bit trip in oil and gas

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Oil and Gas Well Drilling and Servicing eTool

Drilling » tripping out/in.

Tripping refers to the process of removing and/or replacing pipe from the well when it is necessary to change the bit or other piece of the drill string, or when preparing to run certain tests in the well bore.

The activities that comprise tripping out are listed below. Tripping in essentially comprises the same steps in reverse order.

Tripping Out

Setting slips

Breaking out and setting back the kelly, attaching elevators to the elevator links, latching elevators to pipe, working on the monkeyboard, breaking out pipe, maneuvering pipe to racking area.

Tripping In

• Elevators raised
• Tripping In -- latching elevators to top of stand
• Moving pipe to rotary
• Pipe is made up
• Slips are pulled
• Slips are set
• Elevators are unlatched
• Process repeated for all stands
• Pickup kelly and attach to drill string
• Break circulation, and
• Resume drilling

Additional Information:

• Drilling Technology Series . Petroleum Extension Service (PETEX), University of Texas at Austin.
• Accident Prevention Guide . International Association of Drilling Contractors (IADC).
• RP 54 , Occupational Safety for Oil and Gas Well Drilling and Servicing Operations. American Petroleum Institute (API), (March 2007).

The floor crew sets slips around the drill stem.

Potential Hazards

• Getting fingers or other body parts pinched between slips or slip handles and rotary table .
• Receiving muscle strain from improper lifting technique.

Possible Solutions

• Use proper hand placement when setting slips.
• Use proper stance and slip lifting techniques. Slips have three handles and should be lifted jointly by more than one person.

Additional Information

• RP 54 , Occupational Safety for Oil and Gas Well Drilling and Servicing Operations. American Petroleum Institute (API), (March 2007). Includes procedures for promotion and maintenance of safe working conditions for employees engaged in rotary drilling operations and well servicing operations, including special services. Applies to rotary drilling rigs, well servicing rigs, and special services as they relate to operations on locations.

Wedge-shaped pieces of metal with teeth or other gripping elements that are used to prevent pipe from slipping down into the hole or to hold pipe in place. Rotary slips fit around the drill pipe and wedge against the master bushing to support the pipe. Power slips are pneumatically or hydraulically actuated devices that allow the crew to dispense with the manual handling of slips when making a connection. Packers and other down hole equipment are secured in position by slips that engage the pipe by action directed at the surface. †

#51. Rotary Table

The principal component of a rotary, or rotary machine, used to turn the drill stem and support the drilling assembly. It has a beveled gear arrangement to create the rotational motion and an opening into which bushings are fitted to drive and support the drilling assembly.

Note the pipe spinner (in red) on the side of the swivel. †

Breakout the kelly and set it into the rathole .

Potential Hazard

• Release of excess drilling mud resulting in skin contact, loss of footing, etc.
• Shut down the mud pumps before breaking out the kelly.
• Close the mud saver valve on the kelly (if present).
• Use a mud bucket to divert flow of excess mud.
• Being struck by the slip handles if the rotary table is used to spin the drill string.
• Stand clear of the rotary table when it is rotating.
• Consider other technologies (such as a pipe spinner, kelly spinner , or top drive unit) to eliminate this hazard.
• Being struck by the kelly if the pullback line unhooks when kelly is being pulled toward the rathole.
• Implement an effective pullback line attachment procedure.
• Ensure workers stand in a safe location away from the pullback line and rathole during this pullback operation.

The heavy square or hexagonal steel member suspended from the swivel through the rotary table. It is connected to the topmost joint of drill pipe to turn the drill stem as the rotary table turns. †

#49. Rathole

A hole in the rig floor 30 to 35 feet deep, lined with casing that projects above the floor. The kelly is placed in the rathole when hoisting operations are in progress. †

#16. Mud Pump

A large reciprocating pump used to circulate the mud (drilling fluid) on a drilling rig. †

#45. Kelly Spinner

A device for spinning the drill pipe. Replaces the spinning chain. †

#6. Top Drive

The top drive rotates the drill string end bit without the use of a kelly and rotary table. The top drive is operated from a control console on the rig floor. †

The crew attaches elevators to the elevator links.

• Being pinched by the elevator links while attaching elevators (or attaching elevator links to the hook).
• Being struck by the elevators.
• Receiving strains and sprains.
• Use proper hand placement when attaching elevator links.
• Ensure workers stand away from swing-path of the elevators and elevator links.
• Use lifting equipment and limit manual positioning of elevators.
• Use proper mounting procedures.

#40. Elevators

A set of clamps that grips a stand, or column, of casing, tubing, drill pipe, or sucker rods, so the stand can be raised or lowered into the hole. †

The floor crew latches the elevators onto the pipe.

• Getting hands or fingers pinched in elevators.
• Being struck by elevators not securely latched.
• Getting hands or fingers caught between elevators and stump.
• Ensure workers are instructed in proper latching procedure, including the use of handles on elevators as they are descending into place over the stump or tool joint.
• Inspect and maintain elevators.
• RP 8B , Inspection, Maintenance, Repair, and Remanufacture of Hoisting Equipment. American Petroleum Institute (API), (April 2005). Covers such items as crown-block sheaves and bearings, drilling hooks, elevator links, rotary swivels, dead-line tie-down/wireline anchors, and safety clamps. This edition of API RP 8B is an identical adoption of ISO 13534:2000.

The derrickman climbs up the derrick to the monkeyboard . From here he unlatches the elevators and guides the stands of pipe into the fingerboard. The elevators are then lowered and attached to the next stand of pipe.

• Falling while climbing up or down the ladder.
• Falling from monkeyboard or fingerboard.
• Slips, trips, and falls.
• Falling during an emergency descent.
• Use climb assist device.
• 29 CFR 1910.28 , Duty to have fall protection and falling object protection.
• 29 CFR 1910.66 App (C) , Fall Protection guidelines.
• 29 CFR 1910 Subpart D , Walking-Working Surfaces.
• Work gloves
• Safety-toed footwear
• Practice 100% tie-off while working in the derrick.
• Use slip-resistant coatings or materials on working surfaces.
• Train personnel in use of emergency escape device.
• Being caught between pipe and other objects.

Possible Solution

• Practice proper hand placement and use of pullback (tail) ropes.
• Being struck by dropped objects.
• Implement a dropped objects program, such as tie-off for all tools.
• Use extra caution while personnel are working overhead.
• Do not carry tools while climbing the derrick ladder. Raise tools with a line to any worker above the derrick floor.
• Z359.1 . American National Standards Institute (ANSI).
• Personal Fall Arrest Systems . (Please recognize that there is a weight limit, including equipment.)
• Fall Protection Guidance . International Association of Drilling Contractors (IADC).

#4. Monkeyboard

The derrickman's working platform. Double board, tribble board, fourable board; a monkey board located at a height in the derrick or mast equal to two, three, or four lengths of pipe respectively. †

The crew uses the tongs and cathead to breakout the pipe. The rotary table may be used to spin out the pipe after breaking the connection.

• Being struck by swinging tongs if they break free from the pipe.
• Being struck by reverse backlash of tongs (backbiting) during breakout operations.
• Being struck by the tongs if a snub line breaks or the tongs come unlatched.
• Personnel other than tong operators stand outside the tong swing radius when breaking pipe.
• No one should stand in the red zone. (see Figure 10)
• Use proper tong latching techniques and use proper hand and finger placement on tong handles.
• Use special operational procedures when making high torque connections.
• Inspect tong dies and snub lines each tour.
• Maintain good communication between floor hands and driller.

The large wrenches used for turning when making up or breaking out drill pipe, casing, tubing, or other pipe; variously called casing tongs, rotary tongs, and so forth according to the specific use. Power tongs are pneumatically or hydraulically operated tools that spin the pipe up and, in some instances, apply the final makeup torque. †

#29. Cathead

A spool-shaped attachment on a winch around which rope for hoisting and pulling is wound. †

The stand is raised and maneuvered to the pipe racking area.

• Getting hands and fingers pinched between stands of pipe.
• Getting feet or toes crushed or amputated under a stand of pipe.
• Keep hands and fingers from between pipe stands.
• Position feet away from the bottom of the pipe stands.
• See General Safety and Health .

Tripping in - latching elevators to top of stand

The derrickman latches the elevators onto the pipe from the monkeyboard.

• Ensure workers are instructed in proper latching procedure.

† This is an abridged version of the Dictionary of Petroleum Terms provided by Petex and the University of Texas Austin. © Petex 2001

Rotary Table

Kelly Spinner

Monkeyboard

The cutting or boring element used in drilling oil and gas wells. Most bits used in rotary drilling are roller-cone bits. The bit consists of the cutting elements and the circulating element. The circulating element permits the passage of drilling fluid and uses the hydraulic force of the fluid stream to improve drilling rates. †

The heavy seamless tubing used to rotate the bit and circulate the drilling fluid. Joints of pipe 30 feet long are coupled together with tool joints. †

• Calculation of Maximum Allowable Annular Surface Pressure (MAASP)
• Casing Make-Up Torque
• HSE Plan (Example)
• Waste Management Strategy - cuttings discharge
• Inflow Testing Procedure
• Well Control Drills and Exercises
• Classification of BOP and well control equipment.
• Single-shot inclination-only survey tools (TOTCO)
• Packer Setting Mechanism

Tripping Operations - Best Practices

• Drilling program example (Semi-Sub)
• Completion Operation - Best Practices
• Drilling programme 12.25" section HPHT
• Cold Weather Operations Checklist
• Coring Checklist
• Weatherford Overdrive casing running and pick up/lay down machine - Checklist
• 16" Potential Problems - Best Practices
• 12.25" guidelines for tripping, making connections and back reaming
• 9 5/8" Wellhead and BOP Operations Checklist
• Survey and Collision Avoidance Standards
• Operation Programmes Standards

1. Preparation

The Drilling Supervisor shall approve and provide written instructions to the Contractor Toolpusher prior to any trip out of the hole. These instructions shall include the:

• sequence of operations  i.e. flow check, circulate bottoms up, drop survey, etc.
• maximum allowed overpull
• procedures if tight hole is encountered
• maximum running/pulling speeds
• preparation of equipment for the following operation when out of the hole

The drilling contractor shall ensure that a master drill pipe tally book is maintained at all times.  This shall include stand number, single number, single identification, drill pipe grade, single length, stand length and total length.

Prior to pulling out of the hole, the trip tank shall be filled. The fill-up pump to the trip tank should never be left running while tripping out.

Circulation

•  For any trip out of the hole, a minimum of one bottoms up circulation, or appropriate circulation for deviated wells, shall be performed.
•  When circulating to condition mud, a circulating rate of 50 - 75% of the normal circulating rate shall be used.
•  A trip sheet shall be filled out by the Driller and Mud logging contractor for each trip out of the hole.

 2 - General Guidelines

Responsibilities.

The Drilling Supervisor shall be on the rig floor for the first 10 stands during tripping out to observe for correct hole fill, overpull, etc. He shall also be on the rig floor for the last five stands when tripping in, tight hole problems, testing mud motors & MWD, RIH across liner hanger and when casing 3 stands off bottom.

Pipe Movements

• Care shall be exercised to minimise surge/swab pressures by controlling the speed of pipe movements.
• Pull the pipe carefully and check for swabbing. In the event of the hole swabbing, the pipe shall be run back to bottom and the hole circulated bottoms up. Mudloggers shall run the swab programme prior to each round trip to determine the maximum trip speed.

Notes: A hole is swabbing whenever the volume of fluid required to fill the  hole is less than the volume of steel pulled out of the hole. THE HOLE CAN BE SWABBING WITHOUT FLOW AT THE FLOWLINE.

Circulation, Hole Fill, and Pipe Fill

•  The pipe shall be filled every 10 stands while running in the hole and the displacement checked.
•  When pulling the pipe, the hole shall be kept full from the trip tank. The hole shall be checked regularly to ensure that it is taking the correct amount of fluid.
•  The volume required to fill the hole every 3-5 stands shall be recorded in the Trip Sheet until the bit is out of the hole.

 Tight Hole / Bridging Conditions

•  If tight hole or bridging conditions occur during trips, the pipe shall be pulled back to the nearest stand and reaming/washing commenced in accordance with stuck pipe procedure.
•  If tight spots occur while tripping out, the top drive or kelly shall be engaged to commence reaming and circulating out.
•  Reaming trips might be required prior to running LWD/density tools and/or 7in liner.

Directional Wells

While tripping out of the hole from below the surface casing in directional wells:

• reciprocate at all times and rotate the pipe at intervals while circulating and conditioning the mud prior to POOH
• record the pick-up, slack-off and rotating weight indicator readings with the mud pump off. Note: These values shall be used to monitor changes in drag during pulling out.
•  the top drive, if available, shall be used to pump out and/or ream out the first 5 to 10 stands off bottom.

Flow Checks

While tripping flow checks shall be taken:

•  just off bottom
•  at the cement casing shoe
•  prior to pulling drill collars through BOP stack
•  after BHA out of horizontal section
•  while RIH after drilling out shoe
•  while RIH before BHA enters horizontal section.

3 - Requirements When Out Of Hole

 time out of the hole.

The time spent with the pipe out of the hole shall be minimised wherever possible. Operations such as routine repairs and slipping and cutting of the drill-line shall be performed with pipe at the casing shoe whenever possible.

Requirements When Out of Hole

The trip tank volume indicator shall be set at 1/2 barrel gain or loss whenever the trip tank is being circulated on the hole.

Whenever the blind rams are closed, the Driller and the Assistant Driller shall open the rams and check the fluid level at least every half hour, fill the hole as required and report any losses to the Drilling Supervisor. (Before opening blind ram open choke)

During logging operations, the trip tank shall be circulated continuously to keep the hole full.  The volumes shall be recorded every 15 minutes and any losses reported to the Drilling Supervisor.

Whenever the mud pumps are turned off with the pipe still in hole, the trip tank shall be circulated continuously. The volume shall be recorded every 15 minutes and any losses reported to the Drilling Supervisor.

4 - Wiper Trips and Check Trips

Wiper trips.

Wiper trips shall be run at the discretion of the Drilling Supervisor and Drilling Contractor Toolpusher:

• during logging when hole conditions deteriorate and become sticky
• after logging and before running casing when hole conditions deteriorate and become sticky
• before RFT tools are run
• to push junk down the hole (e.g. lost SWS bullets, etc.).
• after 500-1000 ft of hole has been drilled

Note:    In general, wiper trips shall be made to the shoe. However, when there are no indications of hole problem but there is a major change in parameters, a short trip of 10-15 stands shall be made.

Check Trips

Check trips shall be run at the discretion of the Drilling Supervisor and Drilling Contractor Toolpusher but shall be run:

• whenever significant torque/drag increase is noted
• before running casing if hole conditions during logging indicate that this is necessary
• during logging when mud overbalance is limited/low or there is gas cutting of mud
• when the bit has been on bottom for 24 hours.

For casing check trips, the BHA shall include full gauge stabilisers and be at least equal in stiffness to the casing string. MWD’s, NMDC’s and other expensive BHA components shall not be run.

The following table contains the basic guideline procedure to be followed when making a check trip:

1. Circulate bottoms up

2. Flow check for 15 minutes

3. Slowly pull 10-15 stands while using the trip tank to ensure that the hole is taking the correct quantity of mud

4. Flow check

5. Run back to bottom, check for fill and for flow again

6. Circulate bottoms up and condition the mud

7. Check mud returns for gas and salinity and report to the Drilling Supervisor

Note : If a well demonstrates a tendency to swab, pumping out of the hole maybe necessary.

5 - Making Connections

The following guideline procedure shall be followed for all drilling operations in order to minimise the time during which the drill string is motionless:

1. Drill the stand/joint down to the desired point but DO NOT drill-off the WOB or stop the pumps

2. Reduce the rotary speed to 20-30 RPM

3. Begin upward movement of the pipe while maintaining 20-30 RPM rotation

4. Pull one stand/joint of pipe above the rotary to wipe all newly drilled hole

5. Lower the pipe and REAM the stand/joint down, if necessary

Note :   The Directional Driller shall be notified before any reaming is carried out

6. Repeat Steps 4-5 until drag and torque are acceptable

7. Lower the drill string without rotation and observe drag

8. Set the slips and break the tool joint to make connection

9. Pick-up the new stand/joint of pipe and make the connection

10. Start the pumps, lift the pipe and remove the slips

11. When the mud pumps are near required speed, begin rotation, lower the pipe and resume drilling

12. When the pipe is in the open hole, always set the slips on a down stroke long enough to ensure that the pipe is actually moving down the hole when the slips are set; never set the slips with drill pipe tension on the BHA.

Cost Per Foot Equation

The cost per foot equation is used for the comparison of alternative equipment, chemicals, and procedures for the drilling of a formation or an interval. The comparisons are often called break-even calculations and are usually between drill bit types or manufacturers; however, any of the variables may be compared.

Bit + Tools + Mud + [ Drill Time + Trip + Lost ] [ Rig + Support + Tool Rental] C "" Drill Rate * Drill Time

C = Cost per foot for the interval of concern; $/ft

Bit = Cost of delivered bit at the drill site; $

Tools = Cost of tools or repairs to tools; $

Mud = Cost of mud to drill the interval; $

Drill Time = Time required to drill the interval or bit life; hr

Trip = Time to pull and rim a bit; hr

Lost = Time chargeable to non-drilling task; hr

Rig = Contract rental rate of a rig; $/hr

Support = Third party contractors rates; $/hr

Tool Rental = Rental of tools; $/hr

Drill Rate = Average drilling rate over the interval; ft/hr

In a comparison of drill bits, the drilling rate and life of the proposed bit will always be in question. The usual procedure is to compute the cost per foot with the data from a standard bit with the proposed bit; and, then construct a chart of required drilling rate and bit life for the proposed bit. The following example illustrates the method.

A study of bit data from a data base predicts that the expected values from a bit run with a tooth bit are as follows.

Tool = Stabilizer $250

Drill Time = Bit life; 33 hr

Lost = Surveying after every trip; 0.3 hr

Support = Contractor and Supervisors; $250/hr

Tool Rental = Large drill collars; 9 $/hr additional

Drill rate = 13 Mir

C = 84.72 $/ft Cost per foot for the data base tooth bit. Cost of PDC bit

The costs for a proposed PDC bit which is to be run on a bottom hole motor are the following.

_ 9283 + (1894 + 500) + 2500 + [Drill Time + 7.5 + .3][550 + 250 + 200] 84-72 ~ Drill Rate * Drill Time

Reduction of the equation yields,

A break-even chart of required drill rates versus required drill time (bit life) may be prepared with the equation.

Continue reading here: Fracture Gradient Plot Eaton

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Readers' Questions

How much money does it cost to horizontal drill an oilwell?

The cost of horizontal drilling an oilwell can vary widely depending on a variety of factors, including the location, depth, and complexity of the well, as well as market conditions and the technology used. On average, the cost of drilling a horizontal oilwell can range from several million dollars to tens of millions of dollars. However, it is important to note that this estimate is highly subjective and can change dramatically based on the aforementioned factors.

How to complete an oil well in chert?

Completing an oil well in chert requires specific steps and equipment. Here is a general outline of the process: Drilling: Begin by drilling a wellbore into the chert formation. This is done using a drilling rig, which can reach deeper into the earth's surface. Installing Casing: Once the desired depth is reached, casing is installed to prevent the well from collapsing and to isolate different formations. Typically, multiple layers of steel casing are used, with each one progressively narrower in diameter. The casing is cemented in place to provide additional stability. Perforating: After the casing is set, perforate the chert formation to create channels for oil to flow into the wellbore. Perforating can be done using perforation guns or other similar tools that create holes in the casing and surrounding rock. Wellbore Completion: Install a completion system, which consists of various components to facilitate the production of oil. This includes wellhead equipment, tubing, packers, and other tools necessary for oil extraction. The specific arrangement depends on the oilfield's characteristics and operational requirements. Fracturing: If required, hydraulic fracturing (fracking) may be performed to enhance oil recovery. This process involves injecting a high-pressure fluid mixture into the wellbore, which creates fractures in the chert and helps release trapped oil. Production Testing: Conduct production testing to evaluate the well's performance and determine its economic viability. This involves monitoring oil flow rates, pressures, and other parameters to assess the well's productivity and potential profitability. It is important to note that completing an oil well in chert requires expert knowledge and experience. Geologists, petroleum engineers, and other specialists work together to ensure a successful completion process. Additionally, local regulations and environmental considerations should be followed throughout the entire operation.

How to get foot in oil and gas business?

To get your foot in the oil and gas business, you can follow these steps: Gain relevant education: Pursue a degree in a field related to oil and gas, such as petroleum engineering, geology, or chemical engineering. This will provide you with the necessary technical knowledge and skills. Build industry knowledge: Stay updated with the latest trends, technologies, and developments in the oil and gas sector. Read industry publications, attend conferences, and join professional associations to network with industry professionals. Gain practical experience: Look for internships or entry-level positions at oil and gas companies. This will provide you with hands-on experience and help you understand the inner workings of the industry. Network: Attend industry events, conferences, and job fairs where you can meet potential employers and professionals working in the field. Building a strong professional network can provide you with valuable contacts and job opportunities. Develop specialized skills: Acquire additional skills that are in demand in the oil and gas industry, such as knowledge of specific software, project management, or data analysis. These skills can give you a competitive edge when applying for positions. Consider field positions: In the oil and gas industry, many entry-level positions require working in the field. Be open to starting in a remote location or on-site positions to gain practical experience and establish yourself in the industry. Be flexible and open to relocation: The oil and gas industry operates in various regions globally, so being flexible and willing to move to different locations can increase your chances of finding job opportunities. Consider further education: If you want to specialize in a specific area, consider pursuing advanced degrees or certifications in fields like reservoir engineering, offshore operations, or environmental science. Stay persistent: The oil and gas industry can be competitive, so it's important to remain persistent in your job search. Keep applying for positions, attending networking events, and improving your skills and knowledge in the field. Leverage online platforms: Utilize professional networking platforms like LinkedIn to connect with industry professionals, join relevant groups, and showcase your skills and expertise. Remember, entering the oil and gas industry may require time and effort, so it's important to stay motivated and committed to your career goals.

How muc does it cost to rill a vertical oil well?

The cost of drilling a vertical oil well can vary widely depending on various factors such as the location, depth, complexity of the well, and market conditions. On average, it can cost anywhere from several hundred thousand dollars to several million dollars to drill a vertical oil well. Deep offshore wells can be even more expensive and can cost tens or hundreds of millions of dollars.

How much is an oil rig?

The cost of an oil rig can vary greatly depending on several factors, such as size, type, geographic location, and the equipment involved. On average, the cost of a land-based oil drilling rig can range from $20 million to $50 million. However, offshore drilling rigs can be significantly more expensive, usually ranging from $100 million to several billion dollars, depending on their size, capabilities, and complexity. Additionally, operational and maintenance costs also need to be considered, which can add to the overall expenses.

What is the cost to drill an oil well in california?

The cost to drill an oil well in California can vary depending on various factors such as the location, depth, complexity, and technology used. Generally, drilling an oil well in California can range from several million dollars to tens of millions of dollars. It's important to note that costs can significantly fluctuate over time due to market conditions, regulatory requirements, environmental factors, and other variables.

How to compare drilling costs from 2 different years?

To compare drilling costs from two different years, you can follow these steps: Collect data: Gather drilling cost information for both years. This data can be obtained from drilling companies, industry reports, or other reliable sources. Normalize costs: Take into account any changes that may have occurred over time, such as inflation. Normalize the costs to a common base year by adjusting them using a suitable inflation index or price deflator. Determine cost components: Break down the drilling costs into different components, such as labor, equipment, materials, and overhead expenses. This breakdown will allow you to understand the factors that contribute to changes in drilling costs over the years. Calculate percentage changes: Calculate the percentage change in each cost component between the two years. This can be done using the formula: ((New Cost - Old Cost) / Old Cost) x 1This will give you the percentage increase or decrease for each cost component. Analyze cost drivers: Determine the factors that influenced the changes in drilling costs. This could include changes in oil prices, technology advancements, regulatory requirements, or market conditions. Understanding the drivers behind the cost changes will provide valuable insights into the industry trends. Compare overall costs: Finally, compare the overall drilling costs for the two years. Consider the percentage changes in cost components and the impact of cost drivers identified in the analysis. Evaluate the reasons for the changes and assess the cost efficiency or cost-effectiveness of drilling operations in the respective years. By following these steps, you will be able to compare drilling costs from two different years and identify any significant differences or trends.

What is the cost to drill a 4000 ft vertical oil well?

The cost to drill a 4000 ft vertical oil well can vary widely depending on several factors such as the location, complexity of the geology, equipment used, labor costs, and other operational expenses. However, on average, it can cost anywhere between $4 million to $10 million or more to drill a well of that depth.

How much is a oil rig?

The cost of an oil rig can vary greatly depending on a variety of factors such as size, location, and specifications. Small offshore drilling rigs can cost around $20 million, while larger drilling rigs can cost several hundred million dollars. Additionally, the cost of operating and maintaining an oil rig can be quite high. It is important to note that these figures are just approximate ranges and the actual cost can vary significantly.

How much does it cost to have a welldrilled?

The cost of drilling a well can vary greatly depending on various factors such as the depth of the well, the geological conditions of the area, the type of well being drilled, and the equipment and labor required. On average, drilling a residential water well can cost anywhere between $3,000 to $15,000 or more. Shallow wells (less than 100 feet) tend to be less expensive, while deeper wells (over 500 feet) can be significantly more expensive. In certain locations with challenging geological conditions, drilling costs can be even higher. It's important to note that the drilling cost is just one part of the overall cost of a well. Additional expenses may include permitting, well casing, filtration systems, pumps, and any necessary testing and infrastructure. Therefore, it's recommended to consult with local well drilling companies or professionals to obtain accurate cost estimates based on your specific requirements and location.

How much would 50000 square kilomiters cost for drilling oil in?

The cost of drilling for oil on 50000 square kilometers depends on the complexity of the drilling operations, the geological conditions, the price of materials and labor, and the type of oil. There is no single answer to this question and the cost would vary greatly depending on the specifics of the project.

How to calculate cost per foot petroleum?

To calculate the cost per foot of petroleum, you'll need to know the volume of petroleum being used and the total cost of the petroleum. Divide the total cost of the petroleum by the volume of petroleum used, and that will give you the cost per foot. For example: if 10 gallons of petroleum cost you $75, you would divide $75 by 10 gallons, which equals $7.50 per gallon. That would be your cost per foot.

How to calculate drilling bit trip cost?

To calculate the cost of a drilling bit trip, you will need to determine the following factors: The cost of the drill bit itself. The cost of fuel for the drilling rig. The cost of labor for the drilling team. The cost of any additional materials required for the project. The cost of any additional equipment needed to complete the project. Once these factors have been determined, you can multiply the total cost by the number of trips needed to complete the project. This will give you the total cost of the drilling bit trip.

How much does it cost to drill a vertical oil well 18,000 ft?

The cost of drilling a vertical oil well 18,000 feet deep can vary drastically. Factors that impact the cost include the type of well, the depth, the location, and the production rate. On average, vertical wells are estimated to cost between $5 million and $15 million.

How does diamond core drilling cost per foot?

The cost of diamond core drilling per foot depends on a variety of factors, such as the drilling depth, the size of the drill bit being used, what type of soil or material being drilled in, and other logistical issues such as the distance traveled to the work site. Generally, diamond core drilling costs range from $7 to $18 per foot.

How to figure cost to plug an oil well in oklahoma?

Unfortunately, it is not possible to provide a definitive answer to this question as the cost of plugging an oil well in Oklahoma can vary greatly depending on the specific well and the size of the operation. Factors such as the depth of the well, the type of equipment needed to plug the well, the type of formations in the area, and the amount of contaminated soil and water around the well can all affect the cost. The best way to obtain an accurate estimate of the costs associated with plugging an oil well in Oklahoma is to contact a local oil and gas contractor in the area who specializes in well plugging services.

How to calculate cost per lateral foot oil & gas?

The cost per lateral foot for oil & gas will vary depending on the cost of the drilling and completion, the cost of the materials used, and the cost of the production equipment and services. To calculate the cost per lateral foot, add up all the costs associated with the drilling and completion of the well, the cost of the materials used in the drilling, and the cost of any production equipment and services. Then divide the total cost by the length of the lateral in feet.

How to calculate cost of feet drilled?

Cost of feet drilled will depend on the type of drill being used, the size and length of the holes being drilled, and the complexity of the job. The best way to determine cost is to consult with an experienced drilling contractor or specialist. They can provide a quote based on the specifics of the project, such as the number of holes, diameter and length of each hole, and the type of materials used.

How much to drill an 8000 foot oil well?

The cost to drill an 8,000 foot oil well can vary greatly depending on a number of factors, including the type of well and the terrain. Typically, the cost to drill a vertical 8,000 foot oil well can range from $150,000 - $800,000, and the cost to drill a directional or horizontal 8,000 foot oil well can range from $400,000 - $4,000,000.

What does it cost to drill an oil well to 7,000 Feet?

The cost to drill an oil well to 7,000 feet depends on many factors, including the location of the well, the drilling contractor and technology used, the type of oil, and more. Generally speaking, it can cost anywhere from $3 million to $15 million to drill an oil well to 7,000 feet.

How much is casing per foot in the oilfield?

The cost of casing per foot in the oilfield varies widely depending on the size, material, manufacturer and other factors. Generally, casing costs between $13 and $82 per foot.

What is the cost for Concho Oil and Gas to drill an oil well?

The cost for Concho Oil and Gas to drill an oil well depends on many factors including type of well, depth, location and technology. Generally speaking, the estimated cost to drill a shallow well can range from $50,000 - $150,000 whereas a deep well can range from $500,000 - $1,000,000.

How expensive is OCTG casing per foot?

OCTG casing costs vary by size, grade, and length, but the average cost per foot of casing can range from $1.00 to $2.00.

What parameter in the cost per footage relationship in drilling is not related to bit performance?

Operator experience

What is meant by Net Footage of an oil well?

Net footage of an oil well refers to the length of the wellbore drilled into the subsurface of the earth. The wellbore is the cylindrical hole from the surface of the earth to the oil reservoir. The length of the wellbore is measured in feet and is referred to as the net footage of the well.

What is the averge cost per foot to drill an oil or gas well in the United States?

The average cost per foot to drill an oil or gas well in the United States varies greatly depending on factors including location and depth. An estimate from 2021 by Drillinginfo, an oil and gas industry data company, shows that the average cost to drill a well varies from around $15,000-30,000 per foot in the most active shale plays like the Permian Basin in Texas and the Marcellus Shale in Pennsylvania to around $50-150,000 per foot in other regions like the Gulf of Mexico or the Arctic National Wildlife Refuge.

What would it cost drill and complete a 13,000 foot oil well in choctaw county, alabama?

The exact cost to drill and complete a 13,000 foot oil well in Choctaw County, Alabama would depend on a variety of factors, such as the geology of the region, the size and type of oil well to be drilled, and the cost of labor and materials. Generally, the cost of drilling a 13,000 foot oil well in Alabama could range between $1 million and $2 million, depending on the specifics of the project.

Oilfield Glossary | Oil and Gas Glossary

Trip definition.

V: shortened form of “ make a trip .”

Terms Related to Trip

The operation of hoisting the drill stem out of and returning it to the wellbore. See make a trip.

Make a trip

To hoist the drill stem out of the wellbore to perform one of a number of operations such as changing bits, taking a core, and ...

The action of pull out and subsequently running back into the hole a string of drill pipe or tubing. Making a round trip is also ...

Trip margin

The small amount of additional mud weight carried over that needed to balance formation pressure to overcome the pressure-reduction effects caused by swabbing when a ...

A small mud tank with a capacity of 10 to 15 barrels, usually with 1-barrel or h-barrel divisions, used to ascertain the amount of mud ...

Come out of the hole

To pull the drill stem out of the wellbore to change the bit, to change from a core barrel to the bit, to run electric ...

Gas that enters the wellbore when the mud pump is shut down and pipe is being pulled from the wellbore. The gas may enter because ...

» Find the definition of Trip in Wikipedia.

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• Global Standards

Definition(s)

The shutdown is activated automatically by the control/monitoring system.

Source: API STD 689, Collection and Exchange of Reliability and Maintenance Data for Equipment, First Edition, July 2007.  Global Standards

shutdown of machinery from normal operating condition to full stop

Note 1 to entry: Two types of shutdown can be identified:

a) Trip: the shutdown is activated automatically by the control/monitoring system.

• Real trip: the shutdown is activated as a result of a monitored (or calculated) value in the control system

exceeding a pre-set limit.

• Spurious trip: unexpected shutdown resulting from failure(s) in the control/monitoring system or error(s)

imposed by on control/monitoring system originating from the environment or people.

b) Manual shutdown: the machinery is stopped by an intended action of the operator (locally or form the

control room).

Note 2 to entry: Sometimes statements like “equipment trip” or “spurious trip” can be misleading terminology

used for failures causing (rotating) equipment shutdown, especially when it is treated as failure mode in reliability

data or modelling. A failure mechanism (see Table B.2 of ISO 14224[15]) can be of various types (e.g. mechanical,

instrument) and should not be mixed with the term failure modes (of which one is spurious trip). Failure modes

are not necessarily instrument-related failures, but could be mechanical failures. See for example failure modes

in Table B.6 of ISO 14224[15] for rotating equipment.

[SOURCE: ISO 14224]

Source: ISO/TR 12489:2013(E) Reliability modelling and calculation of safety systems.  Global Standards

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#oil&gas_tripping.

Tripping refers to the process of removing and/or replacing pipe from the well when it is necessary to change the bit or other piece of the drill string, or when preparing to run certain tests in the well bore.

A driller “trips” the drill string by removing the entire string from the borehole and then goes back to bottom with it. This may be for a “bit trip” to replace a worn or broken bit, to adjust the number and type of joints in the bottom hole assembly or to just inspect the string for damage or leaks.

Tripping is typically counted as non-productive time and is therefore to be minimized as much as possible. The more time spent turning to the right (actually drilling and making progress) the better the crew, driller and pusher look to the higher-ups.

Tripping Operations - Best Practices

1. Preparation The Drilling Supervisor shall approve and provide written instructions to the Contractor Toolpusher prior to any trip out of the hole. These instructions shall include the:

sequence of operations i.e. flow check, circulate bottoms up, drop survey, etc.

maximum allowed overpull

procedures if tight hole is encountered

maximum running/pulling speeds

preparation of equipment for the following operation when out of the hole

Pipe Tally The drilling contractor shall ensure that a master drill pipe tally book is maintained at all times. This shall include stand number, single number, single identification, drill pipe grade, single length, stand length and total length. Trip Tank Prior to pulling out of the hole, the trip tank shall be filled. The fill-up pump to the trip tank should never be left running while tripping out.

Circulation

For any trip out of the hole, a minimum of one bottoms up circulation, or appropriate circulation for deviated wells, shall be performed.

When circulating to condition mud, a circulating rate of 50 - 75% of the normal circulating rate shall be used.

A trip sheet shall be filled out by the Driller and Mud logging contractor for each trip out of the hole.

2 - General Guidelines

Responsibilities

The Drilling Supervisor shall be on the rig floor for the first 10 stands during tripping out to observe for correct hole fill, overpull, etc. He shall also be on the rig floor for the last five stands when tripping in, tight hole problems, testing mud motors & MWD, RIH across liner hanger and when casing 3 stands off bottom.

Pipe Movements

Care shall be exercised to minimise surge/swab pressures by controlling the speed of pipe movements.

Pull the pipe carefully and check for swabbing. In the event of the hole swabbing, the pipe shall be run back to bottom and the hole circulated bottoms up. Mudloggers shall run the swab programme prior to each round trip to determine the maximum trip speed.

Notes: A hole is swabbing whenever the volume of fluid required to fill the hole is less than the volume of steel pulled out of the hole. THE HOLE CAN BE SWABBING WITHOUT FLOW AT THE FLOWLINE.

Circulation, Hole Fill, and Pipe Fill

During tripping operations, the hole shall be kept full at all times.

The pipe shall be filled every 10 stands while running in the hole and the displacement checked.

When pulling the pipe, the hole shall be kept full from the trip tank. The hole shall be checked regularly to ensure that it is taking the correct amount of fluid.

The volume required to fill the hole every 3-5 stands shall be recorded in the Trip Sheet until the bit is out of the hole.

Tight Hole / Bridging Conditions

If tight hole or bridging conditions occur during trips, the pipe shall be pulled back to the nearest stand and reaming/washing commenced in accordance with stuck pipe procedure.

If tight spots occur while tripping out, the top drive or kelly shall be engaged to commence reaming and circulating out.

Reaming trips might be required prior to running LWD/density tools and/or 7in liner.

Directional Wells

While tripping out of the hole from below the surface casing in directional wells:

reciprocate at all times and rotate the pipe at intervals while circulating and conditioning the mud prior to POOH

record the pick-up, slack-off and rotating weight indicator readings with the mud pump off. Note: These values shall be used to monitor changes in drag during pulling out.

the top drive, if available, shall be used to pump out and/or ream out the first 5 to 10 stands off bottom.

Flow Checks

While tripping flow checks shall be taken:

just off bottom

at the cement casing shoe

prior to pulling drill collars through BOP stack

after BHA out of horizontal section

while RIH after drilling out shoe

while RIH before BHA enters horizontal section.

3 - Requirements When Out Of Hole

Time Out of the Hole

The time spent with the pipe out of the hole shall be minimised wherever possible. Operations such as routine repairs and slipping and cutting of the drill-line shall be performed with pipe at the casing shoe whenever possible.

Requirements When Out of Hole

The trip tank volume indicator shall be set at 1/2 barrel gain or loss whenever the trip tank is being circulated on the hole.

Whenever the blind rams are closed, the Driller and the Assistant Driller shall open the rams and check the fluid level at least every half hour, fill the hole as required and report any losses to the Drilling Supervisor. (Before opening blind ram open choke)

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Look up terms beginning with:

1. n. [Drilling]

Gas entrained in the drilling fluid during a pipe trip , which typically results in a significant increase in gas that is circulated to surface. This increase arises from a combination of two factors: lack of circulation when the mud pumps are turned off, and swabbing effects caused by pulling the drillstring to surface. These effects may be seen following a short trip into casing or a full trip to surface.

Alternate Form: TG

See related terms: connection gas ,  short trip ,  tripping pipe

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4 responses to what is “trip gas”.

IT IS A GOOD SHORT NOTICE . THANKS

Good information regarding different type of gases. However, can you please elaborate as to how much quantity of gas shown on the monitor is acceptable?

Depend on the situation. Typically, the gas unit is less than 500 unit = OK.

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