bluuebunny/crossref_metadata_2025_split huggingface dataset:
Implementation First of a Kind Edge Computing Solution to Increase Production and Reduce Emissions at Bakken and Permian Unconventional Basins
Authors: Baaren S. G. , Sharma R. R. 
Published: October 2023

Abstract
There is a need to reduce carbon emissions sources at production facilities, which can be addressed by employing a digital solution that optimizes the facility's operational set-points in real-time. A novel software solution was developed which can operate on a cost-effective controller at a facility. The software uses many process variables already monitored at a facility to accurately model variables that are not measured, such as the Reid Vapor Pressure (RVP). The software also computes optimized set points, such as the minimum oil temperature required to meet the RVP of the final product.
The novel digital system was installed at one facility in the Bakken and two facilities in the Permian. At the first facility (Bakken), the temperature was optimized using an air cooler. At the second and third facilities in the Permian, the temperature was optimized using heaters. The temperature was optimized to minimize emissions and maximize oil shrinkage whilst ensuring that the RVP would not exceed a specified value required for custody transfer.
It was found that the initial model needed calibration at all three sites. The model was calibrated using oil samples that were processed with an analyzer. The calibration method applied was API MPMS 4.2 Appendix C, whereafter the RVP predictions consistently were within a ± 0.5 psi delta compared to values measured with a sample analyzer.
Once the system successfully optimized the oil temperature in the Bakken, the tank vapor combustion and oil shrinkage reduced by 40% and 0.7%, respectively. The oil temperature was successfully optimized using the heater at the second facility (Permian West), resulting in a 72% reduction of heater emissions, 28% reduction of tank vapor combustion and 0.5% reduction of oil shrinkage. At the third facility (Permian East), heater emissions were reduced by 77%, tank vapor combustion reduced with 40% and oil shrinkage reduced by 1.7%.
The field trials prove that the system can be implemented successfully without cyber-security issues. The relatively low implementation cost combined with reduced oil shrinkage results in an attractive return on investment and a negative cost of carbon abatement. In other words, implementing the system is profitable whilst carbon emissions are reduced at the same time, yielding an attractive business case.
Addressing Asset Integrity, Strongly Emphasizing Energy Efficiency & Sustainability
Authors: Awadhi Ibrahim Al , Sharma Ashok , Subramaniam Krishnan 
Published: October 2023

Abstract

Objective/Scope (25 – 75 word)
Existing Fired heaters in Ruwais Train-1/2 are designed and constructed in 1980 and are currently running with low efficiency of ~76%. In addition, fin burning is observed, due to high fin temperature which impairs heaters performance and necessitates replacement. This paper portrays the specific engineering way adopted to revive the performance, improve efficiency & enhance integrity of the existing 40 years old fired heaters.

Methods, Procedures, Process (75 – 100 word)
Replacing convection section was identified as opportunity to improve & maximize value. Adopting systematic engineering approach, three options (identical, full and partial replacement) were evaluated and best option with maximum benefit was selected as below. Improved tube fin density: Optimum selection of fin density is very crucial not to increase the heater draft at the same time to obtain maximum heat recovery.Enhanced fin material: Existing tube / fins are replaced with CS tubes & 11/13 Cr fins to sustain high temperature & avoid fin burning.Install future tube rows: 2 future tube row space were installed with fin tubes, enhancing heat recovery and reducing flue gas temperature.

Results, Observations & Conclusions (100 – 200 words)
Thermal design of the heaters confirmed that following enhancements could be realized upon existing heaters upgrade. Support Sustainability by reduction in fuel gas consumption and flue gas emissions by 8 to 10%Efficiency increases as below. Heaters 1 A & B - Increase from 76.4 to 86.1%Heaters 2 A & B - increase from 77 to 86%Heaters 3 A & B - Increase from 73 to 84 %Flue gas temperature leaving the convection section drops down from 460 to 263OC in heater 1 & 527 to 300OC in heater 2.Estimated Reduction in CO2 emission is ~ 54,000 MT/year.Integrity: Enhance integrity and service life of convection section by use of improved convection section tube material and improved tube fin material 11/13 Cr for selected rows.Foundation: No impact on foundation as increase in weight of the heater &lt;1%Performance: Proposed new convection section design enables the furnace to be operated at its design duty by avoiding burning of fins with use of enhance fin material.Profitability: Cost savings of USD 39.5M for a design life of 15 years for 4 heaters due to reduction in fuel gas

Novel/Additive Information (25 – 75 words)
Strengthening the aging facilities is crucial to ensure its integrity, life extension and facility performance. However, the benefits are doubled when the asset life extension actions are resulting in enhancement of efficiency, performance & cost saving for the extended life.
Asset life extension can earn to operating companies, when escorted with smart enhancements supported by latest technics and careful selections.
Overcome Parted Sucker Rod in Artificial Lift Sucker Rod Pump Without Fishing Operation in Pendopo Oil Field
Authors: Arifien R Nova Rifika , Putra Mario Aditya Haris , Rasyid Muhammad , Kuncoro Anang Arie , _ Sucipto , Khair Utuh 
Published: October 2023

Abstract
Sucker rod pumping systems are widely used in oil wells. The frequent issue of sucker rod pump is parted sucker rod while operated due to lifetime and workload. Parted sucker rod causes pump off, the pump unable to lift the liquid from the subsurface to the surface, hence causing loss of production. The fishing tool that commonly used to catch the sucker rod fish is overshot or mousetrap. Fishing operation causes rig cost and operating time increase. This paper presents a solution in the operation of reproducing wells with parted sucker rod problem without having to do fishing job.
Using parts from sucker rod pumps designed and modified to overcome the problem of catching and connecting parted SR bodies of various sizes, without having to pull out the sucker rod string and replace parted sucker rod or fishing job. This tool has a different catching design compared to the existing tools, such as overshot. The dies are designed to increase flexibility during engaging operation, therefore there is no require to change the dies to catch multiple size of fish.
This innovation succeeded in accelerating and increasing the effectiveness of well services operation because without having to do fishing job, resulting in reducing non-productive time and costs. This tool has been used at the Pendopo Field, South Sumatra, Indonesia since the end of 2021 until now, for example in West Benakat Structure with 286 Days (27 March 2023) the well is still producing. The benefits obtained from this tool lead to efficiency in well services operations are saving rig operating costs for well maintenance of USD 20,000 per well, saving rig operating costs and reducing lost production opportunities of more than USD 212,000 during 2022, as well as reducing the potential for work accidents
Case Study of Multilaterals Drilling in Under-Balanced Coiled Tubing Drilling (UBCTD) Implementation and Challenges for the First Time in Operator Group of Companies
Authors: Osama Mohamed , Sumaida Ali Sulaiman Bin , El Shahat Ayman , Al Mutawa Ahmed , Almazrouei Saeed , Saleh Abdalla , Yousfi Fawad Zain , Almteiri Nama Ali , Baslaib Mohamed , Mantilla Alfonso , Deshmukh Rohit V. , Solaiman Tarek , Abdulsallam Fouad , Ladmia Abdelhak , Rangel Pedro , Rennox John , Cui Shuai , Jumagaliyev Yerlan , Basha Maged 
Published: October 2023

Abstract
Under Balanced Coiled Tubing Drilling technologies is well proven technology that has been piloted for the first time in OPERATOR for Gas sour Reservoirs this being the first time in the OPERATOR Group of Companies, (UBCTD) technology has proven to be able to enhance the production rate greatly compare with conventional overbalanced technique. However, the UBCTD technology has a limit on the lateral length due to buckling and lock up of the coiled-tubing string. Multilateral drilling can overcome this limit and allow wells drilled by UBCTD technology have a comparable total lateral length with the conventional ERD wells.
Detailed planning was carried out for the technology implementation there were many challenges in the operations, nevertheless, this is the first project of it is kind on the company, the lessons gained from daily challenging operation considered the stepping stone of the technology implementation in Abu Dhabi.
This paper shall spotlight on the project challenges and learnings gained from well to another and how it helps to improve the well performance.
The technique for multilateral drilling is characterized according to definitions established in 1997 during the Technology Advancement of Multilaterals (TAML) Forum held in Aberdeen. These standards classify junctions as TAML Level 1, 2, 3, 4, 5, or 6 based on mechanical complexity, connectivity, and hydraulic isolation. In UBCTD wells, the most common multilateral technology is with TAML level 1, which is done by open-hole sidetracks with barefoot completion.
Plan set to perform the two open hole sidetracks from the main lateral hole to examine the UBCTD multilateral design philosophy for the first time using UBCTD technology and drill a multilateral well with 3 laterals, each of the lateral lengths around 4,000 ft. Comprehensive planning and simulations were done to overcome the challenge of different reservoir pressure, wellbore instability and open-hole sidetrack operations. The sidetrack and multilateral well were proved to be successful with flawless drilling without any NPT and greatly enhanced production of the well.
No doubt that coiled tubing under the balanced technology pilot was extremely successful in all aspects, the paper shall describe all challenges and mitigations in addition spotlight on the best practice of planning and drilling a multilateral well in UBCTD during the execution phase and how it is impacted on project wells delivery. Body text 2 paragraphs.
Rapid Digital Oilfield Transformation Using Edge Computing and AI
Authors: Shukla S. , Hassan K. , Elsiwi A. , Bosnina S. , Saeed N. , Fannir J. , El-meshri A. , Gamberrato A. , Haddad J. 
Published: October 2023

Abstract
The timing and quality of operational decisions are critical factor in preventing production shortfalls and ensure sustained high level of operational efficiency. This impact of these factors amplifies multiple folds if the operations are in remote fields. Edge computing applications have surfaced as a powerful tool to ensure the right decisions are taken at the right time and by the right people. The paper describes multiple innovative and novel applications of edge computing and machine learning deployed in a remote field with no connectivity to enable peak well and network performance by efficiency improvement of artificial lift system, accurate virtual flow metering, minimize HSE exposure and simultaneously reduce the carbon footprint of the operation.
New wells have been drilled in the green field located in western part of Libya. The field is a remote area with no digital connectivity yet and some of the wells require ESP to sustain production. The remoteness of the field also caused potential asset security concerns for the generators and ESP surface system (VSD).
A holistic production performance enhancement digital solution package including sensors, solar power and satellite connectivity was deployed in the field centered around an edge computing platform to develop a digital twin of the green field with multiple wells. Virtual flow metering was done for all the wells using different techniques depending on the well architecture. Well models were run on the edge for wells with ESPs to estimate flow rates in realtime, while robust choke models based on well head and line pressure data were used to derive highly accurate well flowrates. The edge computing device was connected to ESP and the data gathered was analyzed in real time at the edge to identify ESP underperformance and detect any anomalies. At the same time machine learned algorithm continuously analyzed the video captured by two strategically positioned cameras to detect any potential intrusion by person or vehicles.
It is estimated that apart from the significant production performance gain the solution has reduced 16 metric ton of carbon footprint on an annual basis associated with this operation.
The solution allowed for rapid digitization of the field and early realization of value at a relatively much lower capex investment than traditional digital oil field solutions with an opex based model.
Towards Greener Hvac Refrigerant Usage For Offshore and Onshore Facilities -Petronas Journey in Managing Refrigerant in its Production Facilities
Authors: Basri H , Ekhwan A 
Published: October 2023

Abstract
Petronas currently operate 3,226 units of HVAC system to support its production facilities for its Upstream facilities. The HVAC systems are used to provide the required ventilation for shelters during emergency situations, ensuring required humidity for climate control for sensitive electronic equipment, and provide cooling for human comfort. Out of the 3,226 units currently under Petronas Upstream, 915 units are with R22 refrigerant, while the rest are a mixture of other refrigerants such as R134a and R407c. This paper explains about Petronas’ strategy in managing its refrigerant changeout program, to comply with Kigali Amendment to Montreal Protocol, to gradually reduce the consumption and production of hydrochlorofluorocarbons (HCFCs), moving to a more environmentally friendly refrigerants such as Hydrofluorocarbons (HFCs). This is to be achieved and tracked by developing a 10-year road map, from 2020 to 2030, to clearly indicate to stakeholders on key milestones for this initiative. Appropriate Key Performance Indicators have been developed to ensure key activities are tracked and monitored. 3 main methods to achieve the goal of 100% elimination of HCFC usafe in Petronas Upstream facilities are;
Situational Assessment of HVAC inventories in Petronas facilities, focusing on units with HCFC Execution of identified action items including refrigerant retrofit guideline, changeout strategy and manpower competency program Continuous tracking, monitoring and improvement of the action items
Key action items identified and included in the 10 years road-map are
Refurbishment and rejuvenation of old HVAC units from HCFC to HFC Retrofitting suitable HVAC units HCFC to HFC Stocking up of R22 (HCFC) refrigerants to ensure uninterrupted operations.
These 3 key action items are critical to ensure Petronas able to optimize cost as well as complying to the plans that was made. Beyond 2030, Petronas is looking for alternative refrigerants such as hydrofluoroolefin, which have a lesser Ozone Depletion Potential (ODP), and Global Warming Potential (GWP). This however, may require higher Capital Expenditure (CAPEX) investments, as well as adjustments to Operational Expenditure (OPEX)
Leveraging Real Time Operational Data to Reduce Greenhouse Gas Emissions
Authors: Guzman Juan Sebastian , Fuenmayor-Gonzalez Douglas , Turrel Benjamin , Dauce Lucas 
Published: October 2023

Abstract
This paper aims to share the journey of Carbon Footprint reduction in Exploration and Production (E&P) in reducing carbon emissions on operated assets through the implementation of a Real-Time tool for Monitoring Green House Gases (GHG) Emissions and Energy Efficiency (EE). The objectives are to improve the processes efficiencies, track and aid to reduce the total emissions. The solution was designed to monitor GHG key sources using available real time data within facilities. It starts by tracking emissions coming from energy usage through fuel gas combustion and then addresses emissions resulting from energy loss, such as flaring, venting and liquid fuels. The tool has been successfully deployed across 34 operated sites, allowing the tracking of approximately 85% of GHG emissions from Scope 1 & 2 within the E&P Operated Assets’ perimeter.
The implemented solution follows a highly standardized and scalable approach. A model is built once and then applied to hundreds of equipment and assets. Once deployed, the model continuously provides real-time data derived from calculations, analyses, and Key Performance Indicator (KPIs). These products increase operational efficiency and help decision-making process regarding emissions reduction. Additionally, transparency and traceability are ensured by granting users access to all data and calculation.
The tool uses different inputs such as fluid composition, process design data and operating parameters. It delivers a comprehensive overview of emissions and performance, ranging from individual equipment to site and country levels. The solution also eases benchmarking carbon footprint in different systems and identifies corrective and mitigation actions for both design and operational philosophy. Furthermore, it allows to establish a relationship between GHG and Energy efficiency based on potential optimization to be carried-out on significant energy users.
Headquarters and operating centers consistently rely on the solution's displays, which present performance indicators for daily discussions and used in operational decision-making. This solution enables operators to identify poorly performing equipment and capture undesired process deviations as well as metering inaccuracies that contribute to GHG emissions. As a result, these indicators improve operational excellence and revenues, while minimizing the environmental impact of our activities.
The paper discusses the implementation process, highlights the capabilities of the digital tool, and demonstrates its value through use cases where a positive impact both GHG reduction and improved energy efficiency was measured. By leveraging existing resources and valorizing field data and software, we have successfully transformed our operational practices and brought them to higher standards in terms of environmental performance and lower carbon intensity.
An Alternative Coiled Tubing Solution to Access Isolated Reserves Below Two Ball Valves in the Columbus Basin of Trinidad & Tobago
Authors: Mammadli R. , Adilov R. , Ramkissoon A. , Hosein N. , Friedli J. , Holder D. 
Published: October 2023

Abstract
The Well A in the Columbus basin of Trinidad & Tobago was completed with a dual selective Cased Hole Gravel Pack. The completion included two ball valves and multiple sliding sleeves to isolate zone A from zone B. At the end of the completion phase, multiple wireline attempts were made to shift open the two ball valves without success. The well was put on production from the upper Zone A only while lower Zone B was isolated with two closed ball valves. This scope was to open the two ball valves to regain access to the reserves in Zone B and to isolate Zone A by closing the sliding sleeves.
After numerous wireline attempts to gain access to Zone A via electricline clean out, shifting, and milling tools, coil tubing was selected as an alternate conveyance method to shift close sliding sleeves and open both ball valves. The attempt to close the sliding sleeve and shift open the ball valve with coiled tubing was unsuccessful. The decision was to mill the ball valve with differential pressure creating upward force on milling BHA when milling the ball valves.
The initial attempt to close the sliding sleeves with coiled tubing was unsuccessful with one sleeve remaining in communication with Zone A. The top ball valve was milled successfully with a 2.65" tapered bit in ∼4.5 hrs and drifted successfully multiple times using the same toolstring. Pressure behavior confirmed that the bottom ball valve remained fully closed. A 2.5" bit was then run and milled on for ∼8 hrs. with no further progress. A second run was made with a new tapered 2.5" bit and successfully gained access to Zone B. The size of the milled hole estimated on the bottom valve was 1.76". Analysis revealed that the 1.76" restriction at the bottom valve would allow the well to produce at its full well capacity. After successfully gaining access to Zone B, the open sliding sleeve in Zone A was isolated with a straddle packer.
The unique achievement was to mill two closed ball valves as part of a single operation. Being unable to shift close a Zone A sliding sleeve created cross-flow conditions in the well throughout the milling of the bottom ball valve. This introduced challenges to run through the milled top ball valve and progress the milling of the second ball valve with differential pressure. As a result, the second ball valve was milled partially, and the straddle packer was installed across the Zone A leaking sliding sleeve with the cross flow. Therefore, this job was a unique experience in the field that had important leanings that are applicable across the industry.
From Field Trial to Full-Scale Deployment of Pulse Waterflooding on Mature Oil Fields. Incremental Oil at No Cost
Authors: Adil Mukanov 
Published: October 2023

Abstract
Pulse or cyclic waterflooding is a well-known technique to optimize water injection schematics, that requires virtually neither capital nor operational expenditures. Therefore, it is very attractive for marginally mature oil fields to stabilize and even boost oil production with the aim of improving economics. So, the paper demonstrates successful case studies from the South-Turgai Basin in Kazakhstan.
Pulse waterflooding was implemented by increasing the injection volumes of one group of injectors and choking or shutting down another, thereby, sending periodic pulses in a sandstone formation. The pulses created translate into a fast pressure drop in high permeability and a slow pressure drop in low layers, causing a pressure differential and fluid crossflow. So, it was designed for stratified heterogeneous reservoirs, where we couldn't properly displace oil from poor zones. The theory was put into practice in the KK field trial area, and unexpectedly, we achieved profound improvements in production performance. Thus, the next step was to upscale the activity on other sites.
As a result of the first trial, more than 150 Mbbl of oil increment was obtained. That was promising, and the second field went through the same procedure. Pulse waterflooding was applied to the north and south parts, divided by the extensive gas cap of the A field. Most producers in both parts exhibit a clear trend of not only stabilization but also gradual growth. That was mainly reached due to an increase in fluid rates and no changes or event reduction in watercut. Previously, the average oil rate in the south had steadily declined at a 26% annual rate, but after that, it increased for the first time in 10 years. A similar picture is observed in the north, where a 22% annual decline turned into a rate stabilization and then increase. Eventually, the total oil increment is 21 400 tons or 166 Mbbl.
Pulse waterflooding proved to be an efficient EOR technique. If wisely applied, waterflooding optimization by playing with rates of injection patterns can lead to considerable sweep efficiency and, in turn, recovery factor. Finally, the most critical aspect of this story is that 166 Mbbl of oil increment costs zero for the operating company. That becomes the best option in terms of economics and the extension of fields’ lives.