Mitigating Twist-Offs While Drilling with the Help of BHA Dynamics Software

2021 ◽  
Author(s):  
Mario A. Rivas ◽  
Andres A. Ramirez ◽  
Bader S. Al-Zahrani ◽  
Khaled K. Abouelnaaj
Keyword(s):  
Oil And Gas ◽  
Drill Pipe ◽  
Oil And Gas Industry ◽  
Parameters Optimization ◽  
Gas Industry ◽  
Drilling Parameters ◽  
Resonance Vibrations ◽  
Bottom Hole Assembly ◽  
Drilling Operations ◽  
Safe Operating

Abstract One of the major challenges the Oil and Gas Industry faces nowadays during drilling operations is the twist-offs on Bottom Hole Assembly (BHA) components such as Drilling Jars, Shock Tools, Mud Motors, Roller Reamers, Stabilizers, Drill Collars, PBLs, Heavy Weight Drill Pipe (HWDP), Drill Pipe (DP), etc. To overcome this challenge, an initiative was proposed by performing a study based on twist-offs experienced on BHA components while drilling operations and recommendations are provided to reduce and eliminate twist-offs related to drilling with suboptimal drilling parameters. The statistical data for the twist-off events was collected coming from Daily Drilling Reports, and the analysis was limited to all wells which presented twist-offs on the drillstring and BHA components. Three examples of twist-offs due to drilling with erratic torque are discussed as well as a successful example of drilling parameters optimization. The three examples which presented drillstring and BHA twist-offs were analyzed using available BHA Dynamics and vibrations software and it was discovered that the parameters utilized (operational RPM) fell within the critical zone shearing force peaks (resonance vibrations). The components with the most twist-offs were identified. The hole size where we have the most twist-offs were also identified, which will help in focusing on these areas for the recommendations provided. This analysis will help Drilling Engineers and Foremen to foresee vibration dysfunctions and act accordingly by the use of available BHA Dynamics software in order to optimize drilling parameters before and during drilling. By drilling within a safe operating RPM window (away from resonant RPM), there will be reduction in the number of twist-offs and associated lost time.

RAM analysis of dynamic positioning system: An approach taking into account uncertainties and criticality equipment ratings

2021 ◽  
pp. 1748006X2110518
Author(s):  
Maria V Clavijo ◽  
Adriana M Schleder ◽  
Enrique Lopez Droguett ◽  
Marcelo R Martins
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Economic Losses ◽  
Gas Industry ◽  
Dynamic Positioning System ◽  
Failure Data ◽  
Total Failure ◽  
Drilling Operations ◽  
Maintainability Analysis ◽  
Ram Analysis

Currently, a Dynamic Position (DP) System is commonly used for offshore operations. However, DP failures may generate environmental and economic losses; thus, this paper presents the Reliability, Availability and Maintainability (RAM) analysis for two different generations of DP system (DP2 and DP3) used in drilling operations. In addition to the RAM analysis, the approach proposed herein considers the uncertainties present in the equipment failure data and provides more information about criticality equipment ratings and probability density functions (pdf) of the repair times. The reliability analysis shows that, for 3 months of operation, the total failure probability of the DP2 system is 1.52% whereas this probability for the DP3 system is only 0.16%. The results reveal that the bus-bar is the most critical equipment of the DP2 system, whereas the wind sensor represents the priority equipment in the DP3 system. Using 90% confidence level, each DP configuration was evaluated for a 1-year operation, finding a reliability mean equal to 70.39% and 86.77% for the DP2 system and the DP3 system, respectively. The DP2 system asymptotic availability tends to present a constant value of 99.98% whereas for the DP3 system, it tends to be 99.99%. Finally, the maintainability analysis allows concluding that the mean time for system repair is expected to be 3.6 h. This paper presents a logical pathway for analysts, operators, and reliability engineers of the oil and gas industry.

An Analytical Framework for Resilience Exemplified With a Real-Time Operational Center

2019 ◽  
Vol 6 (1) ◽  
Author(s):  
Grethe O. Ose ◽  
Trygve J. Steiro
Keyword(s):  
Change Process ◽  
Oil And Gas ◽  
Data Gathering ◽  
Oil And Gas Industry ◽  
Analytical Framework ◽  
Gas Industry ◽  
Drilling Operations ◽  
Pros And Cons ◽  
Integrated Operations ◽  
Technological Opportunities

Abstract Integrated operations (IO) is an ongoing change process in the oil and gas industry. New technological opportunities enable working in new ways that involve an integration of onshore and offshore personnel. This paper analyzes the results of two rounds of data gathering in an onshore drilling support center, in terms of the development of resilience. The first round took place in 2004/2005 and the second in 2012. This study presents a framework for the analysis of resilience and has used the case company as a mean of testing the framework. Our findings indicate that the support center has taken a huge step in the direction of becoming more resilient. The drilling company has tested a number of designs and sizes of support centers, each of which has different pros and cons. For the drilling discipline to develop resilience, it is essential that the number of rigs supported by a center is not too large, as they must not become involved in too many rigs and drilling operations. Our findings also indicate that the suggested framework provides a good overall picture of the development of resilience in the case company.

Logic Sequence Prevents Launching Devices Downhole Out of Sequence

2014 ◽  
Author(s):  
Ricardo de Lepeleire ◽  
Nicolas Rogozinski ◽  
Hank Rogers ◽  
Daniel Ferrari
Keyword(s):  
Latin America ◽  
Oil And Gas ◽  
New Technology ◽  
Specific Area ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Logic Control ◽  
Drilling Operations ◽  
Common Operation ◽  
Increasing Demand

Within the oil and gas industry, significant costs are often incurred by the operating company during the well-construction phase of drilling operations. Specifically, the operators cost to drill a well can cost tens or hundreds of millions of USD. One specific area where significant changes in drilling operations have occurred is in the offshore environment, specifically operations from mobile offshore drilling units (MODUs). With the ever-increasing demand for oil and gas, operators globally have increased drilling budgets in an effort to meet forecasted demand. However, the increased budgets are often eroded or offset by increasing drilling costs. Therefore, operators are continually in search of new technology, processes, or procedures to help improve drilling operations and overall operational efficiencies. One Latin America operator identified a common operation as a possible area where operational cost could be easily reduced through the implementation of systems that allow the manipulation of valve manifolds remotely. Additionally, operating such valve manifolds remotely enhanced operational safety for personnel, which was an equally important consideration. This paper details the evaluation of existing equipment and procedures and a process used to develop a new remote-control system using a machine logic control (MLC) that has been designed, built, tested, and deployed successfully on MODUs operating in Latin America.

Characterization of barite reserves in Nigeria for use as weighting agent in drilling fluid

2021 ◽  
Vol 11 (5) ◽  
pp. 2157-2178
Author(s):  
David Oluwasegun Afolayan ◽  
Adelana Rasak Adetunji ◽  
Azikiwe Peter Onwualu ◽  
Oghenerume Ogolo ◽  
Richard Kwasi Amankwah
Keyword(s):  
Specific Gravity ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Chemical Properties ◽  
Oil And Gas Industry ◽  
American Petroleum Institute ◽  
Gas Industry ◽  
Cu Content ◽  
Hardness Scale ◽  
Drilling Operations

AbstractSuccessful drilling operations are dependent on the properties of the drilling fluid used to drill wells. Barite is used as a weighting agent during the preparation of drilling fluid. Over the years, oil and gas industry in Nigeria has been depending mainly on imported barite for drilling operations, whereas the country has huge deposits of barite. There is the need to assess the properties of the locally sourced barite for their suitability in drilling fluid formulation. This study presents the local processing methods of barite and examines the crude and on-the-site processed barite’s physio-chemical properties. These parameters were compared with American Petroleum Institute and Department of Petroleum Resources standards. XRD results show that on-the-site beneficiated barite has 87.79% BaSO4, 6.66% silica, 0.03% total soluble salt, 1.39% Fe2O3, and 1.603% heavy metals. Chemical analysis indicated that the pH, moisture content, metallic content such as Ca, Pb, Zn, Mg, Cu, and Cd minerals, and extractable carbonates were within the standard specified for usage as a drilling fluid weighting agent. The analysed crude barite samples were basic, within the pH of 8.3 and 8.6. Locally processed barite has lower Fe, Pb, Cd, and Cu content compared to industrially accepted barite. The specific gravity increased from 4.02 ± 0.07 to 4.15 ± 0.13, and the hardness reduced potentially from 5 Mohr to 3.5 Mohr on the hardness scale. The amount of impurities was sufficiently low, and the specific gravity of the samples improved to meet the needs of any drilling operation and compare favourably with industrially accepted barite.

scholarly journals High Rate and High Temperature Fracture Behaviour of Polycrystalline Diamond

2011 ◽  
Vol 488-489 ◽  
pp. 670-673 ◽  
Author(s):  
Marin Petrović ◽  
Alojz Ivanković ◽  
Neal Murphy
Keyword(s):  
Oil And Gas ◽  
Cutting Tools ◽  
Polycrystalline Diamond ◽  
Oil And Gas Industry ◽  
High Rate ◽  
Full Potential ◽  
Metallic Materials ◽  
Gas Industry ◽  
Drilling Operations ◽  
Temperature Fracture

Polycrystalline diamond (PCD) materials have a variety of applications, mainly as cutting tools for machining non-ferrous metals and non-metallic materials. A significant application of PCD is in oil and gas industry for rock drilling operations. Other important areas, such as mining, have yet to reach their full potential. These cutters/tools are subjected to high operating temperatures, impact loads and abrasive wear during these operations, which may lead to their sudden failure. An advantage of these materials is that their structure and composition can be engineered to return properties required for specific applications and operations.

Comprehensive Instrumentation of Two Offshore Rigs for Wellhead Fatigue Monitoring

2017 ◽  
Author(s):  
Svein Herman Nilsen ◽  
Massimiliano Russo ◽  
Guttorm Grytøyr
Keyword(s):  
Real Time ◽  
Structural Integrity ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Quality Data ◽  
Risk Level ◽  
Gas Industry ◽  
Accuracy Requirement ◽  
Fatigue Monitoring ◽  
Drilling Operations

Over the last decades, the complexity and duration of offshore drilling operations have steadily increased. The size and weight of the risers and BOP stack has grown significantly. These factors have led to an increase in fatigue loads imposed on the wellhead structures during drilling and completion operations. Wellhead fatigue might ultimately lead to loss of well structural integrity and pressure containment and therefore safe and reliable drilling of subsea wellheads has gained high priority in the global oil and gas industry. This paper presents two of the most complex real time instrumentation campaigns for drilling operations. Analyses of a connected drilling riser system including the well structure are complex and involve several engineering disciplines. In addition, there are many unknowns going into the equations when accumulated fatigue damage of the wellhead is estimated. Therefore, assumptions need to be made, very often on the conservative side. A typical example are the global drilling riser analyses where the environmental conditions, actual rig motion and riser / BOP behavior are uncertain. With the duplex scope of accurately documenting the wellhead fatigue status during drilling operations and of achieving a better understanding of the actual risk level of wellhead fatigue, Statoil decided to start a very comprehensive monitoring campaign. Two MODU representing very different generations of rigs in terms of weights and types of equipment were instrumented from topside to BOP connector. Strain gauges were installed around the BOP connector as close as possible to the wellhead in order to capture wellhead response as accurately as possible. Due to the large number of sensors, high accuracy requirement and high sampling frequency of data to be shown live, a cabled solution was selected vs remote battery operated sensors transmitting via acoustic. Double set of cables, sensors and topside equipment were installed in order to make the instrumentation system fully redundant and suited for permanent installation. All data were additionally made available real time onshore to allow the full overview of the operation. To author’s knowledge, these two instrumentation systems are the most comprehensive and complex of this type installed on a drilling riser as of today. The first of the two system was installed approximately three years ago and it is still in operation. This paper describes the instrumentation systems installed and gives an extract of the quality data extracted and already used in already published studies [1, 2, 3].

Application of Numerical Modeling for Predicting the Fatigue Crack Growth of an Elliptical Crack in Kelly Valves

2016 ◽  
Author(s):  
Hamidreza Ahmadimoghaddamseighalani ◽  
Pierre Mertiny
Keyword(s):  
Numerical Modeling ◽  
Fatigue Life ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Elliptical Crack ◽  
Microsoft Excel ◽  
Gas Industry ◽  
Drilling Operations ◽  
Python Programming ◽  
Fea Analysis

Kelly valves, also known as full opening safety valves, are widely used in the oil and gas industry for the purpose of blowout prevention. Crack propagation in the stem hole feature of Kelly valves is of concern during service in drilling operations as fatigue may lead to catastrophic failure. A computational tool to predict the fatigue life of these valves when a crack is present was therefore created. The present paper describes the numerical modeling approach in which an elliptical crack in the stem hole feature was introduced. To predict the fatigue life of the valve based on the J-integral method, ANSYS Workbench was used for a FEA analysis in conjunction with Microsoft EXCEL and Iron Python programming.

Control to Assurance – A Re-Imagined Health Safety and Environment HSE Leadership in the Oil and Gas Industry

2021 ◽  
Author(s):  
Kingsley Okenyi ◽  
Ejiro Ogbodu ◽  
Abayomi Apena ◽  
Olalekan Olagunju
Keyword(s):  
High Performance ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Leadership Practice ◽  
Leadership Model ◽  
Best Value ◽  
Drilling Operations ◽  
Match Theory ◽  
Performance Results

Abstract The importance of HSE in oil and gas activities especially in drilling operations cannot be overemphasized. Over the years, many systems of how to reduce and eliminate HSE challenges in our operations have been implemented. These systems keep changing to meet goal zero target. Despite the implementation and the published advances in HSE approaches and tools, HSE performance continues to be at least one incident above target which is Goal Zero. This paper is focused on identifying if the Best Value Approach (BVA) can be modified into a HSE leadership model to help HSE leaders, frontline barrier leaders with delivering GOAL ZERO. This paper specifically focuses on identifying the unique practice of the BVA that has generated a significant amount of documented high-performance results in the procurement of services and project management. This paper will translate this proven performance to HSE leadership. The paper will match this theory with a current HSE leadership practice of Assist and Assure in Shell. The aim, match theory to practice and then to theory and then produce a concept that will help HSE leaders optimise the implementation of the Assist and Assure Process.

Mitigating Wellhead Fatigue While Reducing HSE Risk, Deck Spread, Deployment Time, and Crew Size

2021 ◽  
Author(s):  
Gunnar Ulland ◽  
Gunnar Hilsen ◽  
Stefano Croatto
Keyword(s):  
Fatigue Life ◽  
Oil And Gas ◽  
New Technology ◽  
High Capacity ◽  
Critical Factor ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Industry Practice ◽  
Drilling Operations ◽  
Deployment Time

Abstract Subsea wellhead systems have a design fatigue life that is expected to withstand the damage incurred from stress caused by cyclic loading during its operation. Wellhead fatigue is a critical factor when drilling offshore wells because the condition of the wellhead determines the length of time drilling activities can be carried out safely. The presence of the BOP on top of the wellhead affects fatigue life. Initially, these units were designed for 6-in. and 10-in. diameter casing and weighed slightly less than 1,400 lb. [ASME, 2003) Over time, BOPs evolved, and today's units are considerably larger and heavier than their predecessors, weighing in at approximately 400 metric tons. This increase in size and weight on the wellhead negatively impacts fatigue life. In recent years, the oil and gas industry has begun to look for ways to reduce wellhead fatigue to extend the life of the wellhead and expand the margins for safe drilling operations. A new ROV-operated Wellhead Load Relief (WLR) system, developed specifically to mitigate fatigue, uses special tensioners that are tethered individually to the BOP. Each tensioner contains a hydraulic spooling unit with a lock- and-pull mechanism that allows the ROV to tighten adjustable tethers subsea, pulling them from slack to a maximum tension of 35 metric tons. This approach to installation is a departure from common industry practice, which necessitates the configuration of the predetermined tether lengths on the topside. The ROV-operated WLR system described in this paper is a compact, high-capacity BOP tethering system suitable for both template and seabed anchoring. It provides a new and efficient way of tethering the BOP to avoid wellhead fatigue and delivers additional benefits that include minimized HSE risk, a smaller deck spread, decreased deployment time, and a smaller crew. The WLR system was operated subsea for the first time in December 2019. By precisely tensioning each tether and limiting the load transferred to the wellhead, the WLR significantly lessened wellhead fatigue, resulting in an almost complete halt in BOP movement. This new technology enables the operator to make optimal use of the fatigue life of the wellhead without compromising efficiency or safety.

The Art of Short Radius Drilling – Best Practices to Consistently Deliver Wells

2021 ◽  
Author(s):  
Farooq Anwar Baig ◽  
Ali Alhasawi ◽  
Marco Aburto Perez
Keyword(s):  
Middle East ◽  
Best Practices ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Drilling Engineering ◽  
Bottom Hole Assembly ◽  
Operational Practices ◽  
Reliable Solution ◽  
Key Steps

Abstract Short radius wells typically incorporate build rates between 35deg per 100ft and 70deg per 100ft. These wells are typically drilled to minimize exposure of a problematic zone above the target or to reduce geological uncertainty. This paper will discuss best practices and equipment developed specifically for delivering these wells in the Middle East. Case histories will illustrate the close collaboration with the operator resulting in performance step change for short radius drilling. The approach is based on a rigorous Drilling Engineering process. Such process is divided in four major steps; design, execute, evaluate and optimize. One of the first key steps is to perform a diligent risk assessment ensuring the customer objectives are achieved. This resulted in the development and implementation of technological innovations on downhole motors and Measurements While Drilling (MWD) tools to achieve the required high build rates safely and consistently. Proper communication was crucial for flawless execution, and meticulous documentation enabled proper evaluation and optimization of the art of short radius drilling. For over 10 years, multiple short radius wells have been consistently delivered meeting their objectives; from successful sidetracking operations, accurate curve landing, optimum geo-steering, valuable Logging While Drilling (LWD) data collection, to extending the life of the wells by maximizing their production. The last two steps of the Drilling Engineering cycle (evaluate and optimize) have been the foundation of the continuous improvement process; targeting adequate equipment maintenance, Bottom Hole Assembly (BHA) design and operational practices to ensure consistent results. The paper will recap the drilling engineering cycle for wells drilled recently. The discussed best practices have enabled master the art of short radius drilling. Such distinctive knowledge should be shared with the entire oil and gas industry. The paper captures the engineering approach to tackle the traditional challenges of drilling short radius wells. It also discusses the reliable solution for drilling short radius wells in Middle East which are planned to access new reserves from an existing infrastructure, while minimizing drilling and geological risks.

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