pulling unit vs workover rig made in china

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Super capacitor energy storing dual—power workover rig mainly consists of Diesel engine power unit which is made up of Diesel engine and Hydraulic transmission box, Electric power unit which is made up of Frequency conversion motor and Mechanical transmission box, Transfer case, Angle gear box, Drawworks, Mast assembly, Super capacitor energy storing and control system, Hydraulic and Pneumatic control system, Voltage transformer, Power connection box, MCC control cabinet, Frequency conversion cabinet, Electric air compressor, Electric hydraulic pump station etc.

The power of Diesel engine is used for the heavy load workover job of workover rig, such as running and jam release etc. The power of Frequency conversion motor is used for the normal trip—up and down operation

SCOPE: To provide a representative basis for determining the availability, capability, dependability, reliability of Stability Systems on Land Based Work-Over Rigs and the recommended practices and procedures for their safe use.

A typical double derrick with load guys in place in Figure 2-1. The sub-structure is in place and the unit properly configured to begin installation of the guying system. From this configuration determination can then be made as to the proper selection, location, configuration and holding capacity of guy anchors. Load guys should meet manufacturers recommendations. In the absence of manufacturers recommendations, the minimum wire rope diameter should not be less than that which is recommended by a representative of a major, oil field recognized, wire rope manufacturer.

The rig location area may grade away from the well bore along centerline II at a maximum drop of 1:20. The cross grades, parallel to centerline I, should be level. The area shall provide a minimum bearing capacity of 6000 psf.

Using the chart: An anchor in Zone "A" located a horizontal distance of 70 feet from the "Well Head" would require an anchor of what minimum holding capacity? On the chart move along the horizontal legend from left to right until you reach 70 feet. At this juncture proceed vertical until you intersect the curved line for Zone "A", now follow the intersecting horizontal line, left toward the vertical legend. We have now determined that the minimum holding capacity for the anchor, at this precise location, is 20,000 pounds.

Standing at the "Well Head", with the well bore immediately to your back, proceed North (in direction monkey board is facing) 24 paces. (The pace length is not as important as the numerical relationship of the units and the consistency of the unit length. The method will work with any unit of length as long as the same unit is used throughout.) Place a stake or other marker at this location (Bench Reference). Turn West 90 degrees and proceed forward 10 paces. At this location turn your body so that the front portion of your anatomy is approximately parallel to the radial of the guy anchor. If the northwest guy anchor is forward of your right shoulder and the southeast guy anchor is aft to the rear of your left shoulder, it can then be presumed that the radial angles are within acceptable parameters. Repeat the procedure from the bench reference, this time to the east, proceed ten paces. In this orientation the northeast anchor should be forward of the left shoulder and the southwest anchor should be aft of the right shoulder.

A survey of 13 drilling contractors operation 193 drilling rigs in northern Canada and Alaska indicated that there is a wide range of experience and operating practices under extremely low temperature conditions. While there is very little precise information available, there have been a sizeable number of failures in portable masts while in the lowering or raising process in winter. Thus the exposure to low temperature failures focuses on mast lowering and raising operations. Based on reports, however, this operation has been accomplished successfully in temperatures as low as -50 degrees F. While the risk may be considerably greater because of the change in physical characteristics of steel at low temperatures, operators may carry on "normal" operations even at extremely low temperatures. This may be accomplished by a program of closely controlled inspection procedures and careful handling and operation. This should reduce damage and impact loading during raising and lowering operations. At the present, there seems to be no widely accepted or soundly supported basis for establishing a critical temperature for limiting the use of these oilfield structures. Experience in the operation of trucks and other heavy equipment exposed to impact forces indicates that -40 degrees F may be the threshold of the temperature range at which the risk of structural failure may increase rapidly. Precautionary measures should be more rigidly practiced at this point. The following recommended practices are included for reference:

If maintained to these tolerances the sags will indicate a pretension of 1000 pounds for crown to ground guywires and 500 pounds for tubing board guywires. this is based on the use of 5/8 inch, 6x19, or 6x37 class, regular lay, ips, IWRC wire rope, installed according to the rigging guidelines set forth in chart depicted in Figure 5-5

All clips must be drop-forged steel; malleable iron clips must never be used. Wire Rope Clips, of the proper type, have the advantage of allowing thorough examination and ease of field installation. Properly installed wire rope clips will develop 80% of the rope strength. This 80% efficiency can only be assured if thimbles are used. A combined clamp and thimble unit is also capable of developing 80% of the wire rope strength.

The drawing on the following page, Figure 5-4, (SAME AS FIGURE 4-4) is another illustration of the continuing evolution of Rig Stability System engineering and design. It represents the latest API thinking relative to planing and preparing a Rig Stability System.

CAUTION: SOLE EMPHASIS SHOULD NOT BE PLACED ON PULL TESTING OR ALTERNATIVES TO PULL TESTING AS THIS MEASURES ONLY ONE COMPONENT OF THE RIG STABILITY SYSTEM.

The rig contractor should be responsible for the following: a. Insuring that anchor capacities are verified and that anchor spacing and capacity is suitable for the mast guying pattern and anticipated loading.

b. Records of pull testing or records of other methods used to verify temporary anchor capacity should be retained by the rig contractor until the job is complete and the guy wires have been removed from the anchors. The records should indicate the capacity of each anchor, the date of verification, name and phone number of the party responsible for verification, and the soil condition at the time of verification.

OUT OF AN ABUNDANCE OF CAUTION IT IS EXTREMELY IMPORTANT TO POINT OUT THAT THE PREVENTION OF RIG UPSET IS DIRECTLY DEPENDENT ON THE TOTAL INTEGRITY OF THE RIG STABILIZATION SYSTEM. THE SYSTEM INCLUDES ALL OF ITS COMPONENTS AND IS ONLY AS SOUND AS ITS WEAKEST MEMBER.

Our research has concluded, that the latest State-of-the-Art in RIG STABILIZATION is to be found in the pending American Petroleum Institute, Recommended Practice for MAINTENANCE and USE of DRILLING and WELL SERVICING STRUCTURES.

WILSON WELL SERVICE RIG  (Ref#3000Ta)  103’ x 248,000# derrick, Out of service since 2017, lot of rust, will start and run and/or drive down the road POR

Refurbished, 700 hp, Double drum 2042 drawwroks with Parmac 202 brake assist, (2) Caterpillar 3406 Engines, (2) rebuilt Allison 750 6 speed auto transmission with reverse. 112" x 300,000 # hook load capacity on 8 lines, clear height 97 feet, leg spread  7" 6-1/2", racking board, oil bath chain case, elevated rotary drive, all raising lines and guidelines. The Draw-works, hydro-mantic break, and crown assembly have been rebuilt. Heavy duty Draw works drive propeller shaft through right angle gear box, rotary drive propeller shaft, heavy duty reverse gear box and oil bath roller chain, and a self-locking handling winch.  Mounted on triple front axle mechanical 6 axle carrier with 134,000# capacity designed to meet highway safety standards with necessary toughness for off road operations.  Price:  $265,000

Derrick fell onto rig when being raised, derrick would need to be replaced or repaired.  Built 1981, double drum, 42 x 12, 42 x 8, swab drum removed from jack shaft, 5-axle back in carrier, 250,000# derrick with double racking board and triple rod basket, Cat 3408, CLT 5860 transmission, Cooper right angle box, 4 hydraulic leveling jacks, air rod transfer in derrick, hydraulic winch, Kerr 6 cyd 10000 psi Mustang pump powered from jack shaft, Kerr 3-valve release 10,000 psi, tong carrier f/Foster, steel work platform, Parmac 22 SR hydromatic brake.  Extra rebuilt 3408 Cat engine.  Price as is:  $112,500

Manufactured 1981, mounted on 5 axle carrier, double triple service rig, 96’ x 250,000# derrick, Detroit Series 60 12.7 diesel engine, Allison transmission, 9/16” sandline, 1” drill line,  hydraulic jacks, hydraulic catwalk, travelling block, tubing bard, rod basket and all necessary lines.  Tooling not included.  Price:  $115,000

Manufactured 1983, double drum, 96’ x 180,000# derrick, mounted on 5 axle carrier with 92T engine, Allison transmission  Price rig only:  $300,000  Price with tooling:$340,000

WILSON 42 WELL SERVICE RIG(Ref#7562Ta)  Manufactured 1975, 180,000# Pemco double/triple derrick, mounted on Wilson carrier with Detroit 8V71 engine, 4 hydraulic leveling jacks, ready to work  Price rig only:  $74,500  Price with tooling:  $94,500

Manufactured 1983, 70" x 120,000# non telescoping stiff mast, double drum 26 x 8, Detroit 6V71 diesel engine, 740 Allison transmission with Spicer power divider, mounted on 4 axle carrier.  Rig runs and truck drives, stacked for several years, good condition  Price:  $93,500 USD

FRANKS 500 WORKOVER RIG(Ref#7615Tc)  Built 1980, refurbished 2018, 102" x 250,000# mast, mounted on 5 axle carrier, new engine and transmission, 150 ton blocks, 15,000’ sandline, ready to work  Price:  $495,000

FRANKS 300 SERVICE RIG(Ref#1169Ta)  4-legged derrick, Series 60 Detroit engine, 6850 Allison transmission, blocks, Foster tongs, mounted on 4 axle carrier, working condition  Price:  $37,500

WILSON MOGUEL 42 WELL SERVICE RIG(Ref#3177Tb)  Two available, 96" x 280,000# mast, Detroit Series 60 engine, 5860 Allison transmission, mounted on 5 axle Wilson carrier, handling tools  Price:  $315,000

Workover rig with 83’ telescoping derrick, 10’ crown extension, 200,000# lift capacity, 100,000# snubbing capacity.  Catwalk with 42’ reach, forward and revere motion, hydraulic pipe slide, six portable pipe racks, powered by workover rig.  5000 ft/lb hydraulic rotary, 15k psi working pressure capability kelly hose, 300 ton mast with 5 x 5 heavy wall box tubing and 2 x 2 heavy wall cross sections, (2) mast raising cylinders, 9-1/8 x 25’ telescoping cylinders/crown sheaves with cable guides, (2) winch sheaves/snubbing sheaves, SRS fall protection, retractable flow tube design, non-swivel boom pole on curb side winch, (2) mast supports, 1” lifting cables, mounted on 5 axle Crane Carrier (3rd axle drop), with 375k Volvo Penta engine, 150 gal fuel capacity, hydraulic self-leveling components, 6 speed Allison transmission, 1:1 gear box, (2) 65 gpm pumps, (2) 30 gpm pumps, (1) 28 gpm Commercial shearing pump, 40 gal accumulator storage, single man cab, hydraulic leveling jacks  Price on Request

Manufactured 1960’s, double drum, single rig mast, 64’ x 250,000# (tubing and rod racks), 70 ton blocks, 2 lines, Detroit diesel 60 gpm @ 2000 psi, hydraulic system, air clutch.  Rig was refurbished 2013/2014 at a cost of $130,000: repairs included used 65’ derrick installed, new 1” main line, repairs to air system, hydraulic system upgrade, leveling jacks, derrick ljghting, tires, 70 ton blocks installed.  But the rig has been sitting since 2015 and now needs rebuilding. It doesn’t run.    Price as is: $19,500

Manufactured 1980, completely refurbished 2004, 5 axle double drum well service unit, double 15 Parmac brake on main drum, 96" x 180,000# hydraulic raised mast, mast lighting, Detroit 60 Sereis engine, 5860 Allison 6 speed transmission, 4 hydraulic leveling jacks, dual manual outriggers, PD12 Braden utility winch, McKissick 100 ton tubing block 21-31 diving, 1000" of 1" tubing line, 13000" of 9/16" sandline  Price:  $225,000

CARDWELL KB200B SERVICE RIG(Ref#11674Ta)  72’ x 140,000# stiff mast, 40 x 10 double drum drawworks, 2 aux deck winches, tubing board, rod board, cat walks, railing, stairs, floor BOP controls and accumulator bottles, McKissick 75 ton tubing block and hook, mounted on 5 axle carrier, Detroit 8V71 diesel engine, Alliston CLBT4460 auto transmission PRICE:  $127,500

Rig manufacture 1980, mounted on 1980 GMC Brigadier with Cat 3208 engine, includes elevators & misc tools, also includes 1996 1-ton Super Duty tool truck, tandem axle, Cat 3208 diesel, sitting 1-1/2 years  Price:  $92,500

1980, 475 hp, single drum (new), reworked, 96" x 205,000# hydraulically raised mast, 6 lines,  crown block: 3 new sheaves blocks and bearings, racking board, guide wires, (2) hydraulic hoist, weight indicator, block, elevator links, fall safety device, work platform, mounted on 4 axle carrier with Detroit Series 60 diesel engine, Allison transmission, rig in excellent condition and has been well maintained, ready for use   PRICE: $115,000

SKYTOP BREWSTER RR400(Ref#13190T) Mounted on 4 axle carrier, single drum drawworks, 8x7 disc assisted brakes, tubing board, Cat3406B engine, Allison 860DB transmission, 100 ton McKissick block, Foster 58-92R tongs, misc hand tools, approx 36" base beam for rig, ready to work  Price:  $110,000

Refurbished 2017, 4 lines, 96’ x 205,000# mast, 8V71 Detroit engine, mounted on CCC, 75 ton McKissick blocks, tubing board, rod basket, work platform, rigged up and working in field  Price:  $295,000

Manufactured 1977, 72’ x 125,000# derrick, 8V71 Detroit engine (rebuilt), Allison 750 transmission, 6500’ of new 5/8” sand line, tubing line new, drum brakes new, new style McKissick blocks, working daily  Price rig only:  $157,500

Double drum drawworks with hydromatic brake, 10" brakes, 96" x 180,000# derrick, mounted on 4-axle PEMCO carrier with hydraulic support legs, 8V71 Detroit, 4460 Allison transmission, Spicer 784 split shaft gearbox, 250 hp right angle drive, 650" of 7/8" tubing line, 8000" of 9/16" swab line, 100 ton Sowa block, hydraulic winch, hydraulic weight indicator, 84" links, 2-3/8" and 2-7/8" tubing elevators, BJ tubing slips, Foster 5893R power tongs with lift in derrick, rod hook, rod stripper, rod elevators, wrenches, transfers, rod fishing tools, misc hand tools and connections  Price:  $140,000

Manufactured 1974, double drum drawworks,  double triple 96" x 180,000# derrick with a hydromatic. The rig has working line with heavy traveling block and approx. 12,000" 9/16 sand line. Mounted on Skytop carrier with tandem steering and rear ends 4 axles W/ tag axle, 4 leveling jacks, powered by an 8V-71 with a Allison 4460 transmission, (note transmission was overhauled in early 2000"s) and the engine has a new head on right bank. The rig has two leveling jacks on the rear and two leveling jacks on the front which are located right behind the steering axels. Tooled out with hydraulic rod and hydraulic tubing tongs, air slips, rod and tubing elevators, hand tools and misc over items. PRICE REDUCED:  $115,000

10 x 13 pole, double Drum, Franks 33” air over grease, brakes in good shape, 7/8” tubing line, tubing blocks, tong pressure adjustment, hi/low on tubing, air slips control, master kill on drawworks, Foster 36 with 8’ lift ram, air backup, swing around tong rack, mounted on 2001 Freightliner F80 truck, Cat C12 Series 3125, Fuller 9-speed transmission, PTO, winch for pole scope Tulsa 48, blocks raise pole, dual fuel tank, dual battery, 50 gal hyd tank, toolboxes, hydraulic outriggers, BJ rod tongs, ¾” and 7/8” heads, tools, swabs, extra tongs, orbits, drilling head  Price:  $242,500

Double drum (second drum is removed, rig is running as single drum), hyd pole and down riggers, mounted on 1990 Crane Carrier, 9 sp Eaton Fuller transmission, 100,000 miles, 8 x 10 telescoping poles, 3/4” cable, no tooling  Price:  $52,500

10 x 13” pole, single drum, mounted on 1980 Brigadier 9500 Series truck with 671 inline Detroit, drop box, travelling blocks, tubing lines, hyd jacks, no tooling, sitting since 2000  PRICE:  $49,500

Cable Tool Drilling and Completion Rig, 60" double poles rated to 150,000#, 5000" drill capacity, 10,000" pull capacity, propane Waukesha 145 engine, 500 gal propane tank, trailer moutned with International 4300 truck, last drilled 2012, 2300" drill line on drum, 3500" on spool casing drum, heavy block sandline drum, cat heads each side, tooling, spare engine  Price:  $72,500

400’ of 7/8” block line, 9/16” sandline drum (no cable), 2000’ of ¾” drilling drum, 3 McKissick sheaves, air clutches and controls, mounted on 1961 Mack truck with 250 hp Cummins engine, older rig but runs good.  Includes elevators, oil saver pump, no BJ tongs, currently working.  Price:  $87,500 - Pennsylvania

Triple drum, friction clutch, cathead (sandline holds 2400’ of 5/8” line), mounted on tandem axle Chevy truck with 427 gasoline engine, 8-5/8” x 45’ single pole, new tires, power steering, wireline unit, good usable rig for shallow oil/gas lease, drills, workover, swab capabilities, no tools  Price:  $112,500 - Oklahoma

Their exceptional mobility, stability, and ease of operation are the outcome of our extensive experience in the design and production of mobile drilling rigs.

Belonging to the same family, Sovonex™ service rigs comprise many of the technological advantages that result in smooth operation and make the life of our customers’ easier:

Wide selection: At our production facility in China we design and develop workover rigs for service depths ranging from 1,600 m to 8,500 m (5,250 ft-27,900 ft), and workover depths from 2,000 m to 9,000 m (6,600 ft-30,000 ft) for 2 7/8” DP.

Full API coverage: The different components of our well-servicing rigs are manufactured to the following API standards:Steel structures, such as the mast: API Spec 4F

Highly maneuverable : Sovonex™ mobile drilling rigs and self-propelled workover rigs possess excellent driving properties in the desert, mountain, and other impassable terrains.

Reduced NPT: The mast is erected hydraulically to reduce time for rig up and increase safety. Likewise, all rig components have been designed to allow for fast assembly and disassembly.

With every service rig, we send technical staff to our customer to provide first-hand technical support. The engineer responsible for the rig design is always part of the service crew.

An oil well is a boring in the Earth that is designed to bring petroleum oil hydrocarbons to the surface. Usually some natural gas is released as associated petroleum gas along with the oil. A well that is designed to produce only gas may be termed a gas well. Wells are created by drilling down into an oil or gas reserve that is then mounted with an extraction device such as a pumpjack which allows extraction from the reserve. Creating the wells can be an expensive process, costing at least hundreds of thousands of dollars, and costing much more when in hard to reach areas, e.g., when creating offshore oil platforms. The process of modern drilling for wells first started in the 19th century, but was made more efficient with advances to oil drilling rigs during the 20th century.

Until the 1970s, most oil wells were vertical, although lithological and mechanical imperfections cause most wells to deviate at least slightly from true vertical (see deviation survey). However, modern directional drilling technologies allow for strongly deviated wells which can, given sufficient depth and with the proper tools, actually become horizontal. This is of great value as the reservoir rocks which contain hydrocarbons are usually horizontal or nearly horizontal; a horizontal wellbore placed in a production zone has more surface area in the production zone than a vertical well, resulting in a higher production rate. The use of deviated and horizontal drilling has also made it possible to reach reservoirs several kilometers or miles away from the drilling location (extended reach drilling), allowing for the production of hydrocarbons located below locations that are either difficult to place a drilling rig on, environmentally sensitive, or populated.

The well is created by drilling a hole 12 cm to 1 meter (5 in to 40 in) in diameter into the earth with a drilling rig that rotates a drill string with a bit attached. After the hole is drilled, sections of steel pipe (casing), slightly smaller in diameter than the borehole, are placed in the hole. Cement may be placed between the outside of the casing and the borehole known as the annulus. The casing provides structural integrity to the newly drilled wellbore, in addition to isolating potentially dangerous high pressure zones from each other and from the surface.

The pipe or drill string to which the bit is attached is gradually lengthened as the well gets deeper by screwing in additional 9 m (30 ft) sections or "joints" of pipe under the kelly or topdrive at the surface. This process is called making a connection. The process called "tripping" is when pulling the bit out of hole to replace the bit (tripping out), and running back in with a new bit (tripping in). Joints can be combined for more efficient tripping when pulling out of the hole by creating stands of multiple joints. A conventional triple, for example, would pull pipe out of the hole three joints at a time and stack them in the derrick. Many modern rigs, called "super singles", trip pipe one at a time, laying it out on racks as they go.

This process is all facilitated by a drilling rig which contains all necessary equipment to circulate the drilling fluid, hoist and turn the pipe, control downhole, remove cuttings from the drilling fluid, and generate on-site power for these operations.

The production stage is the most important stage of a well"s life; when the oil and gas are produced. By this time, the oil rigs and workover rigs used to drill and complete the well have moved off the wellbore, and the top is usually outfitted with a collection of valves called a Christmas tree or production tree. These valves regulate pressures, control flows, and allow access to the wellbore in case further completion work is needed. From the outlet valve of the production tree, the flow can be connected to a distribution network of pipelines and tanks to supply the product to refineries, natural gas compressor stations, or oil export terminals.

Workovers are often necessary in older wells, which may need smaller diameter tubing, scale or paraffin removal, acid matrix jobs, or completing new zones of interest in a shallower reservoir. Such remedial work can be performed using workover rigs – also known as pulling units, completion rigs or "service rigs" – to pull and replace tubing, or by the use of well intervention techniques utilizing coiled tubing. Depending on the type of lift system and wellhead a rod rig or flushby can be used to change a pump without pulling the tubing.

Often, unwanted (or "stranded" gas without a market) gas is pumped back into the reservoir with an "injection" well for storage or for re-pressurizing the producing formation. Another solution is to convert the natural gas to a liquid fuel. Gas to liquid (GTL) is a developing technology that converts stranded natural gas into synthetic gasoline, diesel or jet fuel through the Fischer–Tropsch process developed in World War II Germany. Like oil, such dense liquid fuels can be transported using conventional tankers or trucking to users. Proponents claim GTL fuels burn cleaner than comparable petroleum fuels. Most major international oil companies are in advanced development stages of GTL production, e.g. the 140,000 bbl/d (22,000 m3/d) Pearl GTL plant in Qatar, scheduled to come online in 2011. In locations such as the United States with a high natural gas demand, pipelines are usually favored to take the gas from the well site to the end consumer.

The cost of a well depends mainly on the daily rate of the drilling rig, the extra services required to drill the well, the duration of the well program (including downtime and weather time), and the remoteness of the location (logistic supply costs).

Center, Petrogav International Oil & Gas Training (2020-07-02). The technological process on Offshore Drilling Rigs for fresher candidates. Petrogav International.

Workover rigs, also called pulling unit rigs, are specialized oil rigs set up for inserting or pulling pipe tubing in and out of wells. Workover crews are called when an oil well has been drilled, is undergoing repair or is being retired, as indicated by Schlumberger.

These crews are relatively small compared to other rig crews and consist of tool pushers, operators or relief operators, derrick men and floormen or roughnecks. The average workover rig salary overall was ​$65,039​ as reported by Simply Hired in 2022. Available workover rig jobs and descriptions can be found on the Rigzone website.

The acting supervisor on a workover rig is called the tool pusher. The main task of a pusher is to hire, fire and supervise contracting work crews. When contractors have an issue on site, the first person they report concerns to is the tool pusher. Pushers need to have an intimate knowledge of how each and every part of a rig works, both individually and as an overall part of the drilling operation as a whole.

If equipment fails or needs to be reordered, the tool pusher talks with suppliers to get the right parts out on site with a minimum of downtime for the rig. The pusher is responsible for the overall safety of a rig. If the tool pusher has any safety concerns, he has the power to halt production until the concern is resolved.

The operator/relief operator is next in order of responsibility to the tool pusher on a workover rig. The main task of an operator is to control the crane and derrick that hauls pipe in and out of the bored well. In smaller crews, the operator is also the one who drives the rig truck. When laying pipe into a well, the operator directs the truck or derrick to the optimum spot next to the bore opening.

The operator then instructs the derrick hands and roughnecks where to place the bore pipe for easy access by the crane or by hand-loading methods. During a well breakdown or repair, the operator directs the crew hands in storage of extracted pipelines. Because the operators work most closely with derrick hands and roughnecks, they are typically responsible for selection and maintenance of their immediate workover rig crew.

In the pulling unit rig crew hierarchy, the derrick hands come after the operator/relief operators. The main responsibility of a derrick hand is everything that is above ground on the rig. During laying operations, derrick hands assist the operators/relief operators in inserting boring into the well. During repair or breakdown, they assist the operator in pulling pipe out of the well and storing it properly.

In between laying, derrick hands have other responsibilities as well, depending on the size of the crews. In smaller crews, Derrick hands also see to the maintenance of the rig-based electric and diesel generators necessary to power rig equipment.

At the bottom of the pulling unit rig crew in terms of seniority is the floorhand or roughneck. The main task of a roughneck is to perform any kind of tasks asked by either the derrick hand or the operator. These tasks can range from assisting with laying new pipe or removal of old tubing, general construction, to moving new equipment, such as generators. Most crew members on a work-about start their career as a floorhand or roughneck before working their way up to more senior positions.

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Unit Drilling has put the first of its newly designed BOSS series, Rig 401, to work in the Texas Panhandle for Unit Petroleum. The 1,500-hp, AC-powered walking rig incorporates several features aimed at reducing the number of loads and increasing mobility, including a ram-raised box-on-box substructure. “What makes it unique is the top sub fits down over the lower sub for transportation,” John Cromling, Executive VP for Unit Drilling, explained. “It’s all hydraulically controlled – the raising, the pinning, etc. There’s not another substructure like this one.”

Excluding tubulars and camp facilities, the rig has 32-34 loads. However, the design of the rig was underpinned not just by a desire to have fewer loads but to manage the loads better, Mr Cromling said. For example, the BOSS rigs have been designed so that rig-up can begin with any part of the rig. “You could begin with the mud pits. You could begin with the substructure. You could begin with the engines. It can rig-up no matter which load arrives first. That facilitates a faster rig-up,” he said.

Throughout the design process, significant focus was also placed on engineering each component and load to minimize the weight, height and width. “When you keep every load under 12 ft wide, that adds to the overall efficiency of the rig,” he said. The rig-up does require crane assistance, although it’s minimal, Mr Cromling added. Overall, he believes the BOSS rig can achieve a 15% quicker rig-up compared with other advanced-technology, fast-moving rigs and up to 40% quicker compared with conventional box-on-box rigs.

The new rig also features two 2,200-hp quintuplex mud pumps, which Unit Drilling opted over triplex versions for higher pump output. “This means we can truly drill most of the horizontal wells with one mud pump, with the second as a standby,” Mr Cromling said.

The company also chose to outfit the rigs with diesel engines with bi-fuel capability, rather than natural gas engines. “We felt like going all gas would limit us in places where field gas isn’t available. Another environmental feature is that the skids underneath the engines and pumps are enclosed and can trap any fluid that might spill. Any fluid is contained within the system to be pumped away to a disposal area,” he commented.

The first BOSS rig began operating in the Granite Wash in Texas’ Hemphill County at the end of March, drilling horizontal wells with 14,500- to 16,000-ft MDs. Since Unit Petroleum is a sister company, Mr Cromling said, it has provided greater flexibility to work out problems throughout the assembly and testing process.

The company is now building four more BOSS rigs, and all but the last one has two-year contracts in place. As of early June, the first of these four was near completion and being prepared for mobilization to North Dakota. The second rig will go to work in the Niobrara in Colorado, and the third unit will operate in North Dakota. “Right now, the goal is to have one rig out every two months,” Mr Cromling said, adding that he hopes to build between eight to 12 new BOSS rigs in the coming year.

In the meantime, the company is investing heavily in training. Unit sees this as a critical aspect to the success of the new rigs, especially because they represent the first advanced-technology rigs in Unit’s 119-rig fleet. “For Rig 401, we had the crews do a mix of hands-on and classroom training for about 60 days, and we expect to continue that for all of these rigs as they go out,” Mr Cromling said. “We see a significant focus from the operators on training, and we’re prepared to invest the time necessary to make sure our people are well prepared for these new technologies.”

At the conference, Honghua also signed a three-year agreement for GE Power & Water’s Distributed Power business to supply its Waukesha VHP gas engines to power shale drilling rigs in China.

“We think it’s really going to be a trend in China to provide much more cost-efficient and cleaner power-generation solutions, and we want to become the pioneer in the Chinese market,” he said. The Waukesha gas engines will be fueled by on-site field gas or with commercial-grade gas to generate 2.8 to 3 megawatts of on-site power. The engines provide options to run almost any gaseous fuel from 950 to 2,600 BTU, including hot field gases, commercial-grade gas, LNG, CNG and up to HD-5 propane, according to GE. Waukesha units are being shipped to China, and the company expects the first pilot rig to begin operations in September.

Mr Zhang said he believes that as many as 100 rigs will be drilling for shale gas in China by year-end, mostly in the Sichuan Basin. This development will be critical as natural gas takes on a greater role in the worldwide energy mix and has been a significant motivator for Honghua to develop natural gas-supplied power-generation technologies.

In the US, as well, he sees the switch to natural gas for drilling applications as inevitable, with bi-fuel kits being a good bridging solution. “Right now the reason that a lot of existing drilling applications are using bi-fuel instead of replacing their current existing diesel engines with gas engines is the cost is very high. It’s also a step-by-step process – you can’t replace everything at once. But with the growth in the natural gas supply, eventually natural gas providing power generation will be the final solution.”

Under a new corporate strategy focused on financial discipline, Chesapeake Energy expects to stay at an operational level of approximately 60 to 80 rigs per day, CEO Doug Lawler said at the 2014 IADC Drilling Onshore Conference in Houston in May. Although this is a significant change from previous years – when the operator was running as many as 175 rigs – Mr Lawler said he still expects to achieve a strong 9-12% production growth rate. “From 2012 to 2013, we reduced our operating expenses by about 15% and are expecting continued improvements there by about another 10%,” he added.

As of mid-May, Chesapeake was running between 60 to 65 rigs per day in the US. Capital expenditure for the year was expected to range from $5.2 billion to $5.6 billion. “In 2013, we significantly reduced our capital and brought that down to a level that was much closer to our cash flow. We’re very pleased with the progress that has been made,” Mr Lawler said.

He emphasized that Chesapeake continues to maintain leading positions across the US shale market, with approximately 13 million net acres of leasehold. “That leasehold position gives us a significant amount of opportunity to grow and develop in our oil and gas plays,” he said, noting that the industry will be supported by increasing demand for natural gas. LNG exports alone could reach 8 bcf/day by 2020 in the US, and overall natural gas demand could be double that if you factor in natural gas vehicles, power generation and other industrial demands.

This means the US would need another Marcellus-size development, he said, highlighting both opportunities for growth and the need to capture more efficiency gains. “Think about the significant amount of money that has been invested in the Marcellus and how the industry has grown the infrastructure and services provided there, and the learning curve we’ve traveled on the operations side, the safety side and the environmental side.”

Around the world, too, significant opportunities exist for replicating the North American shale boom. Mr Lawler reiterated Chesapeake’s interest in unconventional development in the international arena. In fact, he said he expects US independents and drilling companies to play key roles outside the US as they have at home.

Under a growth plan called “2×3,” Concho Resources is expecting to ramp up its drilling activities in the Permian Basin in order to double its production by 2016. Further, most of this expected growth will come in the form of horizontal-drilling rigs, Ray Peterson, VP of Drilling for Concho, said at the 2014 IADC Drilling Onshore Conference in Houston in May.

“All in all, we expect to end the year with 35 rigs and 31 of them drilling horizontal wells. This is a big change for Concho. If we look back about a year and a half, you would see just a handful of horizontal and some 30-odd vertical rigs that were drilling at the time,” he said.

The horizontal trend is not limited to Concho, however. Mr Peterson noted that the Permian Basin has gone from a total of 360 rigs in Q1 2011, when only 13% of the fleet was drilling horizontally, to 551 total rigs now. “About 58% of the rigs are horizontal. That’s where the growth is coming from,” he said, adding that the phenomenal comeback the Permian is making is only expected to continue over the next few years. Daily oil production has already passed 1.5 million BOE this year and could reach 2 million BOE in a few more years, he said. “It’s an oily basin, but what’s so surprising is it’s still got a lot of places to drill for gas, too. It’s a great place to be.”

“We are doing more with fewer rigs. That’s a good thing for us,” he said, adding that drilling contractors shouldn’t perceive this as a negative. “I think there is still plenty of opportunities. Fewer days on the well and better efficiencies are things that are going to benefit all of us in the long term.”

Concho is using a variety of rig types, including older mechanical rigs, across its four major operating areas within the Permian, Mr Peterson said. In the New Mexico Shelf area, where the company is drilling shallow TVDs and 1-mile laterals, “a 750-hp mechanical kelly rig is taking care of us and doing a very good job.” In the Northern Delaware Basin, “we’re seeing 1,600-hp pumps on 1,000-hp rigs, and that is working for us. Some have top drives, and some don’t.”

For some extended-lateral wells where the MD reaches 20,000 ft, 1,500-hp SCR and AC rigs with top drives are brought in. These newer-type rigs are also used in the Southern Delaware Basin, where 1.5-mile laterals are the standard. Finally, in the Midland Basin, Concho uses a mix of 1,000-hp mechanical rigs and 1,500 SCR/AC rigs with top drives. “We have enjoyed a wide variety of rigs. That’s what has made it work.”

Concho is also working with 16 different drilling contractors for the 33 rigs it currently has under contract, including several of what Mr Peterson called niche players. “It’s nice to be able to have that variety, but we still want everyone that works for us to focus on safety… This is still a people business. Anybody can buy iron, but it takes people to be a contractor.”

Greg Guidry, Shell Executive VP, Upstream Americas Unconventionals, shared a different perspective that focused on engagement with the public, noting that he sees more overlap between the unconventionals and deepwater in terms of public acceptance than in terms of technology. “If we don’t get it right in terms of the acceptance of our activity, then it gets very tough for the technology to have the opportunity to work,” he said.

One example of the efforts that Shell is undertaking to engage with the public is the Rational Middle Energy Series, which are educational videos intended to generate discussion of the energy business. “Let’s create some information so that we can have a much more rational dialogue around seeking a win-win for an activity that actually fulfills the needs of the community and of society but also allows economic development to take place,” Mr Guidry said.

So far, 21 videos have been generated, such as “Realities of Drilling” and “Shale Gas 101.” “Anyone can use these because they’re free. You can pull them right off the website, and you can use these to actually create a dialogue with those who are uncertain about whether they like or dislike the activity,” he said. “You’re not going to appeal to the bottom 10% who are campaigners or who absolutely will never accept it, but what we found is it creates quite an interesting dialogue with those who are influenceable one way or the other.”

As for the workover rig,we also called completion rigs or pulling units and is a important which can provide the basic power in the workover operation. When the oil well get in trouble ,we always use the workover rig to place the tools to fishing the falling or well casing inspection in the well which make sure the well can keep normal production.

Generally speaking ,there is the same principle in the drilling and workover rig ,but we can still find the difference of them.Firstly ,we can distinguish by definition.as for the oil drilling rig ,the main function of this rig is drilling,oil drilling rig is mainly used for the oil and gas exploration and development.for the workover rig,the main function is retrieve the sucjer rod string,pump or production tubing form the well or run wireline and the repair equipment into the oil well.Secondly,the drilling depth is different,form the distinguish we know that the drilling depth of the oil drilling rig is much higher than workover rigs’,in the workover operation,in some cases,the oil drilling rig always instead of the workover rig used in the superdeep well.

The rig assist unit was installed on top of the rig’s Bops. A landing joint was lowered into the stack and screwed into the tubing hanger. The snubbing Bops were tested using the rig pump to 35mpa

The stack was equalized using the snubbing unit equalize line to well bore pressure. The hanger hold-down screws were backed out and the tubing hanger staged out using the snubbing units annular and stripping rams

Every tubing connection was staged out of the hole using the stripping rams and annular. The pressure at 21mpa made pulling the connections through the annular with pressure under it unwise. Before the connection was pulled through the annular, the lower stripping rams were closed and the pressure between the rams and annular vented to flare. Once the connection was through the annular element, the chamber between the Bops was re-equalized and the stripping ram opened. This process was repeated for every connection

Once the lift force from the well overcame the weight of the string, the snubbing unit took over pipe movement. The tubing connections were still staged out and the pipe continued to be racked in the derrick

The joint was gently snubbed up until the fill/flow sub was above the snubbing unit annular element. The operator continued to raise the tubing until the lower connection of the 3m pup joint engaged the bottom side of the stripping rams. The rams were locked and the chamber between the stripping rams and annular was re-equalized

At first referring to Fig. 1, the utility model is made up of derrick epimere 2, derrick hypomere 8, telescopic hydraulic cylinder 3, hydraulic cylinder top holder 4, cylinder lower holder 9, base 10, connection bearing pin 11, stepless adjustable sleeve pipe stabbing board 12, should provide during work and satisfy required other facility of derrick operation, as overhead traveling crane 1, quadruple board platform 5, standpipe maintenance platform 7.That the utility model adopts is upright, open front, no guy wire, trussed construction, and derrick epimere 2 and derrick hypomere 8 adopt rectangular steel pipes or the angle steel material as column, diagonal brace, crossbeam, stull.Before hoisting, derrick epimere 2 is sleeved in the derrick hypomere 8, the support that the support structure 6 of derrick hypomere 8 is realized derrick epimere 2, telescopic hydraulic cylinder 3 is separately fixed on derrick epimere 2 and the derrick hypomere 8 by hydraulic cylinder top holder 4, cylinder lower holder 9.Telescopic hydraulic cylinder 3 upper ends are fixed on the derrick epimere 2 with U bolt by hydraulic cylinder top holder 4, and are detachable; Telescopic hydraulic cylinder 3 lower ends are by cylinder lower holder 9 usefulness bearing pins fixedly on the derrick hypomere 8, detachably.Hydraulic cylinder top holder 4 is made up of gusset 41, clamp 42, fixed head 43, gusset 44.Cylinder lower holder 9 is made up of riser 91, pin 92, connection base plate 93.Telescopic hydraulic cylinder 3 fixed forms of this structure, making telescopic hydraulic cylinder 3 tops is Open architecture, after pin 92 is removed in telescopic hydraulic cylinder 3 bottoms, also becomes Open architecture, two all can be extracted out, and is easy to maintenance.

The automatic operation equipment for minor workover is mainly composed of a wellhead operation device, hydraulic elevator, pipe and rod transmission and arrangement device and electro-hydraulic control system.

The device adopts the structural form of dispersing the functional modules and integrated installation on the workover rig: with the hydraulic tong, manipulator and anti splash snap device set on the derrick of the workover rig, which can expand and rotate, and the safety slip is installed above the BOP.

The device only needs to install safety slips, which realizes rapid installation and migration and shortens the auxiliary working time. The device has the function of moving back and forth, left and right, which is convenient to align the wellhead. The height of the hydraulic tong is adjustable and can adapt to the wellhead with different heights. Hoisting equipment and special transport vehicles are not required for the installation and removal of the device.

The main electric control box can be installed on the operation vehicle or integrated into the modular wellhead operation device. The make-up torque of various oil pipes is set on the touch screen to realize automatic make-up and break-down. Equipped with video monitoring, process prompt, safety alarm, etc. The control system has a perfect action interlocking function to ensure the safety and reliability of the workover operation process. All of the electric cabinets, sensors, connectors meet the requirement of Explosion-proof on field.