collaborative approach between all parties involved.
This paper presents a case where we successfully brough back on production a well which had been shut in due to complex well integrity issues. We present the lessons learnt as many of these can be applied to other challenging projects. This show case reveals how the combination of different types of well intervention techniques can help restore production from a well with complex well integrity issues.
Integrated Absorption and Regeneration Membrane Contactor Technology for Removal of CO2 and H2S from Natural Gas
Authors: Mohd Tamidi Athirah , M Saleh Syafiqa , Quek Ven Chian , Hanafiah Mahmat Rashid 
Published: October 2022

Abstract
Regeneration of rich amine using membrane contactor (MBC) is studied with observation on factors of operating temperature, flowrate and pressure. The desorption of CO2 and H2S were analyzed, and as a result operating pressure and liquid temperature were identified as the most significant parameters affecting desorption. Higher acid gas flux was observed at higher temperature and higher flowrate. Desorption of CO2 at higher flowrate is limited by the membrane contact area; whilst H2S was more readily desorbed. The higher operating transmembrane pressure of 0.3 barg is preferred as it provided good control during regeneration operation. The optimized parameter for rich amine regeneration was determined through ANOVA analysis using DesignExpert software. The optimum condition was found to be at 90 °C and 0.3 barg; these parameters were then used for the integrated operation of the absorption and regeneration membrane contactor. Continuous integrated testing was carried out and successfully met the specification for both sections. The absorption membrane contactor was able to remove CO2 from 25% down to 6.5% and H2S from 500ppm to below 20ppm. The regeneration section maintained good desorption of H2S where the recycled amine had less than 200ppm and for CO2 desorption 0.2 mol CO2/mol amine loading was removed.
Super Wells: Disruptive Proposal for Well Production Beyond the Established Fixed Limits (Erosional / Corrosive Limits) Case Study in High Potential Wells in Abu Dhabi Field.
Authors: Almarzooqi Laila Sayed , Alqemzi Meera , Cremades Pablo , Lopez Juan Enrique , Palacios Carlos 
Published: October 2022

Abstract
Early in oil field development, it is possible to discover high-potential wells that allow "thinking outside the box." However, in adverse scenarios (presence of H2S and appearance of asphaltenes), the limits appear to be very conservative. Two of these untouchable limits are the erosive and corrosive limits of fluid velocity. In particular, the use of API 14E RP based models is very conservative because it must be used safely in a wide range of applications in producing and injection wells around the world. Even commercial Nodal Analysis ® suites for their default erosion calculations take the dimensionless C factor = 100 as a reference. The objective of this work is to show a case study in which it is determined the feasibility and theoretical limits of increase production mean model the detrimental effect of erosion and corrosion to take advantage the potential of oil-producing wells with a high productivity index (higher than 8 bpd/psi) to safely optimize your production (greater than 5,000 bpd) with low risk of erosion or corrosion over a 5-year horizon under specific conditions.
Alternative models were based on conservative values of 15 ft/s as the upper erosive limit (Zheng et al. at 2000) and 5 mpy (NACE SP0775) as the upper corrosive limit. Iterations of factor C were carried out up to 125 that allowed increasing the production rate of high potential wells above 5000 bpd. This study allowed to determine a list of candidate wells for a second analysis. This second study was more detailed and was based on an extended model (erosion/corrosion) developed by the University of Tulsa and confirmed that these wells could produce more than 5000 bpd over a period of up to 10 years with very low risk of failure due to erosion or corrosion failures.
From 40 wells of the field evaluated, it was found that of the 12 wells with high potential, 9 wells were found to be viable to produce up to 6000 bpd during the first stage (C factor up to 125). In the second stage of the process the study concluded that it was feasible to increase the production of the 9 wells even up to 7000 bpd without causing significant risks of erosion or corrosion if the water cut was kept below 10%. Field short test was carried out in three (3) wells with satisfactory results.
The application, for limited periods of time, of alternative models that allow the optimization of production of wells with high potential during the early development of large oil fields is possible. If the water cut, and solids production values remain low (water cut less than 10% and solids production less than 0.1 kg/1000 bpd and particle size between 20-50 microns).
Digitalization and Data Automation: The Path for a More Efficient Well Integrity Data Management and Cost-Effective Responses
Authors: NIZAR Mouna 
Published: October 2022

Abstract
Bridging data management gap by gathering all well integrity data in one unique data base. The aim of ADNOC Offshore in-house Well Integrity Data Management System (WIDMS) is to comply with the 3A rule: Accessibility of the data, Accuracy by performing regular quality check and Analysis. The analysis allows to maintain wells barriers robust, to ensure personnel safety and to quickly identify integrity issues to make qualified decisions about appropriate mitigations measures and avoid risk escalation. WIDMS has been developed in-house with inputs and collaboration of various stake holders. An enhancement list has been established selecting the most relevant features that will be added value to the system. Therefore, Automation for sub processes like thresholds calculations and Risk Assessment which gives input for Well Passports that contains all the required information to evaluate the well risks and implement the required mitigation measures.
End users are following a RACI Chart to keep WIDMS database on track and to ensure no data falls through the cracks as all the data workflow is defined through the different steps such as providing data, entering it in the system, informing relevant stakeholders and providing technical clarifications if needed. The result of data acquisition in WIDMS is that data flows across the entire organization, with defined access rights in line with ADNOC Offshore policies. This data is collected from various sources, is a robust data base, essential for evaluating and maintaining well integrity.
It is enhancing well barriers system management by allowing to have full overview of well's barriers performance. Moreover, it allows to have reliable and continuously available data such as annulus pressure data that is critical for well integrity assurance, to avoid the uncontrolled release of hydrocarbons to the atmosphere. Notifications have been implemented so alerts can be sent for engineers to inform about any abnormality and non-compliance. As technology evolves, using paper-based processes, excel spreadsheets, time-based equipment inspection and testing become less effective. Well diagnostics are expensive so utilizing well data analytics through this digital hub project will ease having detailed real time data and quick analysis for early detection of failures and anticipation and reduction of risk escalation.
Energy Efficiency Improvement of a Gas Compressor Through Process Parameters Adjustments
Authors: Al-Mulhim Abdulaziz A. 
Published: October 2022

Abstract
As a global leader in energy supply, Saudi Aramco spares no efforts in maintaining the global energy demand by operating major onshore and offshore oil fields. This comes while ensuring to minimize the carbon footprint that will be resulted oil production, and to maximize the value creation from the operating facilities. The production of crude oil from these oil fields will involve producing associated gas at a facility that is called Gas Oil Separation plant (GOSP) which will be handled through gas gathering trains at the Gas Oil Separation Plants (GOSPs) to accommodate this valuable by-product with the produced crude oil from the connected oil field to increase the value creation and reduce flaring of the associated gas which may negatively impact the surrounding environment which includes but not limited to impacting climate change and air pollution. This is also part of Saudi Aramco commitments toward circular economy by reducing waste the amount of waste at the oil producing facilities.
Therefore, Saudi Aramco strives to improve energy efficiency at its premises. In spite of all the exerted efforts, strict policies, challenging targets and investments to achieve a continual improvement in energy efficiency, it would be hard to avoid a performance plateau without breakthrough solutions. This is particularly true in Saudi Aramco, considering the large geographical area in which different facilities are scattered.
Energy efficiency and environmental protection are two important parameters that are interconnected, and both are critical for the quality of future generation. Effective power utilization can eventually help sustainability and circular economy.
AutoBoost and Gas Lift System
Authors: Hadim Ammar , Kaci Yacine , Rahal Mohammed Lakhdar , Elfateh Sebaa Mohamed , Okba Mohammed Nadjib , Lachteg Mohamed , Allal Abdelhalim , Kasmiouri Mahmoud , Belbari Lahouari , Zeghdoud Aziz , Benie Christopher , Abdellah Mehdi 
Published: October 2022

Abstract
This paper will describe a new surface boosting system AutoBooST® used as an artificial lift, it can be defined also as a surface auto gas lift system, fully automated and self-powered with real time monitoring and optimization of well production. Sonatrach and Expro Gulf with its partner Innovative Production Services (IPS) have introduced this technology in Hassi Messaoud field to increase oil production from the low wellhead pressure wells located away from the central facility where gas lift network is already deployed, as well as the remote fields.
AutoBooST® operating principle is to separate the oil, water and gas at well level and re inject the separated gas into the well hence it is a system using the well associated gas as a gas lift and fuel gas of the unit which makes the unit fully autonomous with no external gas source nor energy requirement as the unit generates the necessary power to run all the utilities. Produced gas is recycled in a closed loop, therefore gas will be accumulated along with the operation and provides a wide range of gas rate to perform optimization of the gas lift injection parameters versus the produced oil. During the optimization or once optimum rate is set the excess of gas is diverted to the export line via an automated control valve.
For down hole part, two options were used for the gas injection point either down hole circulating device SSD or SPM to allow gas lift injection from annulus to production tubing_ unloading valves are not required since compressor discharge pressure can reach 160 bars_ or run concentric tubing 1.66 inside the production tubing as velocity string.
AutoBooST® application was very successful and gave an increase of production from 50% to 150%, particularly at well HMD-A with an increase from 2m3/h (301 bpd) @ Qginj = 0m3/d to 11 m3/h (1658bpd) @ Qginj = 23000 m3/d during the optimization phase then the well was set to produce at 6 m3/h (904 bpd) considering reservoir management aspects.
As in conventional gas lift the production increase depends mainly on the well and reservoir parameters hence candidate well selection is the key factor. AutoBooST® application was already extended to target two to three wells with one package knowing that a current unit max compression capacity is 25000 to 40000 m3/d which is prone to improvement, however it is possible to use several units at manifold level to cover a large number of wells which will make a remote mini gas lift station.
AutoBooST® is proven successful technology; it is an ideal solution for remote wells and fields. In addition to the production application it can be used to evaluate the gas lift conventional project prior to major investment decision.
Use of Virtual Metering to Maximize Water Injection Efficiency in an Offshore Field Abu Dhabi
Authors: Salimov Rail , Jaffres Benoit , Alblooshi Jamal , Sarsekov Arlen 
Published: October 2022

Abstract
In offshore field due to pessimistic design in one of the field, water injection flowmeters are not capable to measure full potential injection rates. Highly precise Virtual Metering methodology was developed in-house to estimate rates real-time using advanced analytics and machine learning algorithms. Main application of developed virtual meters are improvement in water injection allocation and Injectivity Index monitoring. For Injectivity Index monitoring a comprehensive methodology was developed to minimize uncertainties such as reservoir pressure and friction forces.
Virtual metering algorithms are based on choke position and pressure loss across the choke (Injection Header Pressure – Well Head Pressure). For all choke sizes with available data a quadratic regression (dP = A*Q^2+B) is fitted to observed data.
For intermediate choke position a polynomial is used to estimate "A" coefficient for any choke position. In case when no data is available to calibrate choke curves, additional step is introduced: total well head tower rate is estimated based on pressure loss between the wellhead towers.
Developed algorithms showed very high precision and accuracy. Backtested algorithm showed &lt; 2.5 % error between estimated and measured rates. Developed Virtual Meter was main enabler for injecting at full capacity without limiting injection rates which had positive impact on field injection and production potential. Practical application of VM are rates allocation as well as injectivity index estimation. Injectivity index calculation methodology discussed in the paper takes into account transient and interference effect by building numerical model in well test interpretation software. Friction forces in the tubing are estimated with prosper model or pressure drop at the beginning of any PFO. Matched tubing friction curve will be used for continuous BHP calculation and precise II estimation. Transient II estimation is very important to understand injectivity index evolution and prompt any injectivity restoration actions if necessary.
Such Virtual Meters are novel in ADNOC group as discussed field is one of the first pilot green fields with available real-time data. Virtual Meters have zero CAPEX and OPEX as only existing hardware and software is used. Developed Algorithms can be upscaled in any asset as proven to be as a success story in discussed field in Offshore Abu Dhabi. All developed algorithms are embedded in commercial real-time monitoring systems and used for daily monitoring.
Advanced Vibration Analysis and Remnant Life Assessment to Maximize Plant Production Rates
Authors: Al Khoujah Khaled , Medina Antonio , Al Qaydi Juma , Al Mansoori Fatima , Frost Liam , McIlwraith Colin , Kaleem Daniyal 
Published: October 2022

Abstract
Oil and Gas facilities are often designed with production capacity margins of 10%-20% to allow for future expansions or modification on the facilities. Similarly, ADNOC Sour Gas has carried out a study to explore production expansion opportunities utilizing the existing facilities. The study included process and mechanical adequacy.
The study showed a limitation on one of the vessels due to dynamic stresses on various weld locations that had a history of failure, and accordingly, ADNOC Sour Gas conducted a measurement based dynamic stress assessment of the welded locations across 4 units. The study has recommended repair and modification work on various locations to ensure safe production increase.
ADNOC Sour Gas has successfully completed the verification and health check of the welds located on various piping and vessels that were limiting production capacity due to risk of various critical weld fatigue cracking and failure. A fatigue life assessment was conducted in-order to ensure safe and sustainable production and to explore the opportunity of a possible marginal production increase. This paper presents the detailed testing and simulation methodology including all technical specifications.
Un-Realize Application of LWD Multipole Sonic Tool for Evaluating Cement Quality: Optimizing the Well Operation in a Highly Deviated North Kuwait Deep Jurassic Well Case Study
Authors: Al-Mutawa Majdi , Saffar Ali Hussein , Al-Azmi Mejbel Saad , Al-Otaibi Fahad Barrak , Abdulmohsen Naser Bader , Ragaey Mohsen Mohammed , Kumar Joshi Girija , Alomar Abdulrahman Ahmad , Tiwary Devendra Nath , Pasaribu Ihsan Taufik , Al-Bannai Khaled , Kho Djisan 
Published: October 2022

Abstract
Cement quality is an important well integrity consideration to ensure proper hydraulic sealing. Traditionally, wireline cement bond logs have been used extensively in the Jurassic formation of North Kuwait. The case study well presented in this paper had an 80° inclination and 3,000 ft of a 6-in. open hole, which has remained opened for quite some time. Cement evaluation was required inside the 7 5/8-in liner to determine the cement quality behind the liner and integrity of liner shoe. This information is important for achieving a successful of multistage completion for the producing interval in the 6-in open hole.
The target interval had a vertical depth greater than 14,000ft from mean-sea level with a well deviation more than 80°. Four operational days were required to run drill pipe conveyance of conventional cement evaluation wireline tools. This operation would have exposed the 2,500ft of open hole to potentially collapsing situation due to the time dependence of the wellbore stability.
The capability of logging-while-drilling (LWD) multipole sonic tool for evaluating the cement quality was considered, as there was plan to acquire open hole log data using LWD technology, which included the LWD multipole sonic tool. While running in the hole to the open hole section, the LWD multipole sonic tool can acquire sonic-based cement evaluation data inside of the 7 5/8-in liner. This operating method consumes no rig time while obtaining the well integrity information.
This paper presents the case study, along with the LWD multipole sonic tool theory for measuring cement bond quality index, operation preparation, and the results of the data acquisition.
Innovative Approach to Maximize NGL Recovery Utilizing Process Modeling in Midstream Operations
Authors: Bu Ali Ahmed Khalid , Almusaiteer Mohammed Khalid , Sharaf Abdulaziz Saleh 
Published: October 2022

Abstract
The aim of this paper is to showcase successful operations of maximizing C2+ Natural Gas Liquids (NGL) recovery in a midstream NGL Recovery Plant utilizing process modeling and simulation.
Gas Treating Trains in Plant-A are designed to remove the CO2 from the sour feed gas using Di-Glycol Amine (DGA) and route the sweet gas to the NGL Recovery trains. To maximize the NGL recovery in Plant A, process modeling and simulation, using ProMax software, was utilized to identify any limitations in the Gas Treating trains and examine the possibility of processing higher feed gas than the design capacity. Main hydraulic parameters in the DGA absorber and regenerator were confirmed to be within the acceptable limit to handle additional amount of gas calculated from the simulation. A detailed procedure was prepared to process higher feed gas in the Gas Treating trains.
Processing higher feed gas at the Gas Treating trains has resulted in increasing the sweet gas production by 7% which was processed smoothly at the Gas Treating trains without abnormalities. Process parameters were closely monitored to ensure a safe and reliable operation. On-spec sweet gas was delivered which was verified by collecting gas samples and by monitoring the sweet gas CO2 online analyzer. In addition, no foaming symptoms were observed during processing the additional gas. The lean DGA and rich DGA velocities were below the maximum. The by-products of the DGA-sour gas reaction were maintained within the acceptable range which indicates that the reclaimer is functioning properly. Moreover, the lean DGA loading was acceptable and within the specification which is an indication of the DGA regenerator efficient operation. After completing all the required procedures and tests, it was concluded that the Gas Treating trains are able to process additional gas without adding any new equipment or modifying existing ones.
The success of maximizing the NGL recovery in Plant-A opens a new frontier for the oil and gas industry to boost the hydrocarbon production and create growth with the value-added of C2+ NGL capitalizing on the hydrocarbon value chain. An innovative approach that combines process simulation with actual implementation in the plant led to higher revenues with no capital expenditure.