Efficiency

Abstract In the past decade, the operators and service companies are seeking an integration solution which combines engineering and geology. Since our drilling wells are becoming much more challenging than ever before, it requires the office engineer not only understanding well construction knowledge but also need learn more about geology to help them address the unexpected scenarios may happen to the wells. Then a novel solution should be provided to help engineers understanding their wells better and easier in engineering and geology aspects. The digital twin technology is used to generate a suppositional subsurface world which contains downhole schematic and nearby formation characteristics. This world is described in 3D modelling engineers could read all the information they need after dealt with a unique algorithm engine. In this digital twin subsurface world, the engineering information like well trajectory, casing program, BHA (bottom hole assembly) status, are combined with geology data like formation lithology, layer distribution and coring samples. Both drilling or completion engineers and geologist could get an intuitive awareness of current downhole scenarios and discuss in a more efficient way. The system has been deployed in a major operator in China this year and received lot of valuable feedback from end user. First of all, the system brings solid benefits to operator's supervisors and engineers to help them relate the engineering challenges with according geology information, in this way the judgement and decision are made more reliable and efficiently, also the solution or proposal could be provided more targeted and available. Beyond, the geology information from nearby wells in digital twin modelling could also provide an intuitional navigation or guidance to under-constructed wells avoid any possible tough layers via adjusting drilling parameters. This digital twin system breaks the barrier between well construction engineers and geologists, revealing a fictive downhole world which is based on the knowledge and insight of our industry, providing the engineers necessary information to support their judgement and assumption at very first time when they meet downhole problems. For example, drilling engineers would pay extra attention to control the ROP (rate of penetration) while drilling ahead to fault layer at the first time it is displayed in digital twin system, which prevent potential downhole accident and avoid related NPT (non-production time). The integration of engineering and geology is a must-do task for operators and service companies to improve their performance and reduce downhole risks. Also, it provides an interdisciplinary information to end user for their better awareness and understanding of their downhole asset. Not only help to avoid some possible downhole risks but also benefit on preventing damage reservoir by optimizing the well construction parameters.

OnePetro

doi: 10.2118/214625-MS

SPE

SPE-214625-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country: Asia > China (0.48)

Genre: Overview (0.47)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > China > Sichuan > Sichuan Basin > Southwest Field > Longwangmiao Formation (0.99)
North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.98)
North America > United States > North Dakota > Williston Basin > Bakken Shale Formation (0.98)
North America > United States > Montana > Williston Basin > Bakken Shale Formation (0.98)

SPE Disciplines:

Well Drilling > Drilling Operations > Drilling optimization (0.67)
Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (0.49)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (0.47)

Technology:

Information Technology > Artificial Intelligence (0.69)
Information Technology > Data Science (0.47)

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A Hybrid Physical and Machine Learning Model to Diagnose Failures in Electrical Submersible Pumps

Al-Ballam, S. (Kuwait Oil Company, Ahmadi, Kuwait) | Karami, H. (Mewbourne School of Petroleum & Geological Engineering, The University of Oklahoma, Norman, OK, USA) | Devegowda, D. (Mewbourne School of Petroleum & Geological Engineering, The University of Oklahoma, Norman, OK, USA)

OnePetroMay, 2023

Abstract Electrical submersible pumps (ESPs) are among the most common artificial lift techniques in highly productive oil wells. The ESP failures are extremely costly to the producers and must be minimized. This study proposes a hybrid approach utilizing multi-class classification machine learning (ML) models to identify various specific failure modes (SFMs) of an ESP. A comprehensive dataset and various ML algorithms are utilized, considering the physics of fluid flow through the ESP. The ML models are based on field data gathered from the surface and downhole ESP monitoring equipment over five years of production of 10 wells. The dataset includes the failure cause, duration of downtime, the corresponding high-frequency (per minute) pump data, and well-production data. The prediction periods of 3 hours to 7 days before the failure are evaluated to minimize false alarms and predict the true events. Four modeling designs are used to handle the data and predict ESP failure. These designs differ in the input parameters used for the model and signify the effect of including the physical parameters in failure prediction. Several ML models are tested and evaluated using precision, recall, and F1-score performance measures. The K-Nearest Neighbor (KNN) model outperforms the other algorithms in forecasting ESP failures. Some other tested models are Random Forest (RF), Decision Tree (DT), Multilayer Perceptron (MLP) Neural Network, etc. According to the data, most ESP operational failures are characterized as electrical failures. The ML models show similarly good performances with high true prediction rates in predicting ESP failures for all the tested designs. The design that integrates the effects of gas presence and pump efficiency while minimizing the number of input variables is suggested for general use. Increasing the prediction period up to 3 days results in a negligible drop in the model’s performance, showing that the model can predict ESP failures accurately three days before their occurrences. However, the forecasts show increases in missed failures and false alarms for prediction periods of more than three days, making three days the selected prediction period. These ML models will aid operators in avoiding undesirable events, reducing downtime, and extending the lifespan of ESPs. ESP failures are unanticipated but common occurrences in oil and gas wells. It is necessary to detect the onset of failures early and prevent excessive downtime. This study’s model allows engineers to detect failures early, diagnose potential causes, and propose preventive actions. It is crucial in transitioning from a reactive event-based to proactive and predictive maintenance of artificial lift operations.

OnePetro

doi: 10.2118/214632-MS

SPE

SPE-214632-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Asia (0.94)
Europe (0.68)
North America > United States > Oklahoma (0.46)
North America > United States > Texas (0.29)

Genre: Research Report > New Finding (0.46)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

North America > United States > California > Los Angeles Basin (0.99)
North America > United States > Alaska > North Slope Basin > Milne Point Field > Kuparuk Formation (0.99)

SPE Disciplines:

Production and Well Operations > Artificial Lift Systems > Electric submersible pumps (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)

Technology:

Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning (1.00)
Information Technology > Artificial Intelligence > Machine Learning > Neural Networks > Perceptrons (0.54)
Information Technology > Artificial Intelligence > Machine Learning > Performance Analysis > Accuracy (0.47)

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Enzyme-Based Cleanup Fluid for High Temperature Filtercake Removal Applications

Al-Taq, Ali A. (Saudi Aramco, Dhahran, Eastern Province, Saudi Arabia) | Al-Ibrahim, Hussain A. (Saudi Aramco, Dhahran, Eastern Province, Saudi Arabia) | Alsalem, Ali A. (Saudi Aramco, Dhahran, Eastern Province, Saudi Arabia) | Alrustum, Abdullah A. (Saudi Aramco, Dhahran, Eastern Province, Saudi Arabia)

OnePetroMay, 2023

Abstract Mud-induced damage is highly pronounced in horizontal wells due to the longer period of exposure to drilling mud and low draw-down pressure. Enzyme-based cleanup fluids are preferred for filtercake removal applications, especially in horizontal wells due to their several advantages compared to conventional cleanup fluids. The advantages include low reactivity, less corrosivity, more environmentally safe, polymer-specific enzyme breakers, and ultimately homogenous filtercake removal coverage. Most enzyme-based cleanup fluids are limited to low temperatures. In this study, extensive lab work was conducted to evaluate an enzyme-based/in-situ generated organic acid cleanup fluid for a water-based mud at a temperature of 250°F. The experimental work included coreflood experiments, HT/HP filter press, and see-through cell. Analytical techniques, including ICP, XRD, EDXRF, IFT, and iodine tests, were used to assess the interaction of the cleanup fluid with filtercake components. The results showed that the enzyme/in-situ organic acid generated cleanup system was effective at degrading filtercake for a water-based mu field sample, which was reflected in the obtained return permeability of nearly 83%. Iodine tests confirmed that the enzyme was able to degrade the starch present in the filtercake. The surface tension of fluid is generated due to the interaction of the enzyme-based breaker with the filtercake at 250°F and for 48 hours was 31.11 dynes/cm at 22°C, which indicates that this system can help to prevent water blockage problems, especially for gas tight formation. This paper will discuss in detail all experimental results and findings.

OnePetro

doi: 10.2118/214628-MS

SPE

SPE-214628-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America > United States > Texas (1.00)
Asia > Middle East > Saudi Arabia (0.68)

Genre: Research Report > New Finding (1.00)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
North America > United States > Texas > Permian Basin > Yates Formation (0.99)
North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
(25 more...)

SPE Disciplines:

Well Drilling > Formation Damage (1.00)
Well Drilling > Drilling Operations > Directional drilling (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
(4 more...)

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Estimating Drilling Emissions Footprint in a Cloud-Based Well-Construction Planning Solution

Medina, Diego (SLB) | Qi, Chaobo (SLB) | Zhu, Lei (SLB) | Suryadi, Hendrik (SLB)

OnePetroMay, 2023

Abstract Many operators commit to reducing their operation's carbon dioxide (CO2 emissions. According to McKinsey & Company (2020)(1), well drilling and extraction processes contribute 8% of the Scope 1 emissions in the oil and gas industry. Rig site activities generate one-third of the overall emissions footprint for the well construction process. A well construction process consists of hundreds of activities and tasks ranging from well spud to rig release. Along the way, many different types of equipment are used. To minimize emissions, we need to analyze how the power is used and how it can be saved throughout the well construction process. Selecting lower-carbon energy sources can significantly reduce Scope 1 emissions, but the transition process takes time. The operator and contractor must continually improve their operation's efficiency to reduce emissions. The emissions footprint model was developed based on CO2 emissions data and power consumption statistics for land rigs. During well planning, the engineer strives to formulate a drilling program considering the anticipated time, cost, and overall emissions objectives. Emissions volumes should be calculated based on the equipment used in each activity. The engineer compares the technologies proposed for the drilling program to determine the optimum equipment solution with the lowest overall environmental impact. The ability to forecast expected emissions for planned wells helps the engineer make technology selections for each drilling plan. With validated models, it's possible to calculate the CO2 released based on the measured drilling parameters and work to reduce it. For sustainability purposes, the engineer must consider the total emissions created by the entire process as an additional performance indicator. In this paper we describe the integration of emissions footprint modeling into the overall well-planning workflow. We developed the model by measuring actual emissions and power usage of different rig equipment during different drilling activities. This was done by using a cloud-based well-construction planning solution. The workflow was embedded into the overall well design, enabling the engineer to visualize each project's anticipated time, cost, and emission. Energy consumption was correlated using the provided drilling parameters. Therefore, the emission can be successfully predicted for different well-construction scenarios, drilling technology, and related parameters. This new workflow enables the engineer to plan with sustainability objectives and determine the best overall drilling program for each project.

OnePetro

doi: 10.2118/214533-MS

SPE

SPE-214533-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country: Asia > Middle East (0.68)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Well Drilling > Well Planning (1.00)
Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
Health, Safety, Environment & Sustainability > Environment > Air emissions (1.00)

Technology: Information Technology (1.00)

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Effective Wellbore Cleaning Design, Treatment and Execution to Remove Invert Emulsion Fluids Residue in a Challenge Gas Well

Olivares, Tulio (Saudi Aramco) | Al-Zahrani, Walid (Saudi Aramco) | Hassan, Islam (MNCHEM) | Seid, Ahmed (MNCHEM)

OnePetroMay, 2023

Abstract Wellbore cleaning is a vital link between drilling operations and well completion to secure the massive time and money invested to drill the hole intervals by removing drilling fluids residues, pipe dope, and other debris from the wellbore. The well production can be sustained in the long-term by properly accomplishing this step, promoting technical and operational efficiencies. This paper presents an effective customized treatment design and successful execution of a wellbore cleaning case study. The Wellbore cleaning process is a combination of both mechanical and chemical means, a cleanout string of scraper, brush, magnets, and pill train of surfactants, and solvents are expected to retrieve debris and displace mud residues leaving the wellbore water wet, whose efficiencies can be judged through return fluids Nephelometric Turbidity Unit (NTU) and Total Suspended Solids (TSS). Since different wells vary in geometry, depths, and mud components, a custom design for the wellbore cleaning process is mandatory to guarantee satisfying treatment outputs, the design includes cleanout string parts and spacing, besides solvents and surfactants pills train additives, and volume. Extensive lab testing was performed to customize the proper wellbore cleaning design to remove inverted emulsion fluids (IEF) residues from casing and tubing in the studied challenge gas well. The casing pickling was executed with 150 barrels (bbl) of solvent and surfactant chemical cleaning Spacers containing 630 gallons (gal) of locally manufactured solvent and 378 gal of locally manufactured surfactant displacing the wellbore water with clean water. The water returns NTU and TSS of 47 and 0.03 % Solids respectively were achieved at 179 bbl after the high viscosity tail spacer of the casing pickling. The Cleanout Bottom Hole Assembly (BHA) was subsequently pulled out of the hole free from IEF residues and water wet, demonstrating the good cleaning performance of the locally formulated Chemistries. Similarly, the Tubing Pickling was executed with 54 bbl of Chemical cleaning spacer containing 990 gal of solvent. The water returns NTU and TSS of 38 and 0.02 % Solids respectively were achieved at 168 bbl after the high viscosity tail Spacer of the tubing pickling. In a conclusion, the low NTU and TSS values confirmed the effective wellbore cleaning design and treatment. In this paper, we will be presenting a custom treatment design and successful execution of a wellbore cleaning case study from a chemical perspective, using 100% locally developed chemistries, that are environmentally friendly and readily available in-country, adding the value of lead time and optimized cost to drilling operations, where selected treatments could achieve targeted return fluids NTU and TSS within competitive displacement volume for both casing and tubing.

OnePetro

doi: 10.2118/214550-MS

SPE

SPE-214550-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Asia > Middle East (0.46)
North America > United States (0.28)

Industry:

Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Well Drilling > Drilling Operations (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
Well Completion > Completion Installation and Operations > Well clean out (1.00)

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Producing Shale Oil Through Rod Free Artificial Lift, A Case Study

Chen, Qiang (RIPED, PetroChina Co. Ltd, Beijing, China) | Hao, Zhongxian (RIPED, PetroChina Co. Ltd, Beijing, China) | Huang, Shouzhi (RIPED, PetroChina Co. Ltd, Beijing, China) | Gao, Yang (RIPED, PetroChina Co. Ltd, Beijing, China) | Wei, Songbo (RIPED, PetroChina Co. Ltd, Beijing, China)

OnePetroMay, 2023

Shale oil had attracted worldwide attention due to its vast volume, according to statistics, technical recovery of shale oil worldwide exceeded 250billion ton, mostly located in America, Africa and north Asia. However shale oil was characterized by its high viscosity, deep reservoir location, posing threats to the operator, traditional rod-pump artificial lift was not a good choice due to the friction issue, How to walk out of those challenges were worth thinking, while rod free artificial lift methods had been field proven in the oilfield, its progress would give us some inspirations. In this paper, rod free artificial lift methods including downhole motivated reciprocating pump, centrifugal pump and progressing cavity pump were discussed, some technological highlights such as pulling and running electric cables, host SCADA system and production control algorism had been introduced in detail. Finally the efficacy of rodless artificial lift was analyzed from the perspective of investment

OnePetro

doi: 10.2118/214564-MS

SPE

SPE-214564-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America > United States (0.69)
Asia > China (0.48)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (1.00)
Production and Well Operations > Artificial Lift Systems > Progressing cavity pumps (1.00)
Production and Well Operations > Artificial Lift Systems > Beam and related pumping techniques (1.00)

Technology:

Information Technology > Sensing and Signal Processing (0.88)
Information Technology > Communications > Networks > Sensor Networks (0.70)

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Intelligent Direct-Drive Top Drive Design of Synchronous Permanent Magnet Motor with Phase Change Heat Dissipation

Han, Haochen. (CPET Beijing Petroleum Machinery Co., Ltd., Beijing, China / CNPC R&D, DIFC Company Limited, Dubai, UAE) | Wang, Bo. (CPET Beijing Petroleum Machinery Co., Ltd., Beijing, China) | Li, Bo. (CPET Beijing KEMBL Petroleum Technology Development Co., Ltd., Beijing, China) | Cheng, Tengfei. (CPET Beijing Petroleum Machinery Co., Ltd., Beijing, China) | Fengliu, Hui. (CNPC R&D, DIFC Company Limited, Dubai, UAE) | Zhang, Yao. (CPET Beijing Petroleum Machinery Co., Ltd., Beijing, China) | Chu, Fei. (CPET Beijing Petroleum Machinery Co., Ltd., Beijing, China)

OnePetroMay, 2023

Abstract In drilling operation, drilling NPT caused by top drive mechanical failure and high noisy and energy suffered a lot onsite. This paper introduces a top drive which utilizes a permanent magnet synchronous AC motor to drive the quill directly without a gearbox which can shorten drive chain. Meanwhile, its symmetrical and compact mechanical construction and shorter main and control cables obviously improve installation efficiency and effectively reduce the failure rate. We conducted research through structural design, motor efficiency and heat dissipation, and automation system upgrades to form a set of high-efficiency, high-performance direct drive top drive. Transmission structure aspect: design of direct-drive top drive structure, calculation and verification of main load bearing parts, analysis of top drive failure types and effects. Motor energy efficiency aspect: research on speed measurement method of permanent magnet direct drive motor, precise control method of permanent magnet direct drive motor, and closed phase change heat dissipation technology. Automation enhancement aspect: research on control system architecture, self-diagnosis system, One-click operating system. This study resulted in three research findings including synchronous permanent magnet motor design, One-Click operating system with self-diagnosis and efficient self-circulation heat dissipation technology. The new generation of direct-drive top drive can reduce current required by 100-200A and increase efficiency by 20-30% compared with asynchronous motor, while meeting the requirements of corresponding rated load, rated power, speed and continuous torque. It can realize quill rotation precision less than 1° under load and keep the speed fluctuation reduced from 10.6% to 1.1% by improving the motor dynamic response performance. The One-click control method realized by preset parameters can reduce the driller's repeated operation and visual judgment. The tripping efficiency can be increased by 11.9%, reducing the driller's operation complexity and improving drilling safety. The application of phase-change heat dissipation system can reduce ambient noise to 72dB without external circulating pump. At present, over 10 sets of this new equipment have been delivered and industrial applications have been launched in CNPC Dagang Oilfield, CNPC Weiyuan National Shale-Gas Demonstration Zone and Sinopec NiuYe Shale-Gas Demonstration Zone. Till now nearly 20 wells have been conduct with running trouble-free throughout. Intelligent direct drive top drive of synchronous permanent magnet motor with phase change heat dissipation can not only improve the top drive mechanical transmission efficiency and extend the service life of main components, but also can reduce energy consumption and improve the automation level of top drive, making the top drive further satisfy the high-demanded requirements in drilling operation. We believe that there will be a great demand in deep wells, ultra-deep wells and unconventional oil and gas resources exploitation, which has a broad application prospect and good economic and social benefits.

OnePetro

doi: 10.2118/214648-MS

SPE

SPE-214648-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Asia > Middle East > UAE (0.28)
Asia > China > Tianjin (0.24)

Industry:

Energy > Oil & Gas > Upstream (1.00)
Government > Regional Government > Asia Government > China Government (0.76)

Oilfield Places: Asia > China > Tianjin > Bohai Basin > Huanghua Basin > Dagang Field (0.99)

SPE Disciplines:

Well Drilling > Drilling Equipment (1.00)
Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)

Technology:

Information Technology > Artificial Intelligence (1.00)
Information Technology > Software (0.75)

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Study on the Drilling Performance Improvement and Risk Reduction with 3D Geomechanical Modelling in Horizontal Wells

Zhang, Junbo (Sinopec Oilfield Service Corporation Southwest, University, Chengdu, China) | Zhao, Liang (Shenzhen Hybrit Drilling Tools Ltd., Beijing, China)

OnePetroMay, 2023

Abstract The deep shale gas reservoir are high formation temperature and pore pressure in Sichuan Basin. Due to the unclear geomechanical characteristics of the reservoir, a large number of accidents occurred during the drilling operation. At the same time, the wellbore instability and frequent adjustment trajectory cause long drilling cycle, low drilling efficiency, and high drilling operation cost. To solve the above problems, the drilling mud weight is optimized based on the three-dimensional geomechanical research and by establishing the pore pressure, collapse pressure and fracture pressure (leakage pressure) models. The key technology of reducing drilling mud weight are used to significantly reduce the drilling mud loss. Field application shows that the mud weight is reduced from 2.15 g/cm to 1.87 g/cm, the average ROP increased by 44.1% from 8.4 m/h to 12.1 m/h, the average drilling operation cycle decreased by 40.7% from 54.2 days to 32.1 days, and the drilling performance and efficiency are significantly improved. The fine 3D geomechanical modeling technology has great promotion and reference significance for the performance and efficiency improvement of the deep shale gas horizontal well drilling operation in China.

OnePetro

doi: 10.2118/214614-MS

SPE

SPE-214614-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America > United States (1.00)
Asia > China > Sichuan (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > China > Sichuan > Sichuan Basin (0.99)

SPE Disciplines:

Well Drilling > Wellbore Design > Wellbore integrity (1.00)
Well Drilling > Pressure Management > Well control (1.00)
Well Drilling > Drilling Operations (1.00)
(3 more...)

Technology: Information Technology > Modeling & Simulation (0.67)

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Revolutionizing Rig Integration with Next-Generation MPD Equipment: The Pressure Management Device (PMD)

Mammadov, Elvin (Opla Energy) | Hoffarth, Dan (Citadel Drilling)

OnePetroMay, 2023

Abstract Managed Pressure Drilling (MPD) is a method of controlling wellbore pressure using specialized equipment and techniques that adjust bottom hole pressure in real time. It can be performed with automated or semi-automated systems and trained field personnel, including operators or rig crew. When MPD systems are integrated into drilling rig operations, benefits of MPD systems and processes can be achieved but can be complex. This includes installing equipment, training personnel, and creating policies and procedures. Integrating MPD into a drilling rig has always been challenging due to the timing of rig in and out operations, diversity in MPD equipment, and required of training rig crew to operate MPD equipment or having MPD personnel on site. Automated MPD has also been difficult to integrate and enable the rig crew to run due to the complexity of managing the MPD software. Drilling contractors will continue to be reluctant to carve out additional bandwidth requirements of their rig personnel to deliver MPD in addition to their main scope, as leads to task saturation and creates safety and operational concerns. Ultimately, the term when there is a requirement or expectation of additional or extra labor to operate any equipment is "mechanized" and referring to such a process as "automated" is incorrect. Effective rig integration is crucial for the MPD industry to achieve performance drilling with a proactive MPD approach. Developed under the guidance of experienced super spec drilling rig contractors, The Pressure Management Device (PMD), offers a level of MPD and rig integration not yet experienced by industry while addressing the historical drawbacks, such as manual or mechanized controls, task saturation or additional time & labor burdens for rig crews or the need for an MPD subject matter expert (SME) on site. The PMD™ combines all MPD methods into a single device, eliminating the need for repeated rig in and rig out operations while providing autonomous pressure control without requiring any additional personnel on-site after initial rig up. Incorporating Internet of Things (IoT) and artificial intelligence (AI) technologies, the PMD™ continuously monitors and adjusts pressure conditions in real time. Recognizing that many MPD failures are a result of operator (human) error, this advanced automation allows for seamless integration into existing rig operations which enables the use of MPD techniques without any additional burden on rig personnel or the need for specialized expertise to be on-site. PMD™ additionally provides a significantly reduced equipment complement and footprint that results in more cost-effective transportation, reduced HSE exposure and greater operational efficiencies. Overall, the PMD™ represents multiple major advancements in MPD rig integration offering an effective and efficient solution for drilling operations. With over 90% of traditional piping being eliminated, PMD™ additionally provides a significantly reduced equipment requirements enabling fast and safe handling. In pad drilling applications, and many other scenarios, there is no need to rig out the PMD during well-to-well walks or rig moves. This paper compares traditional MPD to PMD™ performance from a rig integration perspective, focusing on the drawbacks of traditional MPD and how PMD™ addresses them with its patented new technologies, including AI and ML-based software automation and advanced automated systems in a redesigned version of next-generation MPD equipment. It serves as a comprehensive guide for future MPD land and offshore rig integration and outlines the steps to optimize performance with MPD techniques.

OnePetro

doi: 10.2118/214552-MS

SPE

SPE-214552-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

annular pressure drilling, Artificial Intelligence, automation, drilling operation, Efficiency, integration, intervention, managed pressure drilling, MPD, operator, personnel, Petroleum Engineer, PMD, pressure management device, real time system, rig integration, software, survey article, united states government, Upstream Oil & Gas

Country: North America > United States (0.28)

Genre: Overview (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Well Drilling > Pressure Management > Managed pressure drilling (1.00)
Well Drilling > Drilling Operations (1.00)

Technology:

Information Technology > Artificial Intelligence (1.00)
Information Technology > Architecture > Real Time Systems (0.70)

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Advance Milling and Cutting Structure Development and Implementation to Reduce Well Abandonment Cost for Major Operators

Khan, Muhammad Zafar (Wellbore Integrity Solutions, Houston, TX, USA) | Swadi, Shantanu (Wellbore Integrity Solutions, Houston, TX, USA) | Solorzano, Efrain (Wellbore Integrity Solutions, Houston, TX, USA)

OnePetroMay, 2023

Abstract Decommissioning of end-of-life wells is an essential operation in the lifecycle of a well and requires thorough planning and execution. The plug and abandonment of the wells contribute over 45% of the overall decommission costs and hence there is a clear mandate from the operators and service companies to offer new technologies and solutions to reduce the overall decommissioning costs. The service company has been working with several operators to provide casing cutting and casing milling operations. The aim is to provide the most efficient and cost-effective method to perform the plug and abandon operations for a given well especially in the casing removal and recovery operations which in turn provides rig time savings. Some of the major operations are involved in section milling the casing, removal of large casing conductors or triple casing cuts by the pipe cutter, and subsea wellhead removals. The service company has designed an advanced cutting structure technology to facilitate the milling and casing cutting operations and provide a reliable, durable, and efficient milling solution for well abandonment. The new cutting structure provides reduced cut times and/or a longer useful cutting life to cut large dual casing conductors such as 20″x30″ or 22″x36″ during the conductor recovery phase or the wellhead recovery phase. Similarly, the advanced cutting structure is designed to efficiently mill extended casing sections, especially for high grade casings with higher ROP and lower downtime (rate of penetration) during the milling operation. The development efforts started with an evaluation of the current cutter designs and shortcomings. After an assessment of the field performance and dull characteristics, it was evident that high shock and vibration loading during the downhole operation results in excessive and premature impact damage leading to sub-optimal cutter geometry for cutting steel. Likewise, bird-nesting of swarf was also a common source of NPT due to the interruptions in operations for breaking up and clearing the swarf periodically, before milling commenced again. Several competing concepts for insert shapes were considered and analyzed. Improving the edge strength was considered as a key attribute. As well as the ability to break-up swarf into smaller segments for efficient transportation. Modelling and simulation, and physical testing helped narrow down to a few concepts for full scale lab tests, and eventually to select the most promising concept for field tests. The new advanced cutting structure has been 100% successful in multiple challenging applications of casing cutting and milling operations in the North Sea and is being implemented in Middle East and Asia. Improvements in the conductor cutting time has resulted in record recovery of the subsea well heads. Likewise, for section milling applications – record ROPs and longer intervals have been achieved for high grade casing such as P110. The technology demonstrates how the material behaves in downhole cutting operation and what further development can be made to further enhanced the efficiency, reduce rig time and wells decommissioning cost.

OnePetro

doi: 10.2118/214584-MS

SPE

SPE-214584-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Europe > Netherlands > North Sea (0.35)
Europe > United Kingdom > North Sea (0.25)
Europe > Norway > North Sea (0.25)
Europe > Denmark > North Sea (0.25)

Genre: Overview > Innovation (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Europe > United Kingdom > North Sea (0.89)
Europe > Norway > North Sea (0.89)
Europe > Netherlands > North Sea (0.89)
Europe > Denmark > North Sea (0.89)

SPE Disciplines:

Production and Well Operations > Well Decommissioning (1.00)
Well Drilling > Casing and Cementing > Casing design (0.69)
Well Drilling > Wellhead Design > Subsea wellheads (0.55)

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Collaborating Authors

Efficiency

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A Hybrid Physical and Machine Learning Model to Diagnose Failures in Electrical Submersible Pumps

Enzyme-Based Cleanup Fluid for High Temperature Filtercake Removal Applications

Estimating Drilling Emissions Footprint in a Cloud-Based Well-Construction Planning Solution

Effective Wellbore Cleaning Design, Treatment and Execution to Remove Invert Emulsion Fluids Residue in a Challenge Gas Well

Producing Shale Oil Through Rod Free Artificial Lift, A Case Study

Intelligent Direct-Drive Top Drive Design of Synchronous Permanent Magnet Motor with Phase Change Heat Dissipation

Study on the Drilling Performance Improvement and Risk Reduction with 3D Geomechanical Modelling in Horizontal Wells

Revolutionizing Rig Integration with Next-Generation MPD Equipment: The Pressure Management Device (PMD)

Advance Milling and Cutting Structure Development and Implementation to Reduce Well Abandonment Cost for Major Operators

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