nabors drilling mud pump supplier

The Canrig® Sigma 500-ton top drive is the next generation top drive, completely reimagined to endure the harshest drilling conditions while operating with the highest continuous torque in its class. Designed to endure the harshest drilling conditions, this all-new, innovative top drive provides more power, performance and torque density than ever before, while enabling greater automation and remote-control capabilities – both at the surface and downhole.

Nabors’ SunDowner is capable of being off-loaded and assembled on an offshore platform in a single day…from sunup to sundown. The short rig-up time results in significant mobilization cost savings.

With over 20 years of experience in designing custom solutions for the oilfield industry, engineers are available to integrate top drives, catwalks, casing running tools or other equipment into any desired rig, including rigs of the future or older classes of rigs ready to see a new age of drilling

Canrig’s range of top drives allows for the selection of a hydraulic or an electric powered unit. Each motor class comes with its own set of benefits which can be reviewed to select which option is more appropriate for a particular drilling environment.

Canrig manufactures, markets and services a full range of electric top drive systems for most land and offshore rigs. This includes top drives in every size and configuration to meet any drilling application whether marine, desert, jungle or arctic environments.

Nabors’ Blue Force® mud motors are customized to specific specifications, built to withstand all drilling fluid types and temperatures, and can help reduce non-productive time.

As pad drilling solutions continue to evolve and improve, walking rigs with crane-less rig-up are quickly becoming a typical feature on location. The Canrig® PadWalker™ was created to support multi-well pad drilling.

Canrig’s wireless torque, turn and tension sensor, the TesTORK® sub, delivers high speed, precise data over a secure wireless connection. Designed for ease of use and field robustness, the TesTORK® sub meets the demands of tubular services companies and drilling contractors alike.

Nabors’ fit-for-purpose managed pressure drilling (MPD) equipment and integrated MPD-Ready® drilling rig maximizes efficiencies and makes MPD services more scalable and cost-effective for unconventional land drillers.

In addition to enhancing the safety of drill floor activities, Nabors offers a fully automated drill floor robot system that reduces the non-productive time, noise, energy consumption and emissions typically associated with manual onshore and/or offshore drilling operations.

The Canrig® climate-controlled driller’s cabin provides integrated joystick control utilizing PLC technology. Touch-screen controls provide enhanced monitoring, control of rig equipment and visibility of drilling parameters.

Nabors offers the FracView® high-resolution LWD imager in 4.75 and 6.5 in collar sizes covering borehole diameter ranges from 5.875 to 9.5 inches. FracView was the first commercially available LWD borehole imager demonstrated to operate in long horizontal wells drilled with oil-based mud.

Key FeaturesDeepView Log Viewer capable of viewing and analysis of large volume high resolution drilling dynamics and imaging data in both time and depth domain

Nabors offers the SpectraView™ LWD spectral/azimuthal gamma ray tools capable of covering borehole sizes from 5.875 to 9.5 inches. The tool measures and records naturally occurring gamma radiation from surrounding formations during wellbore drilling.

Nabors offers the FracView® high-resolution LWD imager in 4.75 and 6.5 in collar sizes covering borehole diameter ranges from 5.875 to 9.5 inches. FracView was the first commercially available LWD borehole imager demonstrated to operate in long horizontal wells drilled with oil-based mud.

Nabors’ Blue Force® mud motors are customized to specific specifications, built to withstand all drilling fluid types and temperatures, and can help reduce non-productive time.

Capable of drilling up to eight laterals from a single wellbore, Nabors’ unique coiled tubing/stem drilling rig, CDR2-AC, was designed to help a major operator more effectively work over old wells and boost production in Alaska’s Kuparuk field.

A Side-Saddle® rig is ideal for batch drilling because it can drill the surface along one row of wells, walk to the adjacent row and repeat the same tasks using the same drilling mud.

Equipped with specially trained drillers, drilling performance software and reliable measurement while drilling (MWD) telemetry, Nabors Directional-Ready™ rigs include integrated downhole equipment and directional drilling instrumentation to enable high-fidelity surveying and precise placement in productive targets of longer lateral wellbores.

Key FeaturesDrillers working on Nabors Directional-Ready™ rigs are trained in directional theory, automated HMI sequences, BHA makeup and advanced wellbore placement operations

Nabors MPD-Ready® rigs feature integrated hardware and software components, and required flow paths, to ascertain the downhole pressure environment limits and manage annular hydraulic pressure during drilling operations. All equipment skids with rig, eliminating non-productive time when moving between wells for multi-well pad drilling.

Nabors offers cementing and casing accessories, including hydroform centralizers, Multi-Lobe Torque™ (MLT®) rings, reaming shoes and cementing solutions.

Nabors’ automated tubular service technology brings significant improvements in safety, performance, reliability and efficiency during casing drilling and tubular running operations.

The SmartPLAN™ tool seamlessly manages both the operator’s and drilling contractor’s workflows to deliver digital drilling recipes that optimize efficiency and improve performance.

Proprietary automated drilling activity sequencer that optimizes rig processes. Proven to consistently improve connection times, increase one run laterals and decrease unplanned trips, the SmartDRILL™ system drives scalable cost reduction and improved drilling performance. Workflows are digitalized to improve procedural adherence and ensure that best practices are being configured for future wells.

Nabors SmartROS™ automates many repetitive drilling tasks while integrating data from both downhole tools and surface systems. Automating these functions allows the driller to follow the customer’s well plan with a higher level of precision and operational excellence.

Nabors REVit® technology features advanced top drive automation that eliminates stick slip, a common mode of vibration that limits drilling performance.

The ROCKit® Suite significantly increases rate of penetration (ROP) by rocking pipe and delivering ideal weight to bit. It promotes improved toolface control by allowing fine adjustments while still drilling ahead, reducing the need for lubricants and other friction-reducing additives. Drillers save time by quickly setting toolface orientation.

Nabors offers remote control choke technology to help operators meet the challenges of well pressure control, while reducing costs and enhancing environmental risk and wellsite safety.

This integrated offering includes rotating control devices (RCDs) for the onshore unconventional market. RCDs are utilized for pressure management during drilling for the purpose of making a seal around the drillstring while the drillstring rotates.

Nabors provides BOP installation and inspection as well as API-compliant, field-proven testing of BOP components in compliance with industry standards.

Non-Stop Driller™ is a sub-based constant circulation system that allows the continuous circulation of drill fluids downhole while making or breaking drill pipe connections, enabling improved wellbore stability and hole cleaning, reduced risks of influx and optimum drilling performance.

The SmartSLIDE™ system integrates critical downhole information needed for directional drilling and then automatically implements corrective instructions and steering logic during slide drilling operations.

Nabors’ SmartNAV™ platform is an automated directional drilling decision-making system that visualizes the downhole positions of the drill bit and the planned well path and automatically generates instructions to keep the well on course.

The PACE®-R800 rig utilizes technology optimized for drilling automation with Nabors Rigtelligent® control system. The rack and pinion technology enables the precise control of block position required for advanced automati

As lateral lengths continue to increase, drillers need a rig with more power and greater tripping speed. Nabors PACE®-M800 rig features innovative advanced technologies that provide both.

When drilling laterals at or greater than 7,500 feet, the PACE®-M800 rig’s racking capacity eliminates the need to lay down drill pipe between wells on the same pad.

With over 20 years of experience in designing custom solutions for the oilfield industry, engineers are available to integrate top drives, catwalks, casing running tools or other equipment into any desired rig, including rigs of the future or older classes of rigs ready to see a new age of drilling

Jan. 25, 2023 -- Nabors’ recent acquisition of the engineering technology firm, MindMesh, includes the downhole simulation and modeling technologies that the MindMesh team has developed. Additionally, MindMesh co-founder and Chief Technology Officer Raju Gandikota...

A high percentage of mud motors are considered to be run out of spec by industry standards. The challenge has been to build a reliable motor that can withstand the stresses of more weight on bit, differential pressure, and rotary RPM.

Nabors owns and operates one of the world"s largest land-based drilling rig fleets and is a provider of offshore platform rigs in the United States and numerous international markets. Nabors also provides directional drilling services, performance tools, and innovative technologies for its own rig fleet and those of third parties. Leveraging our advanced drilling automation capabilities, Nabors" highly skilled workforce continues to set new standards for operational excellence and transform our industry.

The Baoji/Bomco F1000 Triplex mud pump has a max. working pressure of 5,000PSI and a 6-3/4" liner size. This model is the first choice for the medium and deep dr... More Info

The Baoji/Bomco F1600HL Triplex mud pump has a max. working pressure of 7,5000PSI and a displacement of 46.5L/S with 6" liner size. This model is the f... More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Mud Pumps - Emsco/Bomco 1600 Mud Pump, Unitized 1600 Mud Pump Powered by Two GE 752 Motors Charging Pump, Liner Flush Pump, Relief Valve, Mud Gauge, Etc. ....Call For Price More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Mud Pumps - 1 - Rebuilt Gardner Denver PZ-9 Mud Pump Package, New Caterpillar C-27, 1050 HP diesel engine. Belt-driven. comes with pulsation dampener, discharge block, precharge, li... More Info

Mud Pumps - 1 of 3 used Gardner Denver PZ-8 triplex mud pumps. This would be a good rebuildable core. We also have new, rebuilt and good used pumps and packages available for sale ... More Info

Mud Pumps - Mud Pump Parts & Complete Units: Liners, Pistons, Rubbers, Rods, Valves, Seats, Springs, Inserts (Bean, BJ, CAT, EMSCO, Ellis Williams, FMC, Failing, GASO, Gardner Denver... More Info

Continental Emsco Drilling Products, Inc., which consisted of Emsco drilling machinery and Wilson mobile rigs, was purchased by National-Oilwell, Inc on July 7, 1999. To our knowledge, no pumps have been manufactured and sold under the Emsco brand name since National-Oilwell acquired them.

Fairbanks Morse pumps are currently manufactured in Kansas City, Kansas. Fairbanks Morse is a division of Pentair ever since August, 1997 when Pentair purchased the General Signal Pump Group.

Gaso pumps are manufactured by National Oilwell Varco. Gaso was acquired as "Wheatley Gaso" by National-Oilwell in the year 2000. At the time, Wheatley Gaso was owned by Halliburton.

Skytop Brewster pumps are no longer available as new pumps. Skytop Brewster(Cnsld Gold), a unit of Hansen PLC"s Consolidated Gold Fields subsidiary, was acquired while in bankruptcy by National-Oilwell, Inc. in November, 1999.

The drill site has physically evolved with the advent of horizontal drilling and multiwell pads. No longer is a rig confined to drilling a single well before having to rig down, move to another location and rig up again. While this evolution is most prominent in North America, other land markets around the world, including Saudi Arabia and Argentina, are following suit. At the center of the evolution is the rig. Driven by the needs of operators and today’s operations, drilling contractors are stepping up the capabilities of horizontal drilling rigs. Fast moving – walking or skidding – AC rigs with 1,600-hp mud pumps and higher torque top drives are populating the global fleet.

North American onshore rigs are predominately occupied by horizontal, development drilling programs. For Patterson-UTI Drilling, more than 80% of its 200-plus active rigs across the US are drilling horizontal wells. Mike Garvin, Senior VP, Operations Support for the company, said he sees that percentage and total number increasing in the coming year, as E&P companies transition to greater levels of horizontal drilling activity in markets that historically were predominantly drilled with vertical wells, such as the Permian basin. “Additionally, horizontal lateral lengths are getting longer, leading to more complex wells.” That greater complexity combined with the desire for more drilling efficiency has made modern AC rigs the preferred rig class by many E&P companies.

Entering US land operations in 2011, BHP Billiton has since been drilling development wells in the Eagle Ford and Haynesville and appraisal wells in the Permian. “Our rigs are specified for drilling horizontal wells and predominately for drilling development wells, too,” Derek Cardno, VP of Drilling and Completions, said. “They’re all AC rigs, and most of them are skiddable. We’ve also turned them into fast movers.”

Besides rig mobility, “the two most important components for efficient pad development and drilling of long laterals are the mud pumps and the torque of the top drive,” Jay Minmier, 2014 IADC Chairman and President of Nomac Drilling, said.

In this overview of horizontal-drilling rigs, industry leaders from BHP, H&P, Nabors Drilling, Nomac, Patterson-UTI and Sidewinder Drillingshare their insights on rig components and capabilities necessary to meet the demands of onshore horizontal drilling.

No stranger to horizontal drilling, Nabors has been drilling horizontal wells in Prudhoe Bay since 1983 and participated in the Austin Chalk trend of the mid-’90s. Nabors has about 300 active land rigs across North America, South America, the Asia Pacific and Middle East, the preponderance of which are drilling horizontal wells. “We are seeing an increasing volume of horizontal drilling internationally, although we have been drilling sophisticated horizontal wells for many years in places like Saudi. A recent example is a record well drilled with one of our rigs, which achieved over 50,000 ft of reservoir contact. The shale reservoirs we are drilling in Argentina are so thick that the initial drilling is vertical, but we

expect over time horizontal drilling will be more prevalent,” Dennis Smith, Director, Corporate Development, said. “It’s not as big a proportion of the total work internationally as it is in the US, but it’s moving that way. I think in another five to 10 years, it will be.”

In North America, roughly 90% of Nabors’ rigs are drilling horizontally, and the industry is supporting the trend. “We’re seeing a big conversion in West Texas and the Permian Basin to horizontal drilling. Customers are switching. Where the majority of the wells they drilled were relatively straight just a year or two ago, now the majority is flipped to where they are going to be horizontal. We see a lot of customers converting drilling plans to horizontal,” Mr Smith said. Not only is the development phase of shales driving the trend but so is the horizontal development of conventional reservoirs, such as the Permian.

The benefit of horizontal drilling is far reaching and not confined to unconventionals or shales. “Horizontal drilling was first commercially applied in the conventional reservoir at Prudhoe Bay. The impetus was to mitigate coning in the reservoir, thereby reducing water and gas intrusion while also increasing well productivity. The economics at the time were a 30% increase in well cost yielded a doubling of production. Many of the wells were drilled in an undulating fashion to facilitate re-perforation over time” Mr Smith explained. With horizontal drilling, “you expose a lot more reservoir to the wellbore, and it’s particularly applicable where you have thinner zones. It’s really the reservoir that dictates it, and shale reservoirs, which require hydraulic fracturing to achieve commercial productivity, lend themselves to horizontal drilling.”

The shift to horizontal drilling has also changed the way operators pick their rigs. In the US, industry has historically classified rigs by the horsepower of the drawworks, which made sense for drilling vertical wells. Hoisting capacity used to be a primary consideration, but with horizontal drilling, it has become less important. “Today’s wells are often just as long as yesterday’s vertical wells in terms of measured depth, but they are generally shallower in terms of total vertical depth. Hence, hoisting requirements are lessened,” Mr Minmier of Nomac said.

Nomac’s customer base – Chesapeake Energy, EOG Resources, Continental Resources and Noble Energy, for example – is primarily in development drilling mode. Nearly 100% of Nomac’s fleet of 85 land rigs

is drilling horizontal wells. “When we talk to operators, they’re most interested in a rig with big mud pumps – 1,600 (hydraulic) hp with 7,500-psi fluid ends – and a higher-torque top drive, rather than drawworks horsepower,” Mr Minmier said. “It is common now to see a rig with a 1,000-hp drawworks, 1,600-hp mud pumps and a higher-torque top drive drilling just as efficiently as a similar rig with 1,500-hp drawworks.”

The acceleration of horizontal drilling has led to numerous changes in rig capabilities, such as increased pipe racking capacity and higher hydraulic horsepower, which in turn requires additional power. “Because the measured depth of wells has increased significantly relative to the true vertical depth, you need more capacity to rack pipe so as to avoid having to lay down any drill pipe when tripping out of the hole,” Mr Smith of Nabors said. Hydraulic horsepower translates to bigger pumps, higher volumes and higher pressures necessary to drive the higher torque and RPM capabilities of today’s downhole motors.

mud pumps. In December 2012, 40% of the company’s rigs were equipped with two 1,600-hp pumps each. By December 2013, it was 52%. Today, 64% of Nomac’s fleet has 1,600 or higher horsepower mud pumps. The contractor also has 16 newbuilds in the works, all of which will be equipped with 1,600-hp pumps. Plans to upgrade other rigs that currently have lesser horsepower pumps are also under way. “By the end of next year, I expect 80% of our fleet to have 1,600-hp pumps,” Mr Minmier added. “That’s arguably the most important factor in determining how long and how efficiently a horizontal section can be drilled.”

With the greater well complexity and longer horizontal laterals, more mud pump pressure is needed to efficiently drill the wells. Accordingly, circulating systems are being upgraded to generate more hydraulic pressure. “We’re providing rigs now with 7,500-psi mud systems, when traditionally it had been limited to 3,500 or 5,000 psi,” Mr Garvin of Patterson-UTI explained. This allows for more hydraulic horsepower to drill extended-reach horizontals quicker.

Sidewinder Drilling, which has 42 land rigs in the US, is constructing two newbuilds – one to be delivered in January and the second in March 2015. Both are likely to operate in Texas and will be equipped with 7,500-psi mud pumps. “We selected the Weatherford7,500-psi mud pumps with permanent magnet motors as we believe they will be more reliable, more powerful and lighter weight than conventional mud pumps,” Jon Cole, Chairman & CEO of Sidewinder said. Permanent magnet motors are smaller and lighter than conventional AC motors. “They can run for longer periods at maximum output than conventional motors.”

Nabors Drilling has also observed more requests for 7,500-psi pumps, which are being retrofitted onto older rigs. “The long-standing standard has been a capability of 5,000 psi,” Mr Smith explained. “To go to that higher pressure, you need to change out the fluid ends and high-pressure piping.” The higher psi allows operators to take advantage of new efficiencies in the drill bits, the high-torque motors and the bigger, faster drilling motors. “It all benefits rate of penetration and the ability to clean the hole efficiently.”

Through 2015, Nabors will add 60 rigs to its fleet, all of which will have the option for 7,500-psi pumps. In North America, about 20% of Nabors’ fleet of 300 rigs is outfitted with 7,500-psi pumps. “We are now installing the higher-pressure piping into all of our new and upgraded rigs so that they can be readily retrofitted,” Mr Smith said.

In the Haynesville, BHP Billiton has specified mud pumps to 7,500 psi. “That’s helped us a lot because they’re higher mud weight, longer-reach wells (reaching 18,000 to 19,000 ft) with a small hole size,” Mr Cardno stated. BHP is using 4-in. drill pipe in the reservoir section in the Haynesville, while using either 4 ½ or 5 in. in the lateral section in other plays. “Because we’re TDing wells in 6 ¼-in. hole, that’s the optimum drill pipe size, and the 7,500-psi capability has helped our performance in Haynesville by allowing full flow rate to total depth.”

Hydraulic horsepower is to mud pumps as torque is to top drives. However, while the top drive plays a critical role in horizontal drilling performance, it also is a key point for failure. “The top drive is by far our leading cause of downtime,” Mr Cole of Sidewinder stressed. He urged manufacturers to improve quality control and equipment uptime, as well as ensure the availability of spare parts.

The wells that Sidewinder is drilling in Appalachia, particularly in the Utica, have a longer horizontal section than what they’re drilling in the Marcellus, where they generally run 7,000 to 12,000 ft. “The hydraulic top drives that we had before lack the torque to really effectively execute the programs in the Utica,” Mr Cole stated. “On our 1,500-hp AC rigs, we prefer 50,000-ft-lb continuous torque. On the new mechanical rigs, we’re upgrading from hydraulic 20,000 ft-lb units to AC-electric powered top drives with up to 30,000 ft-lb of torque.” While high-torque top drives have been in use offshore, a typical 1,500-hp land rig uses a 30,000 ft-lb torque top drive. “Demand is increasing for higher torque capacity top drives,” he added.

In the Haynesville, BHP drills intermediate sections with hard, 40,000-psi compressive strength rock. “That needs more torque capability in the top drive,” Mr Cardno explained, which the operator is able to achieve with Nabors’ PACE-X rigs. The operator began deploying the PACE-X rigs in 2013; the rig features a 500-ton Canrig AC top drive with

Operator demands for higher-torque top drives are leading to a shift away from hydraulic top drives in favor of AC-electric units. Approximately 78% of Nomac’s rigs have AC top drives. Similar to the mud pump trend, Mr Minmier foresees a continued shift in Nomac’s fleet to reach 90% by the end of next year, as all of Nomac’s 16 newbuilds will include AC top drives and others will be upgraded.

“We’ve been going through a significant upgrade process for the last two years, adding bigger mud pumps, adding AC top drives, adding skidding and walking systems, adding hydraulic catwalks, Iron Roughnecks – all the features that operators are requesting. Eventually, the fleet will be all AC top drives, all 1,600-hp mud pumps, all skidding and walking. It’s just a matter of time,” Mr Minmier said.

For land rigs, there are two facets to mobility: the ability to move from location to location and the ability to move from well to well on the same location. The latter has taken on greater significance due to pad drilling, although the former remains key to the efficiency of the overall drilling operation. “A decade or so ago, rigs were being designed and marketed as

being fast moving, meaning they can quickly move from one location to another. In that context, it was how fast can you rig-down, move to a new location and rig back up,” Mr Minmier explained. “With the prevalence of pad drilling, it’s becoming more critical how efficiently a rig can move from well to well on the same pad. It’s not uncommon to see land rigs today doing only two or three location rig moves in a year, and they used to do 15.”

In the Eagle Ford, Bakken and Marcellus, H&P is now primarily drilling multiwell pads. “I see West Texas becoming more and more of a multiwell pad area, as they define the areas and go into development,” Mr Millwee said. “In the Mid-Continent area, specifically in the Woodford, we’re seeing more of a push toward pad wells again. We’ve had some pad wells and some single wells there, but we see that one shifting to almost an all-pad environment.”

The significance in pad drilling systems is prominent in terms of reducing nonproductive time. “It’s a lot of these non-drilling activities where the opportunities (to improve efficiency) lie. Being able to move a rig quickly is a huge efficiency, where it traditionally takes three or four days to move a rig from pad to pad, we can literally walk to the next well on a pad in 45 minutes,” Mr Garvin of Patterson-UTI said.

Since the early ’70s, Nabors has deployed skidding/walking systems at Prudhoe Bay and in desert applications in the Middle East, including Saudi Arabia. The technology has evolved from lift-and-roll to stomper systems since early 2000s. Approximately 75% of Nabors’ US fleet – including approximately 150 AC rigs – have walking systems; outside the US, about 33% of its rigs are equipped. The configuration of the newest AC rigs with walking systems provides more flexibility over a skidding system. “The walking systems have a little more

The new generation of mast and substructures allows drilling contractors to rearrange its rigs to reduce the number the loads and connections, making the rigs move a lot more efficiently between locations. “It’s still important to move rapidly between pads and with smaller-sized loads requiring fewer permits,” Mr Smith said. “In 2005, when we started building a lot of new rigs, the use of AC drives and digital controls facilitated repackaging the rig into fewer loads because the equipment’s lighter and has fewer complex connections.”

Automation is on the horizon for land drilling. While automation has made more headway offshore, onshore drilling contractors also realize there are opportunities for automation to improve

operations and increase efficiencies. “One aspect of automation is automating the drilling of the well downhole,” Mr Garvin said. “Electronic drilling systems on the rig offer very precise control over the hoisting, rotary and circulating systems on the rig.” This precision allows the rig to maintain an optimal weight on the bit to maximize drilling efficiency. Additionally, precise control of the rig’s systems allows for the use of newer, more advanced downhole drilling tools to further increase drilling efficiency.

While today’s horizontal drilling rig is capable of meeting operator demands, Mr Cardno of BHP believes there are opportunities to further optimize the drilling rig and operation. “We do things that take hours that if we really got focused on them, we could potentially do it in minutes,” he stated. Alluding to Formula 1 race cars, he described how crews have “gone from changing tires from 15 seconds to doing it in 2 or 3 seconds. They probably thought they were doing it really fast when they were doing it in 15-20 seconds.”

The land drilling market worldwide is structured primarily as a rental market, not a sales market, where land drilling companies lease their rigs to E&P companies for an agreed period of time – weeks, months, or years – at a day-rate. The rigs are then used to drill wells and execute the E&P’s drilling programs.

Drilling opportunities are analysed and explored in order, leaving a series of dry holes, until a discovery is made. It is rare for an E&P company to actually own the rigs which they operate, but there are some exceptions such as Chesapeake, who will purchase their own fleet of rigs.

Investors require a minimum level of return for their investment dollars in drilling operations, and typically equate cost with risk. These turnkey drilling contracts may limit risk by guaranteeing a minimum number of wells that can be drilled with the rig. The contract will also outline how the rig can be used – including the pieces of equipment, when to change pieces, temperature and pressure tolerances and the weight of mud.

The International Association of Drilling Contractors (IADC) lists 547 members in the category of Land Drilling Contractors. According to Statista, the key US land drilling contractors are: Nabors Industries Ltd, Helmerich & Payne Inc, Patterson-UTI Energy Inc, Precision Drilling Corporation and Pioneer Energy Services Corp.

Nabors operates the world’s largest land drilling rig fleet, with around 500 rigs operating in over 25 countries – in almost every significant O&G basin on the planet. It also has the largest number of high-specification rigs (including new AC rigs and refurbished SCR rigs) and custom rigs, built to withstand challenging conditions such as extreme cold, desert and many complex shale plays.

Headquartered in Tulsa, Oklahoma, H&P is a global business with land operations across the US, as well as offshore operations in the Gulf of Mexico. It is engaged primarily in the drilling of O&G wells for E&P companies, and recognised for its innovative FlexRig technology.

Patterson-UTI operates land based drilling rigs, primarily in O&G producing regions of the continental US, and western Canada. The company also provides pressure pumping services to US E&P companies and specialist technology, notably pipe handling components, to drilling contractors globally.

Precision is an oilfield services company and Canada’s largest drilling rig contractor, with over 240 rigs in operation worldwide. The Company has two segments. The Contract Drilling Services segment operates its rigs in Canada, the United States and internationally. The Completion and Production Services segment provides completion and workover services and ancillary services to O&G E&P companies in Canada and the US.

Pioneer operates a modern fleet of more than 24 top performing drilling rigs throughout onshore O&G producing regions of the US and Colombia. The company also offers production services include well servicing, wireline, and coiled tubing services – supported by 100 well-servicing rigs, and more than 100 cased-hole, open-hole and offshore wireline units.

Together these five companies dominate the US rental market. Other smaller but prominent contractors include: Parker Drilling, Unit Corp, Independence Contract Drilling, Seventy Seven Energy, Schramm and Ensign Drilling. Beyond these players, the market is highly fractured, with many “mom & pop” style drillers.

In Texas, generally considered to be the centre of US land drilling, RigData reports that there are currently 678 active rigs – split between Helmerich & Payne (160), Patterson-UTI (85), Nabors (64), Precision Drilling (39) and 77 other drillers (330).

Most new onshore rigs, both drilling and work over rigs, are built by OEMs in China. In the US, the larger vertically integrated land drillers have in-house manufacturing operations, so they will outsource some equipment construction, but assemble the new rigs at their own facilities. The leading provider of US newbuild rigs is National Oilwell Varco.

Company OverviewNabors Industries owns and operates one of the world"s largest land-based drilling rig fleet and is a provider of offshore drilling rigs in the United States and multiple international markets. Nabors also provides directional drilling services, performance tools, and innovative technologies for its own rig fleet and those of third parties. Leveraging our advanced drilling automation capabilities, Nabors’ highly skilled workforce continues to set new standards for operational excellence and transform our industry.

Nabors is committed to providing equal employment opportunities to all employees and applicants and prohibiting discrimination and harassment of any type without regard to race, religion, age, color, sex, national origin, disability status, genetics, protected veteran status, sexual orientation, gender identity or expression, or any other characteristic protected by federal, state or local laws. This applies to all terms and conditions of employment including recruiting, hiring, placement, promotion, termination, layoff, recall, transfer, leaves of absence, compensation and training. To learn more about our Fair Employment practices, please refer to the Nabors Code of Conduct .

Title: DerrickhandOverview: The Derrickhand is responsible for ensuring the smooth operation and support function of the mud module (sack area, mud pumps and mud pit / shakers). The Derrickhand works under the direction / supervision of the Driller, but reports directly to the Rig Manager.

Key Relevant TasksPreventive maintenance and general repairs to the mud pumps and associatedequipment including changing out the mud pump liners, as requested by the

Working above the drilling floor, on the monkey board, guiding the drill pipeduring the tripping-in/tripping-out process, ensuring to wear proper safety

Nabors owns and operates the world"s largest land-based drilling rig fleet and has one of the largest completion services and workover and well servicing rig fleets in North America. Our company is a leading provider of offshore platform workover and drilling rigs in the U.S. and multiple international markets. Nabors provides innovative drilling technology and equipment, directional drilling and comprehensive oilfield services in most of the significant oil and gas markets in the world.

The job of the Floorhand is to safely and efficiently perform all manual labor tasks on the drilling floor and B.O.P. area. The Floorhand works under the direction/supervision of the Driller, but reports directly to the Rig Manager.

Must be able to stand and walk for a minimum of 4 hours at any one time, including standing and walking on steel decking as well as gravel, board roads and mud, snow and ice

* During daily rig visits, utilizes the Safety Checklist developed by the HSE department. The checklist documents deficiencies in Fall Protection, Safety Equipment, Best Practices, JSA"s and daily safety paperwork. Assist drill crew and rig manager with correction of the deficiencies. Report to Drilling Superintendent and HSE Supervisor those areas where assistance is needed to correct deficiencies.

* Perform incident investigations to find corrective actions for Near Misses, IFO"s, FSA"s and FAP"s. Report corrective actions to the Drilling Superintendent, HSE Supervisor and Operator, if requested.

* Utilizing the DSAIL (Drill Site Action Item Log), record items needing correction resulting from investigations, checklists and audits. Email Rig DSAIL to Drilling Superintendent and HSE Supervisor to monitor completion of action items.

1. Over 10000 sets of centrifugal pump are widely used in overseas market including United States (Nabors), Russia South America, Middle Asia and Middle East. 4 patents given to the SB series centrifugal pumps including special mechanical seal technology ensures long service life, no leaking within more than 1 year. Special designed impeller improves the centrifugal pumps" efficiency and energy-saving by 10%.

2.The centrifugal pumps are made of high-wearable cast irons to improve the service life by 50%. Front opening structure for easy installation and maintenance of the centrifugal pumps.There are six models of the SB serial centrifugal pumps, namely SB8×10, SB6×8, SB5×6, SB4×5, SB3×4 and SB2×3, with engine power ranging from 4Kw to 110Kw, totaling more than 80 of specifications.

3.The centrifugal pump is either in the unit construction structure or in belt transmission structure, suitable for power grids of 50Hz and 60Hz. It also has both Metric and British systems as measuring standards and clockwise and anticlockwise rotary directions.