pup joint well drilling free sample

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In most completions, the length of tubing available at surface is not enough for proper wellhead installation and operation. Pup joints and varying lengths of tubing are used to adjust the production string length as close as possible to the desired value. Then, the adjustable union or joint is installed, rotationally adjusted, and locked to the desired makeup length. In dual completions, the tool can be used to adjust the length of the short string.

The adjustable, telescoping action of the union or joint allows it to be set and locked at any desired position within its adjustment length while maintaining pressure integrity in the tubing string. Once the tool is in place, the desired amount of tension, weight, and rotational torque can be applied through it to the tubing.

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Pup joints are nonstandard pipes used to adjust the length of the tubular string to meet the exact requirements. In addition, the pup joints are used to change the length of the drill string for drilling operations and easy surface handling. The appearance of the pup joints is largely determined by their mechanical properties.

Further, thePup Joint marketis segmented by product type, Technology, End-User, and geography. On the basis of product type, the Pup Joint market is segmented under Crossover Pup Joint, Tubing Pup Joint. Based on the Technology, the market is segmented under the Hot Rolled and Cold Rolled. Based on End-User, the market is segmented into Chemical Industry, Mining, Oil & Gas, Construction, and Others. By geography, the market covers the major countries in North America, i.e., the US, Canada, and Mexico. For each segment, the market sizing and forecasts have been done on the basis of value (in USD Million).

Increasing consumption of natural gas and oil, technological advancements in drilling techniques, and fast-growing industrialization are the major factors contributing to the market growth. The rise in demand for high-grade pup joints from several end-use industries is expected to drive the use of pup joints. Demand for pup joints is expected to rise because of the growing demand for energy and significant investments in exploring onshore and offshore reserves by the oil & gas and mining industries. Increased energy consumption, the economic development of the shipping industry, and increased seaborne trade are the major factors driving the demand for pup joints during the forecast period.

The decline in petroleum production may hinder the market"s growth. Renewable energy will be more affordable than existing oil and gas sources during the forecast period, which will restrain the market for pup joints.

Due to COVID-19, the major end-user industries of pup joints were affected, which will hinder the demand for pup joints since the oil & gas industry is the largest end-user. COVID-19 has had a significant impact on the downstream oil & gas industry due to the significant drop in prices and reduced demand caused by the economic slowdown, which affected production rates in many countries. However, major countries such as the US and Canada implement dynamic and diverse approaches to navigate and deal with what is happening due to COVID-19. As a result, the market will experience moderate growth during the forecast period. The United States is a major revenue generator in the North American pup joint market.

With changes in energy arrangements and expanding political pressures, the market interest in pup joints and comparable items is changing. Government and privately owned businesses are showing a clear interest in finding new oil stores to meet future needs. Ventures by significant oil exploration companies are likely to support the pup joint market.

By Product Type,the Pup Joint Market is segmented into Crossover Pup Joint, Tubing Pup Joint, and Drill Pipe Pup Joint. The Tubing Pup Joint had the highest market share in 2021. Tubing pup joints are likely to have a huge demand because they are also used to handle production tubing accessories. Tubing pup joints are tubing that is short in size and operated for spacing.

By Technology, the Pup Joint Market is segmented into Hot Rolled and Cold Rolled. The Hot Rolled segment had the highest market share in 2021. Under high temperature and pressure processing conditions, the steel tube can be completely devoid of air bubbles, cracks, and porosity. It has a good mechanical effect and excellent intensity.

By End-User, the Pup Joint Market is segmented into Chemical Industry, Mining, Oil & Gas, Construction, and Others. The Oil & Gas segment had the highest market share in 2021. The oil & gas business has been positively impacted by the introduction of several drilling technologies. Due to the reliance on petroleum-based products by various emerging economies, oil & gas dependence has increased. Petroleum is used to make a variety of chemical products, such as fertilizers, pharmaceuticals, and solvents. To meet future demand for oil, both private and public companies are seeking to explore new oil reserves.

The market is characterized by the existence of a number of well-known firms. These companies control a large portion of the market, have a wide Product Type portfolio, and have a North America presence. In addition, the market comprises small to mid-sized competitors that sell a limited variety of items, some of which are self-publishing organizations.

The objective of the report is to present a comprehensive analysis of theNorth AmericaPup Joint market to the stakeholders in the industry. The report provides trends that are most dominant in the North AmericaPup Joint market and how these trends will influence new business investments and market development throughout the forecast period. The report also aids in the comprehension of theNorth AmericaPup Joint Market dynamics and competitive structure of the market by analyzing market leaders, market followers, and regional players.

The qualitative and quantitative data provided in theNorth AmericaPup Joint market report is to help understand which market segments and regions are expected to grow at higher rates, factors affecting the market, and key opportunity areas, which will drive the industry and market growth through the forecast period. The report also includes the competitive landscape of key players in the industry along with their recent developments in theNorth AmericaPup Joint market. The report studies factors such as company size, market share, market growth, revenue, Product Type, and profits of the key players in theNorth AmericaPup Joint market.

The report provides Porter"s Five Force Model, which helps in designing the business strategies in the market. The report helps in identifying how many rivals exist, who they are, and how their Product Type quality is in theNorth AmericaPup Joint market. The report also analyses if theNorth AmericaPup Joint market is easy for a new player to gain a foothold in the market, do they enter or exit the market regularly, if the market is dominated by a few players, etc.

The report also includes a PESTEL Analysis, which aids in the development of company strategies. Political variables help in figuring out how much a government can influence theNorth AmericaPup Joint market. Economic variables aid in the analysis of economic performance drivers that have an impact on theNorth AmericaPup Joint market. Understanding the impact of the surrounding environment and the influence of environmental concerns on the North AmericaPup Joint market is aided by legal factors.

1. Introduction of pup joint The pup joint is fixed length tubing or casing. The thread is EUE, NUE, NEW VAM. The Length is from 1feet to 10feet. 2. Specification 3. Property of material

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A drill string on a drilling rig is a column, or string, of drill pipe that transmits drilling fluid (via the mud pumps) and torque (via the kelly drive or top drive) to the drill bit. The term is loosely applied to the assembled collection of the smuggler pool, drill collars, tools and drill bit. The drill string is hollow so that drilling fluid can be pumped down through it and circulated back up the annulus (the void between the drill string and the casing/open hole).

The Bottom Hole Assembly (BHA) is made up of: a drill bit, which is used to break up the rock formations; drill collars, which are heavy, thick-walled tubes used to apply weight to the drill bit; and drilling stabilizers, which keep the assembly centered in the hole. The BHA may also contain other components such as a downhole motor and rotary steerable system (RSS), measurement while drilling (MWD), and logging while drilling (LWD) tools. The components are joined together using rugged threaded connections. Short "subs" are used to connect items with dissimilar threads.

Heavyweight drill pipe (HWDP) may be used to make the transition between the drill collars and drill pipe. The function of the HWDP is to provide a flexible transition between the drill collars and the drill pipe. This helps to reduce the number of fatigue failures seen directly above the BHA. A secondary use of HWDP is to add additional weight to the drill bit. HWDP is most often used as weight on bit in deviated wells. The HWDP may be directly above the collars in the angled section of the well, or the HWDP may be found before the kick off point in a shallower section of the well.

Drill pipe makes up the majority of the drill string back up to the surface. Each drill pipe comprises a long tubular section with a specified outside diameter (e.g. 3 1/2 inch, 4 inch, 5 inch, 5 1/2 inch, 5 7/8 inch, 6 5/8 inch). At each end of the drill pipe tubular, larger-diameter portions called the tool joints are located. One end of the drill pipe has a male ("pin") connection whilst the other has a female ("box") connection. The tool joint connections are threaded which allows for the mating of each drill pipe segment to the next segment.

Most components in a drill string are manufactured in 31 foot lengths (range 2) although they can also be manufactured in 46 foot lengths (range 3). Each 31 foot component is referred to as a joint. Typically 2, 3 or 4 joints are joined together to make a stand. Modern onshore rigs are capable of handling ~90 ft stands (often referred to as a triple).

Differentially when there is a large difference between formation pressure and wellbore pressure. The drill string is pushed against one side of the well bore. The force required to pull the string along the wellbore in this occurrence is a function of the total contact surface area, the pressure difference and the friction factor.

The mechanical success of cable tool drilling has greatly depended on a device called jars, invented by a spring pole driller, William Morris, in the salt well days of the 1830s. Little is known about Morris except for his invention and that he listed Kanawha County (now in West Virginia) as his address. Morris received a patent

In addition to the mechanical and hydraulic versions, jars are classified as drilling jars or fishing jars. The operation of the two types is similar, and both deliver approximately the same impact blow, but the drilling jar is built such that it can better withstand the rotary and vibrational loading associated with drilling. Jars are designed to be reset by simple string manipulation and are capable of repeated operation or firing before being recovered from the well. Jarring effectiveness is

determined by how rapidly you can impact weight into the jars. When jarring without a compounder or accelerator you rely only on pipe stretch to lift the drill collars upwards after the jar releases to create the upwards impact in the jar. This accelerated upward movement will often be reduced by the friction of the working string along the sides of the well bore, reducing the speed of upwards movement of the drill collars which impact into the jar. At shallow depths jar impact is not achieved because of lack of pipe stretch in the working string.

The concept of using vibration to free stuck objects from a wellbore originated in the 1940s, and probably stemmed from the 1930s use of vibration to drive piling in the Soviet Union. The early use of vibration for driving and extracting piles was confined to low-frequency operation; that is, frequencies less than the fundamental resonant frequency of the system and consequently, although effective, the process was only an improvement on conventional hammer equipment. Early patents and teaching attempted to explain the process and mechanism involved, but lacked a certain degree of sophistication. In 1961, A. G. Bodine obtained a patentresonant vibration that effectively eliminated the reactance portion of mechanical impedance, thus leading to the means of efficient sonic power transmission. Subsequently, Mr. Bodine obtained additional patents directed to more focused applications of the technology.

The first published work on this technique was outlined in a 1987 Society of Petroleum Engineers (SPE) paper presented at the International Association of Drilling Contractors in Dallas, Texasresonant vibration theory in more detail as well as its use in extracting long lengths of mud stuck tubulars.

The vessel was offset 15 m south of the original site coordinates and the seafloor tag depth of 3648.0 m below rig floor (mbrf) used as the official seafloor depth for the hole. After laying out the upper guide horn, preparations began for installing the reentry cone and 10¾″ casing string. The 16″ casing hanger assembly was made up and racked back in the derrick. We then assembled and tested the 458.83 m long drilling assembly, which consisted of the 9⅞″ tricone drilling bit, 8″ mud motor, and underreamer with arms set to 12¾″. The pre-assembled standard reentry cone was positioned over the moonpool doors. We began to run casing at 1200 h on 19 April. The casing string, made-up of a Texas pattern casing shoe, shoe joint, 33 joints of 10¾″ casing, a 16″ × 10¾″ casing crossover (swage), 16″ casing pup joint, and a 16″ casing hanger, totaled 455.11 m in length. This assembly was lowered into the reentry cone using the casing running tool. At 2045 h on 19 April, the driller lowered the drilling assembly into the reentry cone and latch-in was completed at 0035 h on 20 April. At 0100 h we began tripping the assembly toward the seafloor. During the pipe trip, the subsea camera was deployed and the drill pipe filled with seawater every 15 stands.

After picking up the top drive, Hole U1456D was spudded at 1035 h on 20 April. It required a total of 20.75 h to drill-in the 455 m of casing. The reentry cone base landed on the seafloor at 0710 h on 21 April, positioning the casing shoe at a depth of 455.1 m below seafloor (mbsf). The driller rotated the drill string 3½ turns to the right to release the casing running tool; however, the drilling assembly was unable to pull free of the reentry cone and casing. We attempted to free the assembly over the next 4.25 h by offsetting the ship in a grid pattern away from the hole location. After this did not free the assembly, it became clear that the running tool was released, but the underreamer arms had not fully retracted. At 1135 h on 21 April, the drilling assembly was pulled free with 15,000 lb of overpull. While pulling the drill string, the underreamer continued to drag intermittently inside the casing, predominantly when passing through casing couplings. The top drive was set back, the subsea camera retrieved to the ship, and the bit pulled clear of the seafloor at 1540 h. After tripping the assembly back to the ship, the running tool was de-torqued, the drill collars racked back in the derrick, the mud motor and underreamer assemblies flushed with fresh water, and at 0140 h on 22 April, the bit cleared the rotary table. From start to finish, using a mud motor and underreamer assembly, we required only a total of 3 d to make-up and install a standard reentry cone with 455 m of 10¾″ casing in 3648 m water depth using the drill-in casing approach.

With the reentry cone and casing installed, the drill crew requested time to investigate a noise they had heard on multiple occasions that emanated from the drilling package. During operations they were unable to determine whether the source of the noise was the top drive itself or the swivel assembly. A total of 9 h of “downtime” were taken to separate the swivel from the top drive and thoroughly investigate the issue. Ultimately the gear was all reassembled without identifying the original source of the noise. Once everything was reassembled, the noise was no longer heard.

We then made up the rotary core barrel (RCB) bottom-hole assembly and, after slipping and cutting the drilling line, began tripping toward the seafloor. The subsea camera was deployed during the pipe trip; however, after there was a problem with the video feed, the camera was brought back aboard, repaired, and redeployed. At 0245 h on 23 April we reentered Hole U1456D after maneuvering the ship for only 20 min. The drill string was lowered into the casing string to a depth of 416.0 mbsf (39.1 m above the casing shoe) when soft fill was tagged. We picked up the top drive, deployed a wash barrel, and began to slowly circulate. The fill was cleared by 0800 h on 23 April. A 40-barrel sea gel mud sweep was circulated out and the wash barrel recovered. At 1000 h on 23 April, a core barrel was deployed and continuous RCB coring using nonmagnetic core barrels initiated. RCB coring continued with 30-barrel sea gel mud sweeps pumped every third core. Although we encountered no fill on bottom between cores, rapid penetration rates, low recovery, and evidence of sand in the recovered core material indicated there was still some sand in the formation. We therefore initiated preventative measures in order to preserve the integrity of the hole as much as possible. As of midnight on 25 April, 32 RCB cores had been taken in Hole U1456D with a recovery of 46%.

The sedimentologists described Cores U1456D-2R through 30R (458.8–739.69 mbsf) using a combination of visual core description, microscopic investigation of smear slides, core imaging, spectral color scanning, and magnetic susceptibility. The dominant lithology of Cores 2R through 6R (458.8–497.91 mbsf) is dark greenish gray silty sand and clay, with rare bioturbation and pyrite nodules. Normally graded silty sand typically overlies parallel laminated clay with an erosive contact. Drilling disturbance is often severe and fractures are common. The dominant lithologies change in Cores 7R through 29R (507.3–726.6 mbsf) to dark gray nannofossil-rich claystone, dark gray claystone, and light gray nannofossil chalk with some pyrite nodules and dark gray silty sand and sandstone. Bioturbation is generally light to moderate, and the cores are affected by slight to moderate, but occasionally severe, drilling disturbance. Another downhole change in lithology occurs in Core 30R, with a shift from sandstone to claystone that is marked by a sharp color shift from light to dark greenish gray. Smear slide analysis supports the lithologies identified through macroscopic core description and verifies the occurrence of nannofossils throughout the recovered interval, especially in Cores 8R through 23R. Detrital minerals include abundant quartz, feldspar, and micas, and rare to common heavy minerals.

The biostratigraphers examined core catcher samples from Cores U1456D-2R through 31R (458.8–759.8 mbsf) for calcareous nannofossil, planktonic foraminifer, radiolarian, and diatom biostratigraphy. Calcareous nannofossils are generally common and are well preserved, although their abundance decreases in coarser grained intervals. Planktonic foraminifers are generally common in Cores 2R through 17R; however, below Core 17R, planktonic foraminifers are mainly absent in the core catcher samples examined. When present, planktonic foraminifers are moderately to well preserved. Radiolaria are low in abundance and poorly preserved. Diatoms are absent in all samples examined. The 458.8–759.8 mbsf interval is assigned a late Miocene to Pliocene age, based primarily on nannofossil biostratigraphy. Two radiolarian species also support this interpretation. Significant reworking of Cretaceous and Paleogene forms hampers biostratigraphic interpretation, particularly within the calcareous nannofossil assemblages.

After completion of downhole logging in Hole U1456C, the stratigraphic correlators compared whole-round natural gamma radiation (NGR) data from Holes U1456A and U1456C with the processed spectral gamma ray downhole log. Excellent correlation exists between the base of pipe (at 81 m drilling depth below seafloor [DSF]) and the base of the spliced section at 136 m wireline matched depth below seafloor (WMSF). Between 136 and ~210 m WMSF, it was possible to make a fair to good correlation between the Whole-Round Multisensor Logger (WRMSL) data and the logs. Correlation was difficult in the interval between ~210–380 m WMSF, where we only have core data from Hole U1456A because we drilled through this interval without coring in Hole U1456C. Correlation was again possible below 380 m WMSF, where the lithology changes from coarser grained material to clay and claystone.

Paleomagnetic and magnetic susceptibility anisotropy analyses have been completed for Hole U1456C. This work is ongoing in Hole U1456D. We have a preliminary magnetic polarity stratigraphy for Site U1456 that includes the Brunhes Chron (C1n) and the Jaramillo subchron (C1r.1n). The Olduvai appears to be missing, but the Gauss (C2An) is well expressed. We have resumed analysis of archive-half sections in Hole U1456D because of the more favorable lithology. These data agree well with discrete sample results. Interestingly, the drill string overprint that was prevalent in Holes U1456A and U1456C has mostly disappeared in Hole U1456D.

Physical properties measurements were completed for U1456C and are ongoing for Hole U1456D. Measurement of compressional wave (P-wave) velocity was discontinued on whole-round cores from Hole U1456D because of the gap between the core liner and sediment when coring with the RCB system. We applied a correction factor of 1.138 to the density measurements from the WRMSL due to the reduced diameter of the cores (66 mm/58 mm = 1.138). Thermal conductivity measurements were conducted on split sections when possible, with values varying between 1 and 2 W/(m·K). No downhole trend is apparent in those data. Porosity is generally low (~40%) in Hole U1456D, similar to the deeper section of Hole U1456A. Discrete P-wave measurements were made on the working half of split cores on the Section Half Measurement Gantry (SHMG). Higher P-wave velocities occur in the sandstones (>2000 m/s) compared to claystones. The P-wave velocities measured on the SHMG in both Holes U1456A and U1456C are offset to lower values compared to sonic velocities from downhole logging. Magnetic susceptibility shows variations that correlate with the alternation between coarser graded beds, interpreted as turbidites, and nannofossil-rich hemipelagic sediment. Variations in NGR and density also correlate well with lithologic changes.

We conducted five ship-to-shore video events during the week. We held our first connections with India, introducing the expedition objectives and shipboard laboratories to ~200 high school students in Bhagwanpur (Varanasi) and ~250 high school students in Assandh (Haryana). We also held an event with high school science teachers in France who are interested in preparing curriculum material about scientific ocean drilling for their classrooms. Finally, we connected with two groups of ~50 students at a magnet school in Los Angeles, California (USA).