Casing Exit in Expandable Liner Enables Operator to Avoid Redrilling 3,000-ft Hole Sections in Gulf

2021 ◽  
Author(s):  
Tom Emelander ◽  
Justin Muesel ◽  
Casey Carrington
Keyword(s):  
Internal Diameter ◽  
Thin Wall ◽  
Industry Standards ◽  
Equipment Availability ◽  
Bottom Hole Assembly ◽  
Short Lead Time ◽  
Fit For Purpose ◽  
Job Challenges ◽  
Productive Time ◽  
Outside Diameter

Abstract After a 13 3/8-in. expandable liner collapsed in a Gulf of Mexico ultradeepwater well, an operator considered a whipstock sidetrack, exiting as deep as possible to finish drilling and completion operations. Exiting the 16-in. casing, industry standards would have called for redrilling and casing an entire hole section. Exiting the expandable liner was an alternative option, but would require a unique solution to operate in the larger internal diameter (ID) and maintain the existing hole size. The service provider created a fit-for-purpose solution to install a casing window in the 13.77-in. ID expandable liner. The standard casing exit system accommodates 13 3/8-in. casing through 14-in. casing and requires minimal modifications to anchor the actual concave assembly to support a 12.25-in. pilot window. Additional mill runs would then open the 12.25-in. pilot window to a full bore 13 1/2-in. outside diameter (OD) window. Despite never having performed an installation in this size of expandable liner, the provider had a run history for exits with similar modifications and extra trips to enlarge and elongate windows. Job challenges included thin-wall, channeled cement; limited flow rates because of liner pressure limits; equipment availability; and a short lead time. The 11 1/2-in. OD assembly was quickly modified to enable the anchor engagement in the 13.77-in. ID liner. Within days the mills were dressed to the custom ODs required to enlarge the 12.25-in. pilot window to 13.50-in. On the first run, the whipstock was hydraulically set in the liner. Kickoff was achieved at 19,609-ft to cut a 27.5-ft window and ream a 45-ft rathole in 22 hours. The second bottom hole assembly (BHA) consisted of three mills with 12 1/2-in., 12 3/4-in., and 13-in. ODs. Milling and reaming took 6 hours. The third and final BHA to open the window to a 13 1/2-in. OD consisted of a 13 1/4-in. OD mill and two full-drift mills above. Milling and reaming with this BHA took 29 hours before coming back in with a motor assembly to drill ahead. This installation is the first sidetrack conducted with a whipstock in a 13 3/8-in. expandable. This paper will show that it is possible to safely and reliably install a casing exit system in difficult applications, such as deep expandable liners, that might previously have been considered unfeasible. This approach provides an opportunity for the industry to significantly reduce non-productive time in such scenarios.

Fit for Purpose Connection Design for Drilling Operations in Size Constrained Tubular

2021 ◽  
Author(s):  
Guillaume Plessis ◽  
Andrei Muradov ◽  
Richard Griffin ◽  
Jeremy Dugas ◽  
Justin Orlando ◽  
...  
Keyword(s):  
Drill Pipe ◽  
Drill String ◽  
Internal Diameter ◽  
Engineering Technology ◽  
Technology Center ◽  
Drilling Operations ◽  
Fit For Purpose ◽  
The One ◽  
Connection Design ◽  
Outside Diameter

Abstract Drilling out or working within small sizes of casing and liners requires the use of a drill string with small outside diameter tool joints to fit inside the casing/liner bore and, at the same time, a large enough connection internal diameter to pump actuating balls inside the drill string when needed. These requirements significantly limit the available options that can be used. Historically, a drill pipe double shoulder connection with a 3⅛-in. outside diameter (OD) has been used for such operations, as it allows for multiple makeups and breakouts before it needs to be repaired. This is a great improvement compared to using small tubing premium connections that are somewhat limited on the number of makeups. However, the geometry constraints are such that the thin material envelope leads to torsional weakness in the connection, resulting in a higher than expected recut rate as connections can be overtorqued downhole in operation. A research and development (R&D) project was commissioned to improve the connection performance significantly to mitigate the downhole overtorque. Exploring the acceptable connection envelope limits allowed for a slightly reduced internal diameter (ID) when compared to the previously used connection. The team considered different thread designs and decided to use the one that would provide the highest torque. The design process was then followed to develop and qualify a well-balanced connection. The design validation was performed at an engineering technology center in Houston, Texas, where samples were destructively tested to compare the actual capacity of the new connection against the calculated values. It was confirmed that the torsional strength of the new design meets and exceeds the theoretical value, an improvement of at least 85% over the previously used connection, and a first string was built. It was subsequently deployed in the field and the recut rate was monitored to establish that the objective of delivering a connection capable of higher torque was indeed met to resist the downhole overtorque.

Industry's First Sidetrack in 12-1/4-in Casing Enables Operator to Re-Establish Production in GOM

2021 ◽  
Author(s):  
Tom Emelander
Keyword(s):  
Test Results ◽  
Standard Equipment ◽  
Real World Application ◽  
Bottom Hole ◽  
Bottom Hole Assembly ◽  
Job Challenges ◽  
Pass Through ◽  
Best Fit ◽  
Outside Diameter ◽  
Made In

Abstract In a Gulf of Mexico (GOM) ultradeepwater well, liner integrity issues forced an operator to consider milling a conventional casing exit to sidetrack as deep as possible to re-establish production. Milling a window in 12 -1/4-in. heavy wall casing above the liner hanger had never been achieved before because of the thickness and grade of casing. A successful installation would require significant preplanning and testing to prove capability before real-world application. The service provider recommended an off-the-shelf solution to accommodate a 12 -1/4-in. casing exit. It was determined that the best fit for the application would be the standard equipment used for exits out of 10 -3/4-in. casing, given the similar internal diameters (IDs). Despite never having performed an installation in this casing size, the provider had a successful run history for exits in heavy weight casing strings. Job challenges included avoiding cutting a casing connection, managing swarf, milling through a centralizer, and achieving a low dogleg for production packers. Additional challenges included torque limitations, mill gauge, and the limestone formation. An 8-in. outside diameter (OD) system with mechanical anchor and 9 -7/8-in. OD mills was sent to a test well designed to replicate the target section of the offshore well. Based on determinations made in the planning phase, milling of the window and rathole would be staged in two trips. Additionally, a replica drilling bottom hole assembly (BHA), 8 -5/8-in. casing, and a replica production packer would need to pass through the window to ensure both window quality and low enough dogleg. Dogleg data was acquired through multiple logging runs during the 10-day operation. The installation went as planned, along with an additional custom window elongation run to decrease the dogleg severity to approximately 4.5°/100 -ft (30m). Having successfully validated the equipment for the application, the operator and servicer prover were comfortable moving onto the GOM well. Considering the test results, the team planned to mill the window and rathole in one trip. They achieved the 22 -ft long window and 15 -ft rathole in one run that lasted 26 hours. This installation is the first sidetrack conducted with a whipstock in 12 -1/4-in. casing. This paper shows that a safe, reliable casing exit installation is possible in difficult applications, such as uniquely heavy wall casing, even though it may previously have been considered impossible. This successful application provides the industry with contingency options in similar scenarios.

A Client's Fit for Purpose Solutions in Well Abandonment

2021 ◽  
Author(s):  
Yun Thiam Yap ◽  
Avinash Kishore Kumar
Keyword(s):  
Cost Effective ◽  
Well Design ◽  
Industry Standards ◽  
Cost Effective Approach ◽  
Reservoir Conditions ◽  
Standards And Regulations ◽  
Fit For Purpose ◽  
Well Abandonment ◽  
Oil Company

Abstract Typically, most of the well abandonment practice is reference to the recognized industry standards i.e. NORSOK, UK Oil & Gas and etc, and this is how the wells abandonment was carried out in the past. These practices however evolved/changed over time with lessons learnt and experiences and turn into a fit for purpose solutions for the Client. The shift in international and local standards and regulations for a robust plug and abandonment approach has placed the need for a better and long lasting permanent P&A methodology. Adhering to the existing industry standards in well abandonment is somehow not practical and not cost effective to be implemented in different part of the well, where there are major differences in local regulations, reservoir conditions, caprock thickness, well design philosophy and etc. The magnitude of abandonment cost increase is not at par with the risk reduction in long term hydrocarbon leakage. A fit for purpose solutions is recommended in closing the gap between cost and risk. Due to the extremely varied well architecture between wells, the approach to permanent abandonment varies depending on casing sizes, presence of packers and no of casings present to the caprock area. On top of that, identifying the highest depth for a placement of cement plug will reduce on the amount of plugs to be placed, saving rig time and operational time. So far, 16 idle wells have since been permanently abandoned with the systematic approach of applying caprock restoration concept and reinstating the poor isolation across caprock areas with cement with the assistance of technology to the likes of perf-wash-cement, and hydro mechanical casing cutter. These wells have successfully been abandoned as per host authority standards. This paper will explore a major local oil company’ approach to decommissioning of wells, in line with local regulations enforced, while ensuring a cost effective approach is applied in line with the available technologies.

scholarly journals Head loss in laser-perforated thin-walled polyethylene pipes for irrigation

2019 ◽  
Vol 23 (5) ◽  
pp. 317-323 ◽  
Author(s):  
Verônica G. M. L. de Melo ◽  
José A. Frizzone ◽  
Antonio P. de Camargo ◽  
Wagner W. Á. Bombardelli
Keyword(s):  
Flow Rate ◽  
Pressure Head ◽  
Head Loss ◽  
Internal Diameter ◽  
Thin Wall ◽  
Operating Pressure ◽  
Irrigation Systems ◽  
Polyethylene Pipes ◽  
Flexible Pipes ◽  
Thin Walled

ABSTRACT For reducing fixed and operational costs in pressurized irrigation systems, thin-walled polyethylene pipes with laser-perforated orifices are manufactured to operate under low pressure (up to 100 kPa). Hydraulic characterization of these materials is essential for designing irrigation systems. Considering the material elasticity and the thin wall thickness (about 200 μm), the internal diameter of these pipes may vary according to the operating pressure, resulting in changes of head losses. The purpose of this study was to analyze the head loss in flexible pipes with laser-perforated orifices, and to estimate the maximum length of laterals based on criteria of water distribution uniformity. Non-perforated pipe samples were tested to obtain equations of friction loss. Equations were fitted as a function of flow rate and pressure head at the pipe inlet, and, alternatively, the Darcy-Weisbach equation was modified considering the diameter expressed as a power-law function of pressure head. The equation of head loss as a function of flow rate and pressure head provided proper estimations and considered effects related to changes in the diameter of plastic pipes due to variations in the pressure head. The Darcy-Weisbach equation can be employed for estimating head loss in flexible pipes, whose diameter varies due to pressure, but the diameter must be calculated as a function of the pressure head at the lateral inlet.

Leveraging on Machine Learning Solution for Pioneering Wells Augmented Stuck Pipe Indicator in Real Time Centre

2021 ◽  
Author(s):  
Mohamad Hazwan Yusoff ◽  
Meor Muhammad Hakeem Meor Hashim ◽  
Muhammad Hadi Hamzah ◽  
Muhammad Faris Arriffin ◽  
Azlan Mohamad
Keyword(s):  
Machine Learning ◽  
Real Time ◽  
Detection System ◽  
Automation System ◽  
Learning Technology ◽  
Drilling Parameters ◽  
Bottom Hole Assembly ◽  
Signature Pattern ◽  
Monitoring Software ◽  
Productive Time

Abstract Stuck pipe incidents remain as one of the major problems in the drilling industry. The incidents will lead to expensive loss time in daily spread cost, bottom hole assembly cost, sidetracking cost as well as fishing cost. The Wells Augmented Stuck Pipe (WASP) Indicator, a state-of-the-art machine learning technology that seamlessly integrates with PETRONAS existing technologies, is introduced as the stuck pipe prevention detection system for the company. Historical real-time drilling data and stuck pipe incidents reports between 2007 and 2019 are used for the development of machine learning models. The models utilize key drilling parameters such as hookload and equivalent circulating density (ECD) to predict and analyze trends to detect any signature pattern anomalies for various stuck pipe events. The prediction and alarm are displayed in real-time monitoring software to trigger the operation team for prompt intervention. The WASP solution has demonstrated proven outcomes using historical and live well with high confidence in detecting stuck pipe incidents due to differential sticking, hole cleaning, and wellbore geometry. The WASP Indicator is envisaged to provide the company with cutting edge advantages in the industry. It is expected that the system will reduce the identification period and improve the reaction time of the monitoring specialists in recognizing the stuck pipe symptoms and highlighting potential incidents. The system is also bringing value to the company via non-productive time (NPT) cost avoidance and identification of early onset of various stuck pipe events based on distinct mechanisms. With the system, the existing portfolio value can be enhanced via setting dynamic trends and models into historical experiences context. The WASP Indicator is aspired to be the forefront innovation that will leap through the norm and lead the region in a greater plan of drilling automation system.

IMoDD: Intelligent Mapping of Downhole Dynamics

2021 ◽  
Author(s):  
Kelly Scott Sims ◽  
John Abhishek Bomidi ◽  
William Anthony Moss ◽  
Thomas Andrew Wilson
Keyword(s):  
Decision Making ◽  
Energy Transfer ◽  
Sensor Data ◽  
Weight Changes ◽  
Accurate Representation ◽  
Bottom Hole ◽  
Mapping System ◽  
Bottom Hole Assembly ◽  
Downhole Sensors ◽  
Productive Time

Abstract With the ever-increasing pressure to drill wells efficiently at lower costs, the utilization of downhole sensors in the Bottom Hole Assembly (BHA) that reveal true downhole dynamics has become scarce. Surface sensors are notoriously inaccurate in translating readings to an accurate representation of downhole dynamics. The issue of 1 to 1 interpretation of surface to downhole dynamics is prevalent in all sensors and creates a paradigm of inefficient drilling practices and decision making. Intelligent mapping of downhole dynamics (IMoDD) is an analytical suite to address these inefficiencies and maximize the use of surface sensors, thus doing more with less. IMoDD features a new zeroing beyond the traditional workflows of zeroing the surface sensors related to weight and torque at the connection. A new method, Second-order Identifier of Maximum Stand-pipe-pressure: SIMS, is introduced. The method examines changes in stand-pipe pressure and identifies the point before bit-wellbore contact, using a set of conditions. The resulting calculations of weight and torque are verified with measured values of downhole weight and torque, for multiple stands of drilling in vertical, curve-lateral drilling. After the new zero, the deviation of torque-weight correlations is further examined to reveal the downhole weight changes confirmed also by the downhole sensor data. It is demonstrated that an intelligent mapping system that improves downhole characterizations would improve decision making to facilitate smoother energy transfer thus reducing Non-Productive Time (NPT) and increasing BHA life span.

scholarly journals Nest, eggs and nestling description of the Silvery-flanked Antwren Myrmotherula luctuosa (Pelzeln, 1868) in the Atlantic Forest of northeast Brazil

2019 ◽  
Vol 27 (4) ◽  
pp. 238-241
Author(s):  
Cleverton da Silva ◽  
Cristiano Schetini de Azevedo ◽  
Juan Ruiz-Esparza ◽  
Adauto de Souza Ribeiro
Keyword(s):  
Reproductive Biology ◽  
Atlantic Forest ◽  
National Park ◽  
The State ◽  
Internal Diameter ◽  
Northeast Brazil ◽  
Forest Fragments ◽  
Male And Female ◽  
Present Information ◽  
Outside Diameter

AbstractIn the present study, we describe the nest, eggs, and nestlings of the Silvery-flanked Antwren, Myrmotherula luctuosa. One nest was found on 08 May 2017 on the edge of one of the forest fragments of the Serra de Itabaiana National Park, in the state of Sergipe, northeast Brazil, and was monitored until 21 May 2017. The nest, presented the following dimensions: external height: 7.6 cm; outside diameter: 21 × 19 cm; internal diameter: 13.3 × 11 cm; depth of the oologic chamber: 4.7 cm; and height in relation to the ground: 84 cm. The two eggs found in the nest were white with reddish-brown dots, patches and stripes and weighed 1.7 and 1.5 g. Incubation was performed by both the male and female, as well as feeding of the nestlings. A single egg hatched, giving rise to a 3.9 cm, 3.7 g nestling. According to our estimates, the young fledged with about 11 days. This is the first study to present information about the reproductive biology of the Silvery-flanked Antwren.

Acoustic Reflectometry for Blockage Detection in Pipeline

2014 ◽  
Author(s):  
L. Loureiro Silva ◽  
P. C. C. Monteiro ◽  
J. L. A. Vidal ◽  
Theodoro A. Netto
Keyword(s):  
Acoustic Pulse ◽  
Internal Diameter ◽  
Measured Signal ◽  
Online Information ◽  
Sound Pulse ◽  
Critical Issues ◽  
Impulsive Response ◽  
Parallel Finite Element ◽  
Fit For Purpose ◽  
Pipeline Design

Flow assurance is an important aspect of offshore, particularly deepwater pipeline design and operation, since one of the critical issues is the eventual initiation and growth of hydrate or paraffin blockages under certain conditions. Ideally, operators would benefit from online information regarding position and extent of an eventual blockage in a pipeline. The aim of this work is to apply acoustic technology to design and make a prototype that can be used in a pipe to efficiently identify and measure blockages. The technique uses a short duration sound pulse that is injected into the pipe. When the acoustic pulse encounters an impedance discontinuity, a portion is reflected back towards the acoustic source and microphones or hydrophones. Analysis of the measured signal reflections can provide valuable data related to location and size of the blockages. An experimental setup with a pipe of 4″ internal diameter and length of 100 m was constructed, and different excitation signals for the impulsive response function measurements were conducted. Microphones and hydrophones measurements were recorded using a fit-for-purpose data acquisition system with sampling rates of up to 1kS/s per channel. The tests were performed in air and water using different sizes of blockages and in different positions in the pipe. In parallel, finite element analyses were performed using the commercial software Abaqus to simulate the same conditions. The experiments were numerically reproduced with good correlation proving the potential of the technique.

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