bluuebunny/crossref_metadata_2025 huggingface dataset:
Maximizing Efficacy and Efficiency in a De-Flaring Project: Integrated Gas Processing Solutions for Associated Gas Recovery
Authors: Lucherini Franco , Bildesheim Jochen , Gattinoni Federico , Bergamini Lorenzo , Ricci Alessio
Published: October 2023

This paper describes the solution developed by Baker Hughes to maximize efficiency in a de-flaring project by applying a Dry Gas, Liquified Petroleum Gas, and Condensate recovery system to a mid-size associated gas source. The target of the solution is to combat climate change and generate value for the industry by providing an effective approach to address the major environmental challenge of associated gas flaring (The World Bank Group, 2023). The methodology used to provide a detailed description of the recovery system is constituted by outlining the key components and their functions. The main process parameters are also presented, including temperature, pressure, and flow rate, as well as the by-product deliverables of the plant. To provide a practical example, a typical flare gas stream is used as a reference case study, representing 100MMSCFD of raw gas and equivalent to 338 CO2t/hour calculated emission. Field validated models, regularly employed by Baker Hughes in project executions, are adopted as the method to simulate process and rotating equipment performances. The fractionation of raw gas, which involves separating the different hydrocarbons present in the gas stream, is a highly effective method of reducing associated gas flaring emissions. In combination with other measures, such as improved flare management and process optimization, it can reduce emissions by up to 95%. Moreover, the recovered gases can be used to produce export products, with a recovery efficiency of over 98% for propane and heavier hydrocarbons, depending on feed gas composition. By implementing this solution, the yearly revenues generation is expected to be up to $0.2 billion (U.S. Energy Information Administration, 2022), while also helping to combat climate change. This approach represents a significant step forward for the oil and gas industry, offering a way to turn waste into value and improve sustainability. This paper presents an innovative solution to combat routine gas flaring by describing an integrated gas processing solution for associated gas recovery. The paper provides valuable insights for researchers, engineers, and stakeholders interested in addressing climate change and maximizing the efficiency and efficacy of de-flaring projects.
Techno-Economic Analysis of GTL, LNG, CNG and GTW for Monetizing Marginal Remote Gas Field: A Case Study
Authors: Gupta M. K. , Joshi N. B. , Singh V. K.
Published: October 2023

Monetization of marginal gas field is often a challenging task, wherein quantum of gas available is very small. In remote field unavailability of gas consumers, lack of infrastructure, long gestation period makes it an unattractive investment. In this paper, a comparative analysis of available technology helped to take a wise decision among available technology to monetizing marginal fields

For early monetization options such as power generation, utilize it as compressed natural gas (CNG), Gas to Liquid (GTL), Liquefied natural Gas (LNG) and Gas to wire (GTW) was explored. A detailed techno-economic analysis of these have been carried out which enabled us to take a concrete decision. Scenarios such as variation of production performance, tweaking the production profile for optimum return on investment, option of utilization of diesel for internal or sale to oil marketing company (OMC). Sensitive analysis has been carried out to draw conclusion to achieve the best possible return in investment.

CNG is one of the way to monetize gas by compressing it up to 250 kg/cm2g and then transporting it into a cascade mounted truck. In a remote location, where consumers are not available nearby, transportation of CNG is a difficult task and would require multiple stages of transportation & cascade storage. LNG is basically natural gas converted in liquid form by cooling it to –260° F (–162° C). Changing it from a gas into a liquid that is 1/600th of its original volume and thereby transportation will become easier. In GTW, gas is used to generate power. In GTL, gas is catalytically converted into useful product such as synthetic crude, diesel, kerosene etc. Earlier, conversion of gas into diesel was not only cost intensive but also requires high space and hence, generally not accepted for small volume of gas. A detailed techno-economic analysis depicts that conversion of gas into diesel is attractive in investment but has an issue with Indian standard quality required for IC engine. CNG or LNG which was once non-viable are viable with reference to current open market scenario

This approach will open a plethora of opportunity and will open a flood gate to monetize the marginal gas field which time and again remains stranded. Apart from marginal gas field, the said approach is also useful for minimization of flare gas and will contribute significantly in energy transition.
Abandonment of a Well Located in a High Torrent River: Under-River Project using an HWO Unit in Colombia.
Authors: Eladio Guerrero , Jinna Palacios , Roberto Saumeth , Jose Jaramillo , Dario Padilla Luis , Valentin Quintero , Diego Castellanos , Oscar Galindo
Published: October 2023

This paper describes the planning and execution of an integrated Plug and Abandonment (P&A) operation on a well located in the middle of the remote Magdalena River in Colombia. This project was executed using a combination of specialized technologies from multiple service lines, including well control services, Hydraulic Workover (HWO), wireline, cementing, fluids services, and completion tools. An engineering study and river support barges were also a requirement, along with the design, build, and installation of specialist equipment, such as a support structure for the high fluctuations in water levels. The planning and execution of this particular abandonment made this a unique operation, believed to be the first of its kind in the world.

This project was performed in a very complex environment where river conditions and water depths allowed only a limited operational window. Since the well had been shut in for 40 years and was located in the middle of the Magdalena River, well integrity was another key concern. Other challenges included designing and implementing a customized structure suitable for supporting HWO operations in a shallow-water environment, developing a complex readiness process that included civil works (structure design and construction), a social approach, local content development, and environmental permits and licenses.

Despite the many environmental and well integrity challenges, comprehensive planning and preparation activities were key in successfully executing this under-river P&A project. All phases (including well intervention, mobilization, and demobilization) were accomplished with no recorded HSE or service quality issues. All the activities were executed without impacting the river, fauna, and the environment. This project was also delivered 6% ahead of schedule, 35 days in total and in full compliance with contract requirements and local regulations.

This highly complex project represents an achievement for the well operator and service company as it is believed to be the first of its kind in Colombia and worldwide.

This success story is a reference for future abandonment operations under similar conditions expected to be required in the Magdalena River in Colombia.
ESP Deployment Cable Demonstrates Resilience in the Face of Corrosion Challenges in Harsh Downhole Environments
Authors: Al Munif E. H. , Banjar H. M. , Ejim C. E. , Xiao J.
Published: October 2023

Electric Submersible Pumps (ESPs) face significant corrosion challenges in downhole environments due to high temperatures, pressures, and presence of corrosive fluids. These conditions can cause material degradation and severe damage, reducing equipment lifespan and impairing its performance. A Cable Deployed ESP (CDESP) is an alternative ESP deployment method, where the ESP is deployed by a specially designed cable with hydrogen sulfide (H2S)-resistant properties.

This paper shares lessons learnt from three different CDESP installations. It discusses the findings and results of dismantling, inspection, and testing of the encapsulated cable, as well as various CDESP components, including the pump, motor, connector assembly, seal, and sensor. The encapsulated cable was specifically designed for utilization in production environments with high H2S. The paper aims to provide valuable information on the performance and durability of CDESP components in downhole environments with corrosive fluids, high temperatures, and pressures.

The metal encapsulated power cable played a pivotal role in the CDESP system by offering outstanding shielding against H2S attacks and enabling a smooth outer diameter that could be easily grasped and sealed around. Furthermore, the cable was able to withstand harsh H2S environments with concentrations of up to 15mol% and chloride levels exceeding 150,000 ppm, proven from the lab and from the fields. While the developed cable proved to be robust and effective in harsh downhole conditions with high H2S concentration over a long period of time, the study findings indicate that other equipment components need to be improved to withstand corrosion. In all installations, signs of corrosion were observed on other system components such as thrust bearings and runners. Corrosion can cause blockages, increase friction, reduce system efficiency, and result in electrical or mechanical failures. Electrical failures include insulation failure on the cable, connectors and motor windings, while mechanical failures include bearings failure, broken shafts, pinholes and impellers damages. As a preventive measure to mitigate this corrosion from occurring in the seal and motor sections, an H2S scavenger (copper tube) can be installed to all seal chambers. In addition, pressure testing procedures during installation should be developed to enhance reliability.

Overall, this paper highlights the effectiveness of the developed cable and the need for further improvements in other components to ensure long-term reliability and performance of downhole equipment.
ESP Design Improvements Associated with Downhole Slotted Gravitational Filter and Downhole Chemical Treatment Prolong ESPs Run Life in Western Desert of Egypt: Case Study
Authors: Salah Ahmed , Sabaa Ahmed , Elhaleem A. Samir Abd , Medhat Ahmed , Diaa Ahmed , Abu-hozifa Osama
Published: October 2023

Electrical submersible pumps (ESPs) have become the most efficient and reliable artificial-lift method worldwide. One of the most common causes of premature failure in ESP systems is erosion or clogging from sand and solids in the reservoir fluids. These solids generate wear in pump stages, reduce its lifting efficiency and increase frequency of well interventions. Consequently, these ESP failures require reliable solutions to enhance the performance and prolong the run life of the ESP system.

In subject field inside the Western Desert of Egypt, several wells were experiencing pre-mature pump failures because of plugging, sand erosion on pump stages, and broken shafts. Five previous ESPs had been run in three offset wells, all of them had failed after average run life of 150 days. A detailed discussion with a technology provider and reference case studies come up with an integrated approach utilizing ESP Design improvements including Reliable Abrasion-Resistant Pumps and upgraded shaft material. The ESP system also incorporates a downhole slotted gravitational sand filter and continuous downhole chemical injection.

The slotted gravitational Sand filter is an innovative solution to take control of downhole sand problems utilizing gravitational force and filtration process. It prevents particles 100 microns and larger in size from entering and damaging the ESP system. In SWM field, Hydrocarbon recovery is mainly from one deep reservoir characterized by a high-pressure high-temperature (HPHT) environment at depths around 16000 ft, average pressure of nearly 6400 psi, temperature reaching 310 F, and considerable amounts of CO2 and H2S. The pump was set at 10000 ft to produce 2000 BPD with wellhead pressure not less than 1000 psi. In spite of, these challenging operating conditions and high withdrawal requirements, the newly designed system was capable to maintain stable ESP performance in two offset wells for more than 14 months and still ESPs are running. This solution showed significant improvement in overall system reliability and performance. Specifically, it helped to economically produce from the wells, reduce deferred production and downtime resulting from frequent pump failures, and maximize their recoverable reserves. In addition, it increased the capability of being replicated in other wells with high sand production.

This paper will provide a detailed completion design process to create a robust ESP system that fits with challenging wellbore conditions in which sand production and erosion are growing concerns. This study starts from initial installations, subsequent well interventions, equipment Dismantle Inspection and Failure Analysis (DIFA), ESP configuration enhancements, and finally reaches field application performance data in which the new completion design was successfully implemented to extend ESP run life.
ESP Cable Deployment has Induced a New Paradigm in UAE to Turn the ESP Business into Rigless Operation, Presenting a Cost Efficient and Faster Application
Authors: Guzman Rodrigo , Hashmi Zahra Faisal Al , Ilyasov Ruslan , Sonbaty Tarek Mohamed El , Gupta Sanchay , Aguilar Hector , Martins Azubuike , Ofodile Onyebuchi , Cardozo Padron Jose
Published: October 2023

The implementation of the first pilot of the fully rigless ESP deployment in the UAE (United Arab Emirates), has successfully overcome the challenges of well availability and maintainability when using artificial lift systems. The application achieved the production potential of a standard ESP and completely replaced the requirement for a rig during its deployment.

This enhanced ESP deployment is shifting the paradigm associated with ESP and rig intervention and is establishing new opportunities for the artificial lift industry. Cable deployment ESP is the only full rig-less technique allowing to complete the deployment in smaller tubing size (2 7/8" and 3 ½") compared to other kind of ESP semi-rigless deployment as coiled tubing and slickline, which are normally limited to a 4.5" production tubing and initial rig interventions.

The time and resources required for rig intervention were significantly reduced. This resulted in reducing HSE risks, reducing the and the carbon footprint by more than 50%, compared to standard rig-based ESP operations.

With the aim of reducing the number of inactive wells and maximizing return on investment, while also reducing the work-over cost of oil ESP wells, the cable deployment rigless ESP was introduced to eliminate the rig costs associated with the ESP work-over costs - which represent 75-85% of total costs for an onshore ESP completion. Additionally, this approach reduced the failed ESP recovery time from 200 days (mainly waiting to allocate slot in DWS (Drilling and Workover Schedule) to 30 days, which decreased deferred production by 85%. Furthermore, this technology has proved to be an efficient tool to reduce inactive wells percentage, as it can be used as a temporary solution for gas lift wells waiting on availability of surface facilities, which typically could take five years.

The payback of rig-less ESP is 15 days, versus payback of 38.6 days for a rig-based solution, it also avoids an average production deferment of 275K oil barrel per well/year and drastically decreases the number of inactive wells, supporting operations teams to sustain production quotas.

Based on the trial results, the cable deployed rigless ESP has created business value through the following: Successfully re-activate production in less than 1.5 days.Proven success of rig-less application (installing and pulling activities).Production delivered after 2 hours of deployment (as per ESP design/model).Reduction footprint by 60% (compared rig-based ESP)Stable operation conditions observed and achieved proposed runlife of 360 days compliant with HSE 100%.
Navigating Net Zero – The Emerging Role of the National Energy Company
Authors: Markouizou Virginia
Published: October 2023

Executive Summary

In this session we will aim to present a possible pathway for National Energy Companies (NECs) to promote country inward investment that supports climate resilience, a managed transition from hydrocarbon overdependence and net zero goals. We will aim to address how NECs, in close cooperation with their respective Ministry, can develop country analytics that lead to a comprehensive national energy plan that prioritizes climate resilience, renewable energy sources and energy efficiency measures.

We will show how countries such as Namibia understood that they have a once-in-a-generation opportunity to significantly reduce their emissions by leveraging their natural resources to attract muchneeded foreign direct investment and how they moved decisively to develop a portfolio of complimentary infrastructure projects, with a vision to create a hub of renewable assets and effectively transforming their country.

The complexities of the different roles that the NECs have to play today are well recognized. They need to protect core energy assets, revenues and existing cash flows, create jobs and ensure energy security. The NECs are also expected to confidently step towards a net zero and sustainable future on behalf of their country. Global governments expect NECs to deliver emissions reduction at a country level, the practical steps for energy transition and, to a large extent, the delivery of the National Determined Contribution.

In this current environment, NECs around the world are starting to pivot towards climate resilience and renewable energy investments. The NECs must compete for access to capital and participation in the race for a "just" transition. In 2019, the IMF issued a report calling for more transparency in the management and governance of National Oil Companies (NOC) – calling them the "hidden economic giants". Remaining opaque or "hidden" is no longer an option. In a world that demands transparency which addresses ESG and sustainability commitments, capital markets expect consistent reporting. This is a big task for organizations which still face major shortcomings on their reporting practices, and in some cases, have no history of environmental reporting.

To complicate matters further, there is currently no universal standard for external reporting of environmental data, so it is for the individual NECs to determine which data analytics and insights will allow access to energy transition finance at competitive rates. There is general agreement though that data driven investment decision making that allows for transparency, stakeholder engagement and private/public sector collaboration is now needed more than ever for capital allocation and access.

In this context we will aim to present how NECs can use historic static and dynamic operational data analytics to understand and address risk and opportunity and successfully develop their energy investment decision frameworks.
Enabling Autonomous Well Optimization by Applications of Edge Gateway Devices & Advanced Analytics
Authors: Kumar Manish , Varma Nakul , Rao Manjunath , Chandak Ravi , Jadhav Sujit , Sharma Himshella , Singhal Joy , Ranjan Amit , Chauhan Shailesh , Bohra Avinash , Patni Atul
Published: October 2023

Data monitoring in a big oil field without any digital platform is a challenging task but it is critical for ALS monitoring and optimization. In sucker rod pumping wells, real time dyna card collection and analyzation is very important for understanding downhole pump behavior and system health. Manual dyna card collection twice a week for ~47 horizontal wells is very low. Real time dyna card requires atleast 256 data points per minute frequency. Its analysis is very effective to optimize well production and increase the pump life and rod run life. The lack of real time monitoring resulted in well downtime and associated production loss. The combination of IOT, Cloud Computing and Machine learning implementation shifted our approach from reactive to proactive which assisted in ALS Optimization and reduced production loss.

The data is transmitted to Se Suite Central, a web based Descisison Support System hosted on cloud. Since thousands of dynacards are generated in a day, therefore the algorithm was made with automated card classification using computer driven pattern recognition techniques. The real time data is used for analysis including basic statistics and machine learning algorithms to classify thousands of dynacards every day. The pump signatures were identified using machine learning libraries and categorized. Several informative dashboards are developed which provided quick analysis of ALS performance, a few of them are -

Well Operational Status Dyna cards Interpretation module SRP parameters visualization Machine Learning model calibration module Pump Performance Statistics

After collection of enough data and creation of analytical dashboards using domain knowledge, the gained insights were used for ALS optimization.

Smart Alarms were generated using statistics and machine learning settings by the system which gave alerts by e-mail if an abnormal behavior or erratic dyna-cards were identified. This helped in reduction of well downtime in some events which were treated instinctively before. The integration of domain knowledge and digitalization enabled to take informed and effective decisions. This project supported in effectively managing a complete asset of more than 47 wells remotely with limited resources. This set up has capably run low PI wells intermittently, which has saved power consumption to run the surface pumping units. This digitalization plan has prevented many pump & rods failures, resulting in saving numerous workover jobs and well downtime.
Machine Learning Application of Core and Log Prediction in Various Depositional Environment Case Studies
Authors: Shah Jamari Mohd , Masoudi Rahim , Zulkifli Nur Fatihah M , Sansudin Salmi , Fadhil M Imran M
Published: October 2023

Conventional methods of acquiring log and core often exposes project owners to high cost and time-consuming operation. Other than that, massive data availability in different platforms are also persistent issue waiting to be resolved. Artificial Intelligent module of well log artificial intelligent prediction module named Enhanced Resource Monetization Artificial Intelligent (ERMAI) and physical core artificial intelligent prediction module named Core Artificial Intelligent (COREAI) are developed to eliminate expensive operation, factor out human biasness, enable prediction of core data and log data at any depth and all data are kept in structural corporate database.

Overall approach presents innovation and agile technologies that integrate data management, data quality assessment and predictive machine learning to maximize the company asset value using existing core and well log data. The development of machine learning algorithms identifies potential outliers, benchmark the valuable data against the current industry standards, increases the confidence in data quality and avoids augmented error in predicting reservoir properties. For core prediction using CatBoost algorithm machine learning methods by combining digital raw data with core photo. And for log prediction using random forest assemble learning methods which using certain training wells for massive prediction.
Life Cycle Cost Assessment for Digitalization Project Implementation in an E&P Company
Authors: Mishra Nikita , Saraf Anup
Published: October 2023

The main objective of this manuscript is to devise an objective, scientific and empirical tool for assessing the ‘life cycle cost’ of any digitalization project in an Exploration and Production (E&P) Company vise-a-vie its ‘projected benefits’. This provides a ready-made empirically proven tool for the CIO or Project Manager of the E&P Company to decide on the ‘financial model’ for an upcoming digital project during the conceptualization stage when there's a long debate amidst the project team or the user indenting group regarding CAPEX or OPEX or Hybrid Model for the digital project implementation. With the advent of cloud platform and SaaS platform, various exciting avenues have opened up for companies to implement digitalization solution in OPEX model where the upfront investment is very less. Moreover, most of the R&D in this domain around the industry is keeping cloud servers in mind resulting in breakthrough digitalization innovation opportunities for E&P companies at a very nominal cost. However, there is a different narrative as well which signifies the advantages of owning the system(s). This manuscript has tried to settle this long-standing debate.

This manuscript develops a table with a total scoring out of 100 marks with weighted average given to the different factors or parameters. This is a multi-dimensional scoring system developed keeping various factors and scenarios in mind. This also takes into factorization whether the digitalization project under discussion is of transformational nature or incremental nature. This also has a scenario to pick from exploration / drilling / reservoir/well/production/pipeline or complete Digital oilfield project scenario which leads to a different customized scoring pattern. The user has to select various scenarios and factors in the checklist of two pages according to which the scoring pattern is decided for them leading to a customized scoring, hence decision-making tool for them. Apart from the checklist, user has to enter the estimated project cost over lifecycle and range of gain in the checklist too.
First Application of Biogenic Fibres in a Reservoir Drilling Fluid to Enable Safe Drilling and Data Acquisition Across a Depleted, Highly Laminated, Carbonate Reservoir With Heterogenous Characteristics
Authors: Jeughale R. , Khan R. N. , Andrews K. H. , Mendez F. A. , Nakano S. , Toki T. , Alzaabi M. A. , Klungtvedt K. R. , Sarap G. , Meki Z. , Gupta K. , Vallejo A. V. , Ramnarine N. , Nofal S. F. , Alzaabi A. Y.
Published: October 2023

Drilling and completion operations across mature reservoirs are challenging due to high overbalance pressure and become even more so when extended static time is required to satisfy data acquisition requirements. A major Operator in the UAE typically drills challenging 6-inch horizontal drains which cross several heterogenous layers with pore pressure requirements varying from equivalent mud weights of 14.5 ppg to as low as 6.0 ppg across the exposed reservoirs.

With increasing data collection requirements there was a high incidence of stuck pipe events during Modular Dynamics Tester (MDT) operations, which led to significant Non-Productive Time (NPT) while attempting to release the stuck pipe. As a short-term mitigation measure additional work was done optimizing the bridging package along with increased sacrificial treatments and monitoring to ensure compliance with the required bridging scheme.

In parallel, a longer-term strategy was initiated to examine alternative fluid systems or products to mitigate against stuck pipe as Well-As aids for releasing stuck pipe. This paper presents the methodology for the design and field validation of an engineered Reservoir Drilling Fluid (RDF) solution with a thin cohesive filter cake and minimal pore pressure transmission characteristics to achieve well objectives.
Leveraging Carbon Market Mechanism to Achieve De-Carbonization Targets
Authors: Al Mazrouei Shayma , Aggarwal Dinesh Kumar , Ganesan Suresh , Ramachandran Kumaravel
Published: October 2023

ADNOC is committed to achieve 25% reduction of GHG emissions by 2030. The biggest challenge however remains the financial implications of implementing de-carbonization measures. Company has successfully registered one of its "36-inch 52km Pipeline Network Flare Avoidance Greenhouse Gas (GHG) Reduction Project" under the Under the European Fuel Quality Directive (FQD) Upstream Emission Reduction (UER) scheme to generate Carbon Credits, equivalent to amount of flare gas avoided. The process involved: Project identification and development of Project Design Document.Calculation of Upstream Emission Reduction based on daily volume of HP and RG gas diverted and respective calorific values,Third party validation and verification.Transaction of verified Carbon Credits in the international market.

A part of the carbon credits accumulated were traded in the international market to realize carbon revenue. Success of this program complemented Company’s de-carbonization efforts as a clear demonstration of realizing the benefits GHG reduction initiatives that will help offsetting a part of de-carbonization costs, making it a win-win situation.

The project supports ADNOC commitment towards achieving GHG emission reduction targets. Success of the project has been the result of remarkable collaboration between various internal and external stakeholders. This effort will stimulate others Operating Sites/Group Companies to implement similar programs, leading to a wider impact towards fighting the climate change challenge.
Torque-Balanced Sour-Service Cable and Intelligent Extreme Wireline Tractor Enables Access to Deepest Sour Reservoirs in UAE
Authors: Varghese M. , Benserradj M. L. , Woods J. , Varkey J. , Cevallos A. , Chang S. , Mangum J. , Nigmetullin K. , Correia G. M. , Mustafa H. , Gadelhak A. , Bazuhair A.
Published: October 2023

Advanced torque-balanced sour-service wireline cable in combination with an intelligent sour-service slim tractor overcomes wireline conveyance challenges to obtain high-quality production logging and well integrity data from extended-reach drilling (ERD) wells in a hostile environment. Using the data obtained by this method, the operator evaluated the well production profile, confirmed the reservoir properties, and assessed the integrity of wells. The use of this technique also enabled the operator to successfully restore the production in a well with malfunctioning inflow control devices (ICDs). Wireline conveyance in ultra-sour, deep ERD wells is extremely challenging due to the limitations of existing conveyance technologies.

This paper presents an innovative method of combining a torque-balanced sour-service wireline cable and an intelligent sour-service slim tractor to successfully convey production logging tools in over 35 ERD wells with more than 100 cable descents including conveyance to the deepest depth ever in a sour well in the UAE. The following methods were used: 1) Model well tortuosity to estimate tractor forces and navigation challenges. 2) Select a high-strength, torque-balanced, sour-service cable, and a small-diameter, intelligent, sour-service tractor. 3) Design a fit-for-purpose tool configuration and operation strategy to navigate complex completions. 4) Establish a core team of key personnel from field operations and the operator with direct feedback to the product manufacturing center to enhance equipment design and performance.

Deep reservoir access up to 26,870 ft was achieved. Successful navigation through step changes between the upper and lower completion and across multiple ICDs demonstrated the tractor's ability to traverse varying internal diameters throughout the intervention. The interventions represent over 480,000 ft of cumulative tractoring. Simultaneous acquisition of production log data while tractoring down ensured superior quality of data and improved efficiency of the operation. Repeatable and reliable performance of equipment enabled rapid turnaround between operations. Accurate determination of horizontal lateral zonal contributions, fluid source, completion integrity, and reservoir saturation were made possible for the first time in this field.

Successful deployment of this combined conveyance solution has created a paradigm shift for safe and efficient intervention of extended reach development wells with high H2S/CO2 concentrations.
Revolutionary Electrical-Mechanical Punching Solution for Remediation of Declining Hydrocarbon Production
Authors: Mourani Houssam , Rustan Jon-Erik Stølen , Owen Edward Thomas
Published: October 2023

An operator on the Norwegian Continental Shelf was confronted with declining production of hydrocarbons, making a particular well no longer profitable. The typical solution for this issue is to sidetrack and recomplete, however, this method is both time-consuming and costly.

The existing completion of the well included multiple sand screens, where production of hydrocarbons was achieved through a single narrow nozzle for each screen. It was believed that these nozzles were fully blocked by scale and/or sand, and a potential solution was to punch or perforate the basepipe. However, any accidental puncturing of the screens would open the door to the possibility of increased sand production and would eventually kill the well. The only acceptable tolerance for penetration depth was 1.75 mm (0.0689″).

Explosives were ruled out as an option due to the lack of control over penetration depth, as well as the irregular shape of the holes that would be produced. Instead, an electrical-mechanical punching tool was chosen as the preferred solution. This tool was chosen for its precision and control of penetration depth, as well as the uniform shape of the machined holes.

Following the operator's assessment of production logging tool data, it was decided to create five holes at every 60° increment in the two deepest sand screens to increase the flow area through the screen. Precision and control of penetration depth were of the utmost importance. The remaining sand screens in the well were isolated by a straddle to prevent excessive gas production.

The intervention was completed in December 2020, with both of the targeted sand screens punched in one run utilizing a combination of an electrical-mechanical punching tool and a mechanical rotational sub to ensure correct tool orientation. As of the beginning of June, 2023, the operator has kept the well in production due to the significant shift in hydrocarbon production rates.

This study presents an innovative and cost-effective solution that eliminated the need for a costly workover recompletion operation and, prevented the potential failure of the well. By implementing the electrical-mechanical punching tool, the operator was able to remove blockages in the sand screens with precision and control, leading to a substantial increase in hydrocarbon production. This approach offers valuable insights and a viable alternative for addressing declining production in wells with similar completion configurations.
Accelerating Decarbonisation through Enterprise Level Orchestration
Authors: Prabagar M. , Kuah Y. , Uzaini M. Mohd
Published: October 2023

The world is in a journey to achieve Net Zero Carbon Emission targets in line with the Paris Agreement to limit the rise of global average temperature to below 2degC and strive to achieve 1.5degC combating climate change. PETRONAS has taken progressive steps to position the organization by declaring Net Zero Carbon Emission by 2050 aspiration. The immediate short-term target is to cap the GHG emission by 20241. Enterprise Decarbonization unit is established to accelerate decarbonization solutions & projects across the Enterprise encompassing Upstream, Gas and Downstream Facilities. The methods utilized for the execution is first to identify the emission sources across the Enterprise through evaluation of the actual & forecasted emission profiles for the past 5 years and next 5 years. The major sources such as Flaring & Venting, Stationary Combustion, Inherent, Fugitive and Purchased Energy are categorized and mapped.

The possible solutions are also identified and mapped against the Focus Areas such as Carbon Capture and Storage, Energy Efficiency & Electrification Improvement, Zero Flaring & Venting and Renewables.1 The projects appliable to each facility are then measured quantitively in terms of their Cost, Schedule, Carbon Abatement & Project Complexity & Maturity. The projects are then ranked to an index, allowing prioritization and sequencing of high impact projects that could contribute to the target.

The projects are then executed through a 3-pronged strategies which are front loading the activities, bundling solutions for scale and pace, and advocating open innovation. A dedicated corporate decarbonization budget is also allocated to drive the decarbonization project focusing on reducing emissions.

Through the execution of the projects in a centralized and orchestrated manner, Enterprise Decarbonisation has been able to realise some early successes.

The short-term projects and programs are accelerated to achieve the target as aspired based on the Net Zero Carbon 2050 Pathway2. The novel approach in this paper is the methodology used to identify, prioritize & accelerate programs to ensure quick deployment ensuring a good portfolio sequencing.
Business Agility: Enabling PDO to Thrive in a Rapidly Changing World
Authors: Al Ghafri Z. S. , Al Aufi Y. A. , Al Bahri L. Y. , Al Yazeedi Z. A. , Al Kindi T. S. , Crampin T. , Hillgartner H. O.
Published: October 2023

Agile methodology is one of the important and popular approaches used in project management. It is widely implemented in software development, and it shows success results in the implementation. Unlike waterfall approach, Agile drives the team to work simultaneously on different phases of the project, that's why it's known to be faster and more adoptive. It also emphasizes flexibility, collaboration, and enable continuous improvement.

The waterfall approach, is a linear system of working that manages projects step by step, where project phase does not advance until the earlier phase completed and receives final approval (Figure 1)

With the internet taking the world to another era in mid 1990s, the traditional project management approaches found to be outdated. These approaches didn't allow the developers to be responsive enough to the dynamic changes happening in the market. Therefore, looking for alternative for theses outdated approaches became an urgent need to survive in the market.
Integration of Multi-Well Ultra-Deep Resistivity Inversions to Map Oil-Water Contact at Reservoir Scale
Authors: Bikchandaev E. , Fouda M. , Taher A. , Abdulmohsin M.
Published: October 2023

Ultra-deep resistivity is a necessary measurement in well placement operations, for detecting secondary reservoirs over 100ft from the wellbore and steering in the optimum target zone to maximize well productivity. The data provides deeper understanding of the subsurface geology and is usually analyzed on a well-to-well basis. A new workflow has been developed to integrate data from different wells for mapping fluid contacts to optimize future well placement to maximize productivity.

Ultra-deep resistivity measurements are inverted real-time to produce models of the sub-surface geology. The resulting models, along with supporting LWD data have the following applications: geomapping of the target zone (formation dip and thickness); deep detection of oil-water contacts (OWC) to maintain standoff distances; geosteering in targets avoiding reservoir exits; geomapping resistive or conductive layers above and below trajectory if present. This data has been acquired from several wells and OWC grids created based on inversions for three neighboring wells. One of the wells has a proven OWC level confirmation. The structural surfaces created reflect the distribution of the OWC in the drilling area.

Inversion results integrated with geological models reduce the uncertainties for far field fluid mapping. The OWC does not have a single sustained vertical depth, it displays vertical depth variations (water coning) across the area under investigation. The general trend follows the structural surfaces of the target formation. However, the OWC level can vary along the well path up to 10-20 ft true vertical depth over 300 ft of measured depth footage. Identifying and measuring these changes during drilling helps to optimize the completion design to maximize production. Additionally, it helps to improve and optimize the planning of future wells planned for the area.

Ultra-deep resistivity inversions integrated with the geological model provide critical information for OWC characterization at the reservoir scale. This new workflow helps to increase sweep efficiency and optimize the wells productivity, by taking advantage of the information available real-time to identify the position of the OWC along a target well path.
Challenges in Implementing a Corrosion Monitoring Operating Envelope Program in Matured Offshore Operations
Authors: Zulkafli H. S. , On A. A. , Nair K. , Kerisnan V. G.
Published: October 2023

In the current operational dynamics, relying solely on past records and known equipment conditions to become the basis for Corrosion Management for specific equipment or systems may no longer be adequate. It is essential to have a comprehensive understanding of the process and operating conditions, as well as the resulting damage mechanisms, to develop and maintain the equipment and systems' integrity.

Effective corrosion monitoring can maximize the likelihood of detecting potential increased damage rates or appearance of new credible damage mechanisms. Corrosion monitoring strategies and plans should be adaptable and consider evolving process conditions and the current state of equipment. Particularly with the adoption of risk-based corrosion management approach, it has become increasingly crucial to identify and monitor the process closely against the predetermined operating envelopes.

Understanding the importance for proactive corrosion monitoring to be able to control the degradation rates and/or avoid the occurrence of new damage mechanisms that might eventually lead to loss of containment, it is compulsory to have a systematic Corrosion Monitoring System (CMS) in place to effective corrosion management. Corrosion Management Plan (CMP) specifies the necessary requirements for each identified damage mechanism applicable to the specific assets.
Remote Wells Wireless Integrity Monitoring – Field to Desk (FTD)
Authors: Yusubov Tural , Malek Matar Bani , Vähäkangas Teemu
Published: October 2023

Well Integrity Management is essential to the Asset Integrity Management (AIM) process. In Remote and Marginal fields, the key to success in AIM is agility which requires continuous monitoring and the ability to predict any potential failure. The conventional method of data collection in remote fields requires periodic (from weeks to months) field trips, which has relevant costs and risks impacted with other challenges such as: Data collection on site: traveling to the site and human exposure to HSE risks (H2S, high pressure, hydrocarbons, etc)Data communication: infrequent data losses due to sites remote locationsData quality: human involvement in the process introduces potential errors and noises in the data

This paper presents a comprehensive study on the successful pilot conducted by Al Yasat Petroleum, an oil and gas industry company, in collaboration with CREOWAVE. The objective of the pilot was to test wireless communication pressure and temperature technology using the GSM network and LoRa data communication method. The technology was applied to monitor the Well Integrity status of two onshore remote wells over a period of two years. The paper discusses the effectiveness, benefits, and potential of this technology in improving operational efficiency, reducing HSE risks, and minimizing costs associated with well integrity management.
Successful Pipe Recovery Solutions in Unique Stuck Scenarios for Coiled Tubing and Downhole Completions
Authors: AlMarzooqi A. , Faqir A. M. , Nasr K. K. , Bana S. , Baca Espinoza I. , Garzon C. , Abushamat A.
Published: October 2023

Considering the advancement of smart completions getting stuck downhole is a high risk in today's working environment. To avoid incurred costs in a rig and rig spread rates, it is eminent to have reliable and quick pipe recovery tools (PRT) and methods for special cases. To complete this challenge the nonexplosive plasma punchers and cutters play an important role.

Convectional PRT utilizes HAZMAT materials and involves both HSE and logistical challenges increasing the delivery times to the wellsite for direct execution. This step is bypassed for non-explosive plasma PRT. The slim coiled tubing (CT) recovery puncher and cutter range from ¾″ to 1″ in size; applicable on 1 ¾″ - 2″ CT produces a clean cut for further fishing intervention. For unconventional cases where the standard tools cannot pass the slimmer PRT is required. Finally, a serious challenge is packer mandrels with cut/release windows < 1-2ft could be addressed by plasma PRT.

The Adnoc Offshore real results include 4 successful CT recovery operations mobilized in under 24 hours and successfully executed as low as 10 hours of operating time. The plasma PRT also helped to recover the stuck dual completions with small restrictions and managed to cut at points with deviation >80 degrees. Moreover, the PRT can cut in any pipe condition such as in neutral, compression, or under tension allowing to perform the job prior to the rig move. Having the ability to cut in restrictive conditions with high accuracy, more than 100's successful nonexplosive PRT punchers and plasma cutter run with very high success rates.

The non-explosive PRT can be air shipped by chopper to offshore locations minimizing downtime on logistics such as vessel availability, and weather challenges. It is fulfilling the governmental security requirements for HAZMAT logistics, storage, and handling that are restrictive to the explosives or chemicals PRTs.
Innovative Isolation of In-service Pipelines Using STATS Remote Tecno Plug for Modification Works
Authors: Chandran Jimesh , Bowie Angus , Menon Unnikrishnan , Backer Mohsin , Eisa Zayed Mohammed , Gor Chirag Madhusudan
Published: October 2023

Isolating operating pipelines for modifications without production impact is a challenge that Oil &Gas industry faces regularly during projects and maintenance works.

This paper details innovative non-intrusive isolation of 2 (two) ADNOC Onshore Crude oil pipelines transferring total 680MBOD using STATS Remote Tecnoplug to carry out project modification works without impacting production. The objective of this paper is to present an alternative isolation technique for pipelines with space constraints to deploy conventional hot tap and stopple operations