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Summary The hydraulic effects on torque and drag modeling have been thoroughly studied in the past, yet their interpretation still causes a lot of misunderstandings and confusion. Historical models disregard the circulation effects and focus on the fluid mass by employing buoyancy forces based on the Archimedes principle. On the other hand, the reference model including the fluid circulation effects, introduced by R. F. Mitchell in the 1990s, consists in computing the forces due to internal and external fluids along the drillstring. The first type of model (called the Archimedes method) directly produces an effective tension, while the second one (generally called the pressure area method) produces a true tension that must be further transformed to obtain the effective tension. These different forms of tensions add even more confusion. By returning to the basic equations of the fluid effects on the drillstring, an equivalency between Archimedes and pressure area models has been found for the case with no circulation. Furthermore, with the same principle, an Archimedes-like model is deduced for the case of fluid circulation, where the effects of fluid pressures, frictions, and flows could be more easily interpreted. These two hydraulic models, after implementation in a true stiff-string 3D model, enable them to fairly compare the two approaches in terms of forces applied on the structure. The comparison of this Archimedes formulation with pressure area model gave sensibly the same results for various scenarios, proving the equivalency of the two approaches even with the case of circulating fluid. In addition to the model-to-model comparisons, torque and drag results are compared to field experiments at different depths. The flow rate was varied while reciprocating the drillstring up and down, and the hookload was recorded for each flow rate and each tripping direction. The model-to-data comparisons showed a good agreement between the theoretical results and experimental data. An advanced Archimedes method with all fluid circulation effects has been developed. By tackling the problem of circulating fluid in the drillstring using two different approaches and proving their equivalency, a better understanding of the hydraulic effects can be achieved, which in terms can help settle the possible debates and confusion that might arise by drilling engineers.
- North America > United States (1.00)
- Europe (0.93)
- Well Drilling > Drillstring Design > Torque and drag analysis (1.00)
- Well Drilling > Drilling Fluids and Materials (1.00)
- Well Drilling > Drilling Equipment (1.00)
IADC Code Upgrade: Data Collection and Workflow Required to Conduct Bit and BHA Forensics to Create Effective Changes in Practices or Design
Watson, William (Shell) | Dupriest, Fred (Robert Gordon University (Corresponding author)) | Witt-Doerring, Ysabel (Texas A&M University) | Sugiura, Junichi (Halliburton) | Pastusek, Paul (Sanvean Technology) | Daechsel, Dustin (Exxon) | Abbas, Raafat (Shell) | Shackleton, David (Chevron) | Amish, Mohamed (Independent Data Services)
Summary This paper introduces a forensic workflow that can be used to link drill-bit and bottomhole assembly (BHA) damage to drilling dysfunction. This paper will also discuss the data that should be collected and how it should be processed to enable operational practices and engineering design changes to address these issues. There is a vast amount of data collected in all drilling operations that can be used to improve performance if utilized within an effective forensic workflow. Several drilling forensic case studies were developed and critically reviewed by subject matter experts from across the industry. From the causal analysis for each case study, an assessment was performed on what information was (1) available, (2) required to diagnose the cause, and (3) not available but would have been preferred. The way the team communicated and acted on the data was also documented. By combining the learnings from these case studies, it was observed that a guided approach can improve data collection and lead to a more consistent, accurate, timely, and causal analysis with appropriate remedial actions. The process discussed within has been refined to support data collection for forensic analysis and provides a reference for field- and office-based drilling professionals. These practical guidelines have been developed to offer a foundation for a drilling forensic data collection methodology as well as training for the industry—they have been created such that they can grow organically and will form part of the International Association of Drilling Contactors (IADC) Bit Dull Grading Recommended Practice to support the IADC dull grade manual. In the future, these can be used for developing subsequent industry publications. The work described in this paper is part of a joint IADC/Society of Petroleum Engineers industry effort to revise the IADC dull grade manual.
- North America > United States > Texas (0.95)
- Europe (0.93)
- Geology > Geological Subdiscipline > Geomechanics (0.93)
- Geology > Rock Type (0.68)
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > New Mexico > Permian Basin > Delaware Basin (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field (0.99)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 95 > Meta Field (0.93)
Real-Time Underreamer Vibration Predicting, Monitoring, and Decision-Making Using Hybrid Modeling and a Process Digital Twin
Shi, Jibin (Schlumberger (Corresponding author)) | Dourthe, Laetitia (Schlumberger) | Li, Denis (Schlumberger) | Deng, Li (Schlumberger) | Louback, Leonardo (Schlumberger) | Song, Fei (Schlumberger) | Abolins, Nick (Schlumberger) | Verano, Fernando (Schlumberger) | Zhang, Pusheng (Schlumberger) | Groover, Joshua (Schlumberger) | Gomez Falla, Diego (Schlumberger) | Li, Ke (Schlumberger)
Summary In hole enlargement while drilling (HEWD) operations, underreamers are used extensively to enlarge the pilot hole. Reamer wipeout failure can cause additional bottomhole assembly (BHA) trips, which can cost operators millions of dollars. Excessive reamer shock and vibration are leading causes of reamer wipeout; therefore, careful monitoring of reamer vibration is important in mitigating such a risk. Currently, downhole vibration sensors and drilling dynamics simulations (DDSs) are used to comprehend and reduce downhole vibration, but vibration sensors cannot be placed exactly at the reamer to monitor the vibrations in real time. DDSs are difficult to calibrate and are computationally expensive for use in real time; therefore, the real-time reamer vibration status is typically unknown during drilling operations. A process digital twin using a hybrid modeling approach is proposed and tested to address the vibration issue. Large amounts of field data are used in advanced DDSs to calibrate the HEWD runs. For each HEWD section, calibrated DDSs are performed to comprehend the downhole vibration at the reamer and downhole vibration sensors. A surrogate regression model between reamer vibration and sensor vibration is built using machine learning. This surrogate model is implemented in a drilling monitoring software platform as a process digital twin. During drilling, the surrogate model uses downhole measurement while drilling (MWD) data as inputs to predict reamer vibration. Wipeout risk levels are calculated and sent to the operators for real-time decision-making to reduce the possibility of reamer wipeout. Large volumes of reamer field data, including field recorded vibration and reamer dull conditions were used to validate the digital twin workflow. Then, the process digital twin was implemented and tested in two reamer runs in the Gulf of Mexico. A downhole high-frequency sensor was placed 8 ft above the reamer cutting structure in one field run, and the recorded sensor vibration data and corresponding reamer dull conditions showed a very good match with the real-time digital twin predictions in a low-vibration scenario. Cases in high vibration are needed to fully validate the feasibility and accuracy of the digital twin. State-of-the-art downhole sensors, DDS packages, large amounts of field data, and a hybrid approach are the solutions to building, calibrating, and field testing the reamer digital twin to ensure its effectiveness and accuracy. Such a hybrid modeling approach can not only be applied to reamers but also to other critical BHA components.
- Europe (1.00)
- Asia (1.00)
- North America > United States > Texas (0.69)
Study on Fatigue Behavior of S135 Steel and Titanium Alloy Drillpipes: Experiment and Modeling
Peng, Xianbo (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University (Corresponding author)) | Yu, Hao (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University (Corresponding author)) | Lian, Zhanghua (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Liu, Tao (Engineering Technology Research Institute, PetroChina Xinjiang Oilfield Company) | Shi, Junlin (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Yang, Dongchuan (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University)
Summary This paper studies the fatigue failure behavior of S135 steel and titanium alloy drillpipe, tries to reveal the mechanism of fatigue fracture, and evaluates the degree of fatigue damage. First, the chemical composition, tensile test, and microstructure analysis of two types of pipes were carried out, and the difference in microstructure affects its macroscopic fatigue performance. Second, the stress vs. fatigue life (SN) curve equation and fatigue limit of S135 steel and titanium alloy drillpipes in air and mud were obtained through the fatigue test. Scanning electron microscope analysis results show that the S135 steel drillpipe presents brittle fracture, while titanium alloy drillpipe presents mixed fracture of quasi-cleavage and dimple. Finally, a case study of actual horizontal well was carried out to evaluate the fatigue damage of two drillpipes; compared with conventional steel drillpipe, titanium alloy drillpipe can effectively resist fatigue damage in the drilling fluid environment. The fatigue test results and corrosion fatigue mechanism analysis in this paper can provide data and theoretical guidance for the study of drillpipe fatigue life. Introduction Oil and gas wells with ultradeep, large displacement, short radius, and long horizontal section have progressively drawn the industry's attention for exploration and drilling activities to meet the rapid increase in global energy consumption (Eren and Polat 2020). These complex track wells greatly improve the capacity efficiency of oilfield companies and bring considerable economic benefits.
- Asia (1.00)
- North America > United States (0.93)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
Standardization of Mechanical Specific Energy Equations and Nomenclature
Dupriest, Fred (Texas A&M University (Corresponding author)) | Lai, Stephen (Pason Systems) | Behounek, Michael (Apache Corporation) | Pastusek, Paul (ExxonMobil Upstream Integrated Solutions Company) | Cutts, Chris (K&M Technology Group) | Best, Bob (Pason Systems) | Cook, Bryan (National Oilwell Varco) | Bassarath, Wendell (Contractor) | Collins, Jared (Occidental Petroleum Corp) | Kamyab, Mohammedreza (Corva) | Moore, Dennis (Marathon Oil (retired)) | Pulpan, Eric (Marathon Oil) | Jeske, Austin (Pioneer Natural Resources) | Wilson, JJ (Pioneer Natural Resources) | Sheets, Jamie (Ensign Energy)
Summary This paper recommends standardized names and equations for the two most common uses of mechanical specific energy (MSE) concepts: “total MSE” and “downhole MSE.” These names and their equations should be used uniformly in all applications, including electronic drilling recorder (EDR) picklists, rigsite surveillance, engineering surveillance, data analytics, research, and technical publications. MSE, used as a metric for drilling efficiency, is a mathematical calculation of the energy used per volume of rock drilled. The downhole MSE equation calculates the efficiency of the bit alone, while the total MSE equation includes both the bit and drillstring. Those who use MSE in surveillance or analytics know the negative effects created by the lack of standardization over the years; it is certainly not a new problem. The lack of standardized nomenclature has resulted in the use of the same name for different equations, or different names are given for two equations that are identical. This affects the ability of drill teams to engage vendors in the redesigning of performance limitations or to communicate new operational practices between teams and rigs. In addition to standardizing nomenclature, this document corrects a mathematical error that is common in calculating the total MSE. The concern with the inconsistencies has increased as MSE has become a key element in many automated optimization schemes. Inconsistencies or uncertainties in the basis of MSE values calculated in real time or shared in large data sets will affect the industry’s ability to develop useful analytics or to automate rig control platforms and data-driven decisions. This paper also includes a discussion of the MSE measurement errors and their effect on calculated values, which is of particular interest to controls engineers and those involved in data analytics. Examples are provided to illustrate how the two different MSE values are used in field operations. Also, a substantial list of current and potential future uses of MSE is included to encourage better MSE-based practices to potentially lead to the development of new uses in the future, including automation. This ad hoc MSE Standardization Committee is a volunteer group with representation from operators, rig contractors, service companies, and data acquisition vendors. The guidance given reflects their shared experience in utilizing MSE in surveillance and analytics, and the recommended equations are technically correct.
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > New Mexico > Permian Basin > Delaware Basin (0.99)
- Information Technology > Data Science (1.00)
- Information Technology > Architecture > Real Time Systems (0.49)
Analysis of Whirl Characteristics of Drill String Under Multidirectional Coupling Conditions
Tian, Jialin (School of Mechanical Engineering, Southwest Petroleum University.) | Xiong, Changqing (School of Mechanical Engineering, Southwest Petroleum University.) | Fan, Changyue (School of Mechanical Engineering, Southwest Petroleum University.) | Guo, Linpeng (School of Mechanical Engineering, Southwest Petroleum University.) | Liu, Chenghang (School of Mechanical Engineering, Southwest Petroleum University.)
Summary The nonlinear contact between the bottomhole assembly (BHA) and the borehole can cause backward whirl. During an actual drilling process, the backward whirl will increase wear of the downhole drilling tool and lead to bending or even bulking failure. Therefore, analyzing the drillstring whirl characteristics considering multidirectional coupling effects, combined with field conditions, is a key issue and research hotspot. In this paper, considering the relationships between axial, torsional, and lateral vibrations of the drillstring system, the whirl model is established with finite element method. Research results indicate that with higher driving speed and larger friction coefficient between drillstring and borehole wall, the drillstring lateral vibration changes from forward to backward whirl. On the contrary, the increasing of drilling fluid density can effectively suppress the occurrence of backward whirl. As drilling fluid density increases, forward and backward whirl coexist, and only the forward whirl occurs at last. The research results can provide a basis for formulating whirl control strategy, and promoting the efficient and safe operations of drilling engineering.
Study on Fatigue Behavior of S135 Steel and Titanium Alloy Drillpipes: Experiment and Modeling
Peng, Xianbo (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University (Corresponding author)) | Yu, Hao (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University (Corresponding author)) | Lian, Zhanghua (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Liu, Tao (Engineering Technology Research Institute, PetroChina Xinjiang Oilfield Company) | Shi, Junlin (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Yang, Dongchuan (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University)
Summary This paper studies the fatigue failure behavior of S135 steel and titanium alloy drillpipe, tries to reveal the mechanism of fatigue fracture, and evaluates the degree of fatigue damage. First, the chemical composition, tensile test, and microstructure analysis of two types of pipes were carried out, and the difference in microstructure affects its macroscopic fatigue performance. Second, the stress vs. fatigue life (SN) curve equation and fatigue limit of S135 steel and titanium alloy drillpipes in air and mud were obtained through the fatigue test. Scanning electron microscope analysis results show that the S135 steel drillpipe presents brittle fracture, while titanium alloy drillpipe presents mixed fracture of quasi-cleavage and dimple. Finally, a case study of actual horizontal well was carried out to evaluate the fatigue damage of two drillpipes; compared with conventional steel drillpipe, titanium alloy drillpipe can effectively resist fatigue damage in the drilling fluid environment. The fatigue test results and corrosion fatigue mechanism analysis in this paper can provide data and theoretical guidance for the study of drillpipe fatigue life. Introduction Oil and gas wells with ultradeep, large displacement, short radius, and long horizontal section have progressively drawn the industry's attention for exploration and drilling activities to meet the rapid increase in global energy consumption (Eren and Polat 2020). These complex track wells greatly improve the capacity efficiency of oilfield companies and bring considerable economic benefits.
- Asia (1.00)
- North America > United States (0.93)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
Standardization of Mechanical Specific Energy Equations and Nomenclature
Dupriest, Fred (Texas A&M University (Corresponding author)) | Lai, Stephen (Pason Systems) | Behounek, Michael (Apache Corporation) | Pastusek, Paul (ExxonMobil Upstream Integrated Solutions Company) | Cutts, Chris (K&M Technology Group) | Best, Bob (Pason Systems) | Cook, Bryan (National Oilwell Varco) | Bassarath, Wendell (Contractor) | Collins, Jared (Occidental Petroleum Corp) | Kamyab, Mohammedreza (Corva) | Moore, Dennis (Marathon Oil (retired)) | Pulpan, Eric (Marathon Oil) | Jeske, Austin (Pioneer Natural Resources) | Wilson, JJ (Pioneer Natural Resources) | Sheets, Jamie (Ensign Energy)
Summary This paper recommends standardized names and equations for the two most common uses of mechanical specific energy (MSE) concepts: “total MSE” and “downhole MSE.” These names and their equations should be used uniformly in all applications, including electronic drilling recorder (EDR) picklists, rigsite surveillance, engineering surveillance, data analytics, research, and technical publications. MSE, used as a metric for drilling efficiency, is a mathematical calculation of the energy used per volume of rock drilled. The downhole MSE equation calculates the efficiency of the bit alone, while the total MSE equation includes both the bit and drillstring. Those who use MSE in surveillance or analytics know the negative effects created by the lack of standardization over the years; it is certainly not a new problem. The lack of standardized nomenclature has resulted in the use of the same name for different equations, or different names are given for two equations that are identical. This affects the ability of drill teams to engage vendors in the redesigning of performance limitations or to communicate new operational practices between teams and rigs. In addition to standardizing nomenclature, this document corrects a mathematical error that is common in calculating the total MSE. The concern with the inconsistencies has increased as MSE has become a key element in many automated optimization schemes. Inconsistencies or uncertainties in the basis of MSE values calculated in real time or shared in large data sets will affect the industry’s ability to develop useful analytics or to automate rig control platforms and data-driven decisions. This paper also includes a discussion of the MSE measurement errors and their effect on calculated values, which is of particular interest to controls engineers and those involved in data analytics. Examples are provided to illustrate how the two different MSE values are used in field operations. Also, a substantial list of current and potential future uses of MSE is included to encourage better MSE-based practices to potentially lead to the development of new uses in the future, including automation. This ad hoc MSE Standardization Committee is a volunteer group with representation from operators, rig contractors, service companies, and data acquisition vendors. The guidance given reflects their shared experience in utilizing MSE in surveillance and analytics, and the recommended equations are technically correct.
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > New Mexico > Permian Basin > Delaware Basin (0.99)
- Information Technology > Data Science (1.00)
- Information Technology > Architecture > Real Time Systems (0.49)
Summary This work presents a method to move a vertical drillstring off-bottom in a given time without exciting the torsional vibrations. The control algorithm was originally developed for robots with flexible arms, and it is here applied to a long drillstring. The control strategy consists of calculating a feedforward torque based on the modal characteristics of the drillstring. The approach presented can be used to change the downhole orientation or to bring the drillstring to a stable rotational speed without residual vibrations before drilling is started. Numerical examples are presented for both displacement and velocity control strategies. Introduction A drillstring is a long sequence of interconnected pipes used to drill a borehole for hydrocarbons or geothermal exploration and production.
- Well Drilling > Drillstring Design > Torque and drag analysis (1.00)
- Well Drilling > Drillstring Design > Drillstring dynamics (1.00)
- Well Drilling > Drilling Equipment (1.00)
Summary Appropriate selection of a bottomhole assembly (BHA) is critical to the success of a drilling operation. In US land drilling, these assemblies are often selected using local heuristics rather than rigorous analysis. These heuristics are frequently derived from the incentives of the directional contractor as opposed to incentives for the operator. Large motor bends enable more rotation through the curve and reduce the possibility of tripping for build rates. Unstabilized motors are believed to aid sliding and tool face control. Both of these practices lead to drilling a more tortuous wellbore and may cause problems later in the well’s life. This study quantifies the impact of these practices and proposes alternatives that can balance the needs of directional companies with the desire of operators for high-quality wellbores. More than 60 conventional motor assemblies used to drill curves in the Eagle Ford and Permian basins were analyzed for directional performance using commercial drillstring analysis software. The sliding and rotary tendencies were modeled through the curve across a range of potential drilling conditions. Expected build-rate models were validated by comparison to the maximum achieved doglegs in the directional surveys. When available, additional validation was performed using motor yields calculated from slide sheets. The validated models were compared to the dogleg severity (DLS) requirements for each assembly’s respective well plan. Comparisons of slide ratios and slide/rotate tendencies of the BHAs were used to estimate the impact on wellbore quality using the tortuosity metric proposed by Jamieson (2019). Typical well plans for both basins had curves of 10° per 100 ft with no well plan greater than 12° per 100 ft. Typical BHAs were capable of >15° per 100 ft under normal sliding conditions, with some assemblies capable of >20° per 100 ft of build. Predicted build rates were validated by slide sheets and observed DLSs. Common characteristics among assemblies with excess capacity were high-bend angles (≥2°) and minimal stabilization. These understabilized assemblies exhibited unstable rotary tendencies across a range of drilling parameters. The combination of high-build rates with rotary drop masks the true level of tortuosity in a wellbore, leading to an underestimation of unwanted curvature. A minority of the assemblies used a lower motor bend angle (<2°) combined with multiple stabilizers. These assemblies had a more consistent directional capability throughout the curve and exhibited stable behavior in rotation. The success of these assemblies confirms that there is potential for tailoring BHA designs to improve wellbore quality without compromising the technical objectives of the well. As increasing attention is afforded to the topic of wellbore quality, it is important to have methods available to technically achieve high-quality wellbores. In addition to the management of drilling practices, it is also important to have an appropriate BHA design that can enable those practices
- North America > United States > Texas > Permian Basin > Yeso Formation (0.94)
- North America > United States > Texas > Permian Basin > Yates Formation (0.94)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.94)
- (24 more...)
- Well Drilling > Drillstring Design (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)