CA2473073C - Vessel for well intervention - Google Patents
Vessel for well intervention Download PDFInfo
- Publication number
- CA2473073C CA2473073C CA2473073A CA2473073A CA2473073C CA 2473073 C CA2473073 C CA 2473073C CA 2473073 A CA2473073 A CA 2473073A CA 2473073 A CA2473073 A CA 2473073A CA 2473073 C CA2473073 C CA 2473073C
- Authority
- CA
- Canada
- Prior art keywords
- pipeline
- intervening
- tap
- fluid flow
- location
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Fee Related
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/20—Driving or forcing casings or pipes into boreholes, e.g. sinking; Simultaneously drilling and casing boreholes
- E21B7/201—Driving or forcing casings or pipes into boreholes, e.g. sinking; Simultaneously drilling and casing boreholes with helical conveying means
- E21B7/203—Driving or forcing casings or pipes into boreholes, e.g. sinking; Simultaneously drilling and casing boreholes with helical conveying means using down-hole drives
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
- B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING
- B63B27/00—Arrangement of ship-based loading or unloading equipment for cargo or passengers
- B63B27/24—Arrangement of ship-based loading or unloading equipment for cargo or passengers of pipe-lines
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
- B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING
- B63B35/00—Vessels or similar floating structures specially adapted for specific purposes and not otherwise provided for
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
- B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING
- B63B35/00—Vessels or similar floating structures specially adapted for specific purposes and not otherwise provided for
- B63B35/44—Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
- B63B35/4413—Floating drilling platforms, e.g. carrying water-oil separating devices
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/64—Drill bits characterised by the whole or part thereof being insertable into or removable from the borehole without withdrawing the drilling pipe
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
- E21B21/085—Underbalanced techniques, i.e. where borehole fluid pressure is below formation pressure
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T137/00—Fluid handling
- Y10T137/0318—Processes
- Y10T137/0402—Cleaning, repairing, or assembling
- Y10T137/0441—Repairing, securing, replacing, or servicing pipe joint, valve, or tank
- Y10T137/0458—Tapping pipe, keg, or tank
Abstract
In one aspect, a method and apparatus for intervening in an offshore pipeline while diverting fluid flow to a storage site is provided, so that production through the offshore pipeline may continue while conducting a pipeline intervention operation. An offshore vessel may be used to divert and store fluid flow while intervening in the pipeline. In another aspect, a method and apparatus for drilling a subsea wellbore with an offshore vessel is provided. The method and apparatus involve drilling the wellbore and casing the wellbore with continuous casing lowered from the offshore vessel.
Description
VESSEL FOR WELL INTERVENTION
BACKGROUND OF THE INVENTION
Field of the Invention Embodiments of the present invention generally relate to an apparatus and method for intervening in offshore pipelines. Embodiments also relate to an apparatus and method for drilling and casing an offshore wellbore.
Description of the Related Art Hydrocarbon production occurs either directly from the earth or from the earth below a body of water. Production directly from the earth is typically termed a "land production operation," while production from the earth below a body of water is ordinarily typically termed an "offshore production operation" or a "subsea"
production operation." To obtain hydrocarbons in either a land production operation or an offshore production operation, casing is inserted into a drilled-out wellbore within the earth formation. Casing isolates the wellbore from the formation, preventing unwanted fluids such as water from flowing from the formation into the wellbore. The casing is perforated at an area of interest within the formation which contains the desired hydrocarbons, and the hydrocarbons flow from the area of interest to the surface of the earth formation to result in the production of the hydrocarbons. Typically, hydrocarbons flow to the surface of the formation through production tubing inserted into the cased wellbore.
Casing is inserted into the formation to form a cased wellbore by a well completion operation. In conventional well completion operations, the wellbore is formed to access hydrocarbon-bearing formations by the use of drilling.
Drilling is accomplished by utilizing a cutting structure that is mounted on the end of a drill support member, commonly known as a drill string. To drill within the wellbore to a predetermined depth, the drill string is often rotated by a top drive or rotary table on a surface platform or rig, or by a downhole motor mounted towards the lower end of the drill string. After drilling to a predetermined depth, the drill string and its cutting structure are removed from the wellbore and a section of casing is lowered into the wellbore. An annular area is thus formed between the string of casing and the formation. The casing string is temporarily hung from the surface of the well.
A cementing operation is then conducted in order to fill the annular area with cement. Using apparatus known in the art, the casing string is cemented into the wellbore by circulating cement into the annular area defined between the outer wall of the casing and the borehole. The combination of cement and casing strengthens the wellbore and facilitates the isolation of certain areas of the formation behind the casing for the production of hydrocarbons.
It is common to employ more than one string of casing in a wellbore. In this respect, the well is drilled to a first designated depth with a cutting structure on a drill string. The drill string is removed. A first string of casing or conductor pipe is then run into the wellbore and set in the drilled out portion of the wellbore, and cement is circulated into the annulus behind the casing string. Next, the well is drilled to a second designated depth, and a second string of casing, or liner, is run into the drilled out portion of the wellbore. The second string is set at a depth such that the upper portion of the second string of casing overlaps the lower portion of the first string of casing. The second liner string is then fixed, or "hung"
off of the existing casing by the use of slips which utilize slip members and cones to wedgingly fix the new string of liner in the wellbore. The second casing string is then cemented. This process is typically repeated with additional casing strings until the well has been drilled to total depth. In this manner, wells are typically formed with two or more strings of casing of an ever-decreasing diameter.
As an alternative to the conventional method, drilling with casing is a method often used to place casing strings of decreasing diameter within the wellbore. This method involves attaching a cutting structure in the form of a drill bit to the same string of casing which will line the wellbore. Rather than running a cutting structure on a drill string, the cutting structure or drill shoe is run in at the end of the casing that will remain in the wellbore and be cemented therein.
Drilling
BACKGROUND OF THE INVENTION
Field of the Invention Embodiments of the present invention generally relate to an apparatus and method for intervening in offshore pipelines. Embodiments also relate to an apparatus and method for drilling and casing an offshore wellbore.
Description of the Related Art Hydrocarbon production occurs either directly from the earth or from the earth below a body of water. Production directly from the earth is typically termed a "land production operation," while production from the earth below a body of water is ordinarily typically termed an "offshore production operation" or a "subsea"
production operation." To obtain hydrocarbons in either a land production operation or an offshore production operation, casing is inserted into a drilled-out wellbore within the earth formation. Casing isolates the wellbore from the formation, preventing unwanted fluids such as water from flowing from the formation into the wellbore. The casing is perforated at an area of interest within the formation which contains the desired hydrocarbons, and the hydrocarbons flow from the area of interest to the surface of the earth formation to result in the production of the hydrocarbons. Typically, hydrocarbons flow to the surface of the formation through production tubing inserted into the cased wellbore.
Casing is inserted into the formation to form a cased wellbore by a well completion operation. In conventional well completion operations, the wellbore is formed to access hydrocarbon-bearing formations by the use of drilling.
Drilling is accomplished by utilizing a cutting structure that is mounted on the end of a drill support member, commonly known as a drill string. To drill within the wellbore to a predetermined depth, the drill string is often rotated by a top drive or rotary table on a surface platform or rig, or by a downhole motor mounted towards the lower end of the drill string. After drilling to a predetermined depth, the drill string and its cutting structure are removed from the wellbore and a section of casing is lowered into the wellbore. An annular area is thus formed between the string of casing and the formation. The casing string is temporarily hung from the surface of the well.
A cementing operation is then conducted in order to fill the annular area with cement. Using apparatus known in the art, the casing string is cemented into the wellbore by circulating cement into the annular area defined between the outer wall of the casing and the borehole. The combination of cement and casing strengthens the wellbore and facilitates the isolation of certain areas of the formation behind the casing for the production of hydrocarbons.
It is common to employ more than one string of casing in a wellbore. In this respect, the well is drilled to a first designated depth with a cutting structure on a drill string. The drill string is removed. A first string of casing or conductor pipe is then run into the wellbore and set in the drilled out portion of the wellbore, and cement is circulated into the annulus behind the casing string. Next, the well is drilled to a second designated depth, and a second string of casing, or liner, is run into the drilled out portion of the wellbore. The second string is set at a depth such that the upper portion of the second string of casing overlaps the lower portion of the first string of casing. The second liner string is then fixed, or "hung"
off of the existing casing by the use of slips which utilize slip members and cones to wedgingly fix the new string of liner in the wellbore. The second casing string is then cemented. This process is typically repeated with additional casing strings until the well has been drilled to total depth. In this manner, wells are typically formed with two or more strings of casing of an ever-decreasing diameter.
As an alternative to the conventional method, drilling with casing is a method often used to place casing strings of decreasing diameter within the wellbore. This method involves attaching a cutting structure in the form of a drill bit to the same string of casing which will line the wellbore. Rather than running a cutting structure on a drill string, the cutting structure or drill shoe is run in at the end of the casing that will remain in the wellbore and be cemented therein.
Drilling
2 with casing is often the preferred method of well completion because only one run-in of the working string into the wellbore is necessary to form and line the wellbore per section of casing placed within the wellbore.
Drilling with casing is especially useful in drilling and lining a subsea wellbore in a deepwater well completion operation. When forming a subsea wellbore, the initial length of wellbore that has been drilled is subject to potential collapse due to soft formations present at the ocean floor. Additionally, sections of wellbore that intersect areas of high pressure can cause damage to the wellbore during the time lapse between the formation of the wellbore and the lining of the wellbore. Drilling with casing minimizes the time between the drilling of the wellbore and the lining of the wellbore, thus alleviating the above problems.
After production of the hydrocarbons at the surface of the earth formation, the hydrocarbons must be stored at a location and subsequently processed to remove undesired contaminants in the hydrocarbons and to produce the desired product. In land production operations, one option for storage and processing involves storing the hydrocarbons at a tank beside the wellbore, removing the hydrocarbons at time intervals from the storage unit with a mobile storage unit, physically transporting the hydrocarbons with the mobile storage unit to a processing unit, removing the hydrocarbons from the mobile storage unit and into the processing unit, and then processing the hydrocarbons at the processing unit.
Another option for storing and processing the hydrocarbons in land production operations includes using a pipeline connected to the production tubing. The hydrocarbons flow from the formation through the perforations, into the production tubing, through the pipeline, and into a storage and processing unit at a remote location. The storage and processing unit typically receives multiple pipelines from multiple land production operations at various wellbores to allow storage and processing of hydrocarbons from multiple locations at one facility
Drilling with casing is especially useful in drilling and lining a subsea wellbore in a deepwater well completion operation. When forming a subsea wellbore, the initial length of wellbore that has been drilled is subject to potential collapse due to soft formations present at the ocean floor. Additionally, sections of wellbore that intersect areas of high pressure can cause damage to the wellbore during the time lapse between the formation of the wellbore and the lining of the wellbore. Drilling with casing minimizes the time between the drilling of the wellbore and the lining of the wellbore, thus alleviating the above problems.
After production of the hydrocarbons at the surface of the earth formation, the hydrocarbons must be stored at a location and subsequently processed to remove undesired contaminants in the hydrocarbons and to produce the desired product. In land production operations, one option for storage and processing involves storing the hydrocarbons at a tank beside the wellbore, removing the hydrocarbons at time intervals from the storage unit with a mobile storage unit, physically transporting the hydrocarbons with the mobile storage unit to a processing unit, removing the hydrocarbons from the mobile storage unit and into the processing unit, and then processing the hydrocarbons at the processing unit.
Another option for storing and processing the hydrocarbons in land production operations includes using a pipeline connected to the production tubing. The hydrocarbons flow from the formation through the perforations, into the production tubing, through the pipeline, and into a storage and processing unit at a remote location. The storage and processing unit typically receives multiple pipelines from multiple land production operations at various wellbores to allow storage and processing of hydrocarbons from multiple locations at one facility
3 without the need for physically transporting the hydrocarbons to the processing unit.
The above options for storage and processing of hydrocarbons produced during land production operations are feasible because of the unlimited space available for storage units and processing units on the land. Offshore production operations, however, require alternative storage and processing methods because of the limited space allotted to hydrocarbon production at the surface of a body of water. Thus, methods for storing large quantities of hydrocarbons at a remote location are currently practiced.
Offshore wells are often drilled and completed by use of a drilling rig.
The drilling rig includes legs which rest on the floor of the body of water and support a rig floor. A hole is located in the rig floor of the drilling rig through which supplies for completing and drilling the wellbore, such as a drill string and casing strings, may be inserted and lowered into the body of water. The wellbore is typically drilled out by use of the drill string, then strings of casing are placed within the drilled-out wellbore to form a cased wellbore. Perforations are created in the casing and the formation as described above. A riser, which is piping which spans the distance of the water from the ocean floor to the surface of the water, is ultimately inserted at the top of the cased wellbore. Because drilling rigs are relatively expensive to maintain above the wellbore after the completion operation, the drilling rig is removed from its location above the completed wellbore and employed to drill a subsequent wellbore at a different location. At this point, production of the hydrocarbons and subsequent storage of the hydrocarbons becomes an issue.
One method for producing and storing hydrocarbons in offshore operations involves first building a production platform on the ocean floor.
Like the drilling rig, the production platform includes a platform supported on legs which extend to the ocean floor. Production tubing is lowered from a hole which exists in
The above options for storage and processing of hydrocarbons produced during land production operations are feasible because of the unlimited space available for storage units and processing units on the land. Offshore production operations, however, require alternative storage and processing methods because of the limited space allotted to hydrocarbon production at the surface of a body of water. Thus, methods for storing large quantities of hydrocarbons at a remote location are currently practiced.
Offshore wells are often drilled and completed by use of a drilling rig.
The drilling rig includes legs which rest on the floor of the body of water and support a rig floor. A hole is located in the rig floor of the drilling rig through which supplies for completing and drilling the wellbore, such as a drill string and casing strings, may be inserted and lowered into the body of water. The wellbore is typically drilled out by use of the drill string, then strings of casing are placed within the drilled-out wellbore to form a cased wellbore. Perforations are created in the casing and the formation as described above. A riser, which is piping which spans the distance of the water from the ocean floor to the surface of the water, is ultimately inserted at the top of the cased wellbore. Because drilling rigs are relatively expensive to maintain above the wellbore after the completion operation, the drilling rig is removed from its location above the completed wellbore and employed to drill a subsequent wellbore at a different location. At this point, production of the hydrocarbons and subsequent storage of the hydrocarbons becomes an issue.
One method for producing and storing hydrocarbons in offshore operations involves first building a production platform on the ocean floor.
Like the drilling rig, the production platform includes a platform supported on legs which extend to the ocean floor. Production tubing is lowered from a hole which exists in
4 the production platform into the riser and the cased wellbore to the area of interest which contains the perforations, then the hydrocarbons flow through the production tubing to a storage unit located on the production platform. The production platform is usually not large enough to accommodate the large volume of hydrocarbons which flow through the production tubing to the production platform; therefore, the production platform must only store hydrocarbons until a tanker arrives to transport the hydrocarbons from the storage unit to a larger storage and processing unit at another location. This method is expensive because each production platform above each wellbore which must be constructed and maintained represents a relatively large expense.
Alternatively, a subsea well intervention vessel having processing equipment coupled to storage tanks and having well intervention equipment may be utilized to produce hydrocarbons through coiled tubing drilling or to store or process hydrocarbon mixtures produced from underbalanced drilling, as described in U.S. Publication Number 2003/0000740 published on January 2, 2003, filed by Haynes et al. and entitled "Subsea Well Intervention Vessel". The intervention equipment is theoretically capable of reentering existing production wells without changing the wellbore from its production mode.
As a more economic alternative to installing a production platform above each wellbore, a second method of producing and storing hydrocarbons in an offshore operation is more often practiced. Rather than building and maintaining a production platform for each wellbore, the median step in the production and storage operation which includes the production platform is eliminated by satelliting. Satelliting involves installing pipelines at each wellbore and routing all of the pipelines to a common storage and processing location, typically termed a "satellite unit," through the pipelines. The pipelines remain underwater from the wellbore until reaching the storage and processing unit.
Alternatively, a subsea well intervention vessel having processing equipment coupled to storage tanks and having well intervention equipment may be utilized to produce hydrocarbons through coiled tubing drilling or to store or process hydrocarbon mixtures produced from underbalanced drilling, as described in U.S. Publication Number 2003/0000740 published on January 2, 2003, filed by Haynes et al. and entitled "Subsea Well Intervention Vessel". The intervention equipment is theoretically capable of reentering existing production wells without changing the wellbore from its production mode.
As a more economic alternative to installing a production platform above each wellbore, a second method of producing and storing hydrocarbons in an offshore operation is more often practiced. Rather than building and maintaining a production platform for each wellbore, the median step in the production and storage operation which includes the production platform is eliminated by satelliting. Satelliting involves installing pipelines at each wellbore and routing all of the pipelines to a common storage and processing location, typically termed a "satellite unit," through the pipelines. The pipelines remain underwater from the wellbore until reaching the storage and processing unit.
5 Special problems are currently encountered when satelliting. The hydrocarbons must often travel long distances through the underwater pipelines to reach the satellite unit. The water through which the hydrocarbons must pass is very low in temperature, especially at the ocean floor where the pipelines are commonly placed. Because of the cold temperatures within the water, flowing the liquid hydrocarbons underwater for long distances is often challenging. One problem which may result from the cold temperature of the water involves the viscosity of the hydrocarbons. Viscosity of liquid hydrocarbons increases as the hydrocarbons decrease in temperature. The higher the viscosity of the hydrocarbon liquid, the lower the flow rate of the hydrocarbon liquid becomes.
Therefore, the colder the water surrounding the pipelines becomes, the more difficult or impossible flowing the hydrocarbons from the wellbore to the storage unit becomes. Decreasing viscosity of the liquid hydrocarbons flowing in the pipeline may ultimately cause blockage within the pipeline, reducing or halting hydrocarbon production.
A second problem which may result from the cold temperature of the water involves the changing temperatures of the hydrocarbons during their production. Within the wellbore, temperatures are high, causing the hydrocarbons to possess a high temperature. The hydrocarbons within the wellbore may contain both the liquid and gas phases. As described above, the environment within the water when the hydrocarbons travel through the pipelines consists of low temperatures. Then, when the hydrocarbons are flowed from the pipeline up to the satellite unit, the temperature of the environment of the hydrocarbons becomes increasingly higher as the temperature increases with decreasing depth within the water. These temperature variations when using pipeline to transport produced hydrocarbons to the satellite unit often result in precipitation of the hydrocarbons on the inside of the pipeline. Eventually, the precipitation build-up may result in partial or total blockage of the flow path through the pipeline, decreasing or
Therefore, the colder the water surrounding the pipelines becomes, the more difficult or impossible flowing the hydrocarbons from the wellbore to the storage unit becomes. Decreasing viscosity of the liquid hydrocarbons flowing in the pipeline may ultimately cause blockage within the pipeline, reducing or halting hydrocarbon production.
A second problem which may result from the cold temperature of the water involves the changing temperatures of the hydrocarbons during their production. Within the wellbore, temperatures are high, causing the hydrocarbons to possess a high temperature. The hydrocarbons within the wellbore may contain both the liquid and gas phases. As described above, the environment within the water when the hydrocarbons travel through the pipelines consists of low temperatures. Then, when the hydrocarbons are flowed from the pipeline up to the satellite unit, the temperature of the environment of the hydrocarbons becomes increasingly higher as the temperature increases with decreasing depth within the water. These temperature variations when using pipeline to transport produced hydrocarbons to the satellite unit often result in precipitation of the hydrocarbons on the inside of the pipeline. Eventually, the precipitation build-up may result in partial or total blockage of the flow path through the pipeline, decreasing or
6 stopping hydrocarbon production. Reduced hydrocarbon production decreases the profitability of the wellbore.
Other problems which require pipeline intervention to reduce blockage include paraffin deposits which often build up in the pipelines due to the presence and flow of oil, as well as gas hydration when gas is present in the hydrocarbon stream. Some form of pipeline intervention must occur to reduce blockage within the pipeline caused by cold and variable temperatures. Pipeline intervention may also be necessary to repair holes or tears in the pipeline caused by corrosion of the pipeline or holes, tears, or bends due to physical assault of the pipeline.
Currently, an intervention operation requires a remotely operated vehicle to raise the pipeline off the ocean floor, cut out the damaged section of pipe, install pipe connections on the cut ends of the pipeline, and then install and connect a new section of pipeline. Other intervention operations require stoppage of the flow of hydrocarbons through the pipeline to introduce treatment fluid into the pipeline to remove blockage within the pipeline. For the intervention process, to prevent hydrocarbons from escaping from the pipeline to the water, hydrocarbon flow must be halted during the intervention operation.
Pipeline intervention operations are costly. Because interventions require physical invasion of the interior of the pipeline, hydrocarbon flow must be halted to conduct an intervention. Stopping the flow of the hydrocarbons reduces the profitability of the well, as the equipment and labor required to produce the hydrocarbons is still funded while no hydrocarbon production is occurring to offset these costs. It is therefore desirable to allow hydrocarbon production during pipeline intervention operations in offshore wells.
Light intervention vessels are available which make it possible to conduct operations such as well servicing, e.g. well logging and general maintenance. Such vessels, however, cannot be considered appropriate
Other problems which require pipeline intervention to reduce blockage include paraffin deposits which often build up in the pipelines due to the presence and flow of oil, as well as gas hydration when gas is present in the hydrocarbon stream. Some form of pipeline intervention must occur to reduce blockage within the pipeline caused by cold and variable temperatures. Pipeline intervention may also be necessary to repair holes or tears in the pipeline caused by corrosion of the pipeline or holes, tears, or bends due to physical assault of the pipeline.
Currently, an intervention operation requires a remotely operated vehicle to raise the pipeline off the ocean floor, cut out the damaged section of pipe, install pipe connections on the cut ends of the pipeline, and then install and connect a new section of pipeline. Other intervention operations require stoppage of the flow of hydrocarbons through the pipeline to introduce treatment fluid into the pipeline to remove blockage within the pipeline. For the intervention process, to prevent hydrocarbons from escaping from the pipeline to the water, hydrocarbon flow must be halted during the intervention operation.
Pipeline intervention operations are costly. Because interventions require physical invasion of the interior of the pipeline, hydrocarbon flow must be halted to conduct an intervention. Stopping the flow of the hydrocarbons reduces the profitability of the well, as the equipment and labor required to produce the hydrocarbons is still funded while no hydrocarbon production is occurring to offset these costs. It is therefore desirable to allow hydrocarbon production during pipeline intervention operations in offshore wells.
Light intervention vessels are available which make it possible to conduct operations such as well servicing, e.g. well logging and general maintenance. Such vessels, however, cannot be considered appropriate
7 platforms for interventions requiring drilling or hydrocarbon production as they are not sufficiently stable for such operations and are too small to handle the volumes of material that result from drilling. As such, the vessels must be supplemented with support vessels to receive produced hydrocarbons. Furthermore, light intervention vessels require large capital investments as compared with the returns that can be generated, particularly as they are highly vulnerable to bad weather such that intervention costs are relatively high and utilization time is relatively low. Even more cost is required to employ an additional support vessel.
Because of the above disadvantages, no attempts have been made to use continuous casing to drill and line a wellbore from floating units or to allow hydrocarbon production during intervention operations in offshore wells.
Furthermore, while drilling with sections of casing minimizes the time between the drilling of the wellbore and the lining of the wellbore, it remains desirable to further minimize the time between the drilling and lining of the wellbore to decrease production costs and further prevent collapse of the formation during the time lapse. It is also desirable to provide an alternative to the costly drilling platform or the option of two vessels (one having the drilling equipment and one having storage equipment) by allowing drilling with casing completion operations as well as production operations to be conducted concurrently from the same structure.
SUMMARY OF THE INVENTION
In one aspect, the present invention provides a method and apparatus for intervening in a pipeline, comprising providing a pipeline for transporting fluid flow from an offshore well to a location, diverting the fluid flow to a storage site, and intervening in the pipeline. Diverting the fluid flow to the storage site may comprise diverting the fluid flow to an offshore tanker while intervening in the pipeline from the offshore tanker.
Because of the above disadvantages, no attempts have been made to use continuous casing to drill and line a wellbore from floating units or to allow hydrocarbon production during intervention operations in offshore wells.
Furthermore, while drilling with sections of casing minimizes the time between the drilling of the wellbore and the lining of the wellbore, it remains desirable to further minimize the time between the drilling and lining of the wellbore to decrease production costs and further prevent collapse of the formation during the time lapse. It is also desirable to provide an alternative to the costly drilling platform or the option of two vessels (one having the drilling equipment and one having storage equipment) by allowing drilling with casing completion operations as well as production operations to be conducted concurrently from the same structure.
SUMMARY OF THE INVENTION
In one aspect, the present invention provides a method and apparatus for intervening in a pipeline, comprising providing a pipeline for transporting fluid flow from an offshore well to a location, diverting the fluid flow to a storage site, and intervening in the pipeline. Diverting the fluid flow to the storage site may comprise diverting the fluid flow to an offshore tanker while intervening in the pipeline from the offshore tanker.
8 In another aspect, the present invention provides an apparatus for remediating an offshore pipeline and producing well fluids, comprising a vessel capable of storing well fluids flowing through the pipeline from a well, a first tubular body disposed within the vessel for diverting well fluid flow from the pipeline to the vessel for storing, and a second tubular body disposed within the vessel for remediating the pipeline. The vessel may be capable of diverting well fluid flow through the first tubular body while remediating the pipeline through the second tubular body and capable of remediating the pipeline without interruption of production of well fluids.
In yet another aspect, the present invention provides a method of drilling a subsea wellbore from a vessel, comprising locating the vessel, the vessel having continuous casing, drilling the wellbore, and casing the wellbore with the continuous casing. Drilling and casing the wellbore may comprise drilling the wellbore with the continuous casing.
In yet a further aspect, the present invention provides a vessel for drilling an offshore wellbore, comprising a positionable vessel, continuous casing having an earth removal member operatively attached thereto disposed on the vessel for drilling the wellbore, and storage equipment disposed on the vessel for storing hydrocarbon fluid produced from the wellbore. The vessel may further comprise processing equipment connected to the storage equipment for processing the hydrocarbon fluid produced from the wellbore.
The present invention advantageously allows offshore or subsea intervention operations to occur within a pipeline while simultaneously producing hydrocarbons from the pipeline, thus increasing profitability of the wellbore.
Further, the present invention permits formation of an offshore or subsea cased wellbore with one run-in of the casing, and also allows for storage and/or processing of hydrocarbons during the drilling process on the same vessel which
In yet another aspect, the present invention provides a method of drilling a subsea wellbore from a vessel, comprising locating the vessel, the vessel having continuous casing, drilling the wellbore, and casing the wellbore with the continuous casing. Drilling and casing the wellbore may comprise drilling the wellbore with the continuous casing.
In yet a further aspect, the present invention provides a vessel for drilling an offshore wellbore, comprising a positionable vessel, continuous casing having an earth removal member operatively attached thereto disposed on the vessel for drilling the wellbore, and storage equipment disposed on the vessel for storing hydrocarbon fluid produced from the wellbore. The vessel may further comprise processing equipment connected to the storage equipment for processing the hydrocarbon fluid produced from the wellbore.
The present invention advantageously allows offshore or subsea intervention operations to occur within a pipeline while simultaneously producing hydrocarbons from the pipeline, thus increasing profitability of the wellbore.
Further, the present invention permits formation of an offshore or subsea cased wellbore with one run-in of the casing, and also allows for storage and/or processing of hydrocarbons during the drilling process on the same vessel which
9 houses the equipment used to form the cased wellbore, increasing the profitability of the wellbore.
BRIEF DESCRIPTION OF THE DRAWINGS
So that the manner in which the above recited features of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
Figure 1 is a sectional view of a satellite pipeline operation. A first tap is inserted into the pipeline for connection to a vessel at or near the surface of the water.
Figure 2 is a sectional view of the satellite pipeline operation of Figure 1, with a first tubular member lowered from the vessel and connected to the first tap to divert fluid flow from the pipeline to the vessel.
Figure 3 is a sectional view of the satellite pipeline operation of Figure 1, with a second tap inserted into the pipeline downstream from the first tap to remediate the pipeline.
Figure 4 is a sectional view of the satellite pipeline operation of Figure 1, with a second tubular member lowered from the vessel and connected to the second tap to remediate the pipeline.
Figure 5 is a sectional view of a drilling operation with continuous casing, where the drilling operation is performed from a vessel at or near the surface of the water. The continuous casing is poised above a hole in the floor of the vessel prior to drilling.
Figure 6 is a sectional view of the drilling operation of Figure 5, where the cutting structure operatively attached to the continuous casing drills through the ocean floor and into the formation to form a wellbore.
Figure 7 is a sectional view of the drilling operation of Figure 5, where the continuous casing is drilled into the formation to a desired depth. The continuous casing is severed at a location, and the cutting structure is retrieved from the wellbore.
Figure 8 is a side view of an embodiment of a vessel which may house and facilitate use of equipment for remediating a pipeline or drilling a wellbore.
Figure 9 is a schematic layout diagram of pipeline intervention equipment on the vessel of Figure 8.
Figure 10 is a schematic view of an alternate embodiment of a vessel which defines moon pools through which drilling or intervention may be performed.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT
Figure 8 illustrates a vessel 10 embodying the present invention. Figure 8 is based on a drawing extracted from "First Olsen Tankers" and shows a shuttle tanker of the type widely used in the North Sea. In the vessel 10, the only modification made to the standard shuttle tanker is the mounting of a superstructure 107 above the main deck (not shown) of the vessel 10, for example at a height of approximately 3 meters so as to exist above the installed deck pipes and vents (not shown). A standard North Sea specified shuttle tanker with dynamic positioning can be readily charted and fitted with a new deck above the installed deck pipes and vents, upon which deck can be installed, for example, the following equipment: a skid mounted derrick riser handling unit with subsea control panel; stumps for the subsea well intervention equipment; a pipe rack;
coiled tubing reels, a control unit, and a power pack; a cementing unit and blender, production test equipment including a choke manifold, heater treater, separators, degassing boot and gas flare; tanks for kill mud; a closed circulation system for handling drilling mud and drilled solids during underbalanced drilling;
storage tanks for chemical and solid wastes; cranes for subsea equipment and supplies;
remote controlled vehicles for working and observation tasks; and water supplies for cooling and fire fighting services (see below). All the equipment necessary for pipeline intervention and/or drilling is mounted on the superstructure 107, including a crane 108. The detailed layout of the equipment mounted on the superstructure 107 of Figure 8 is shown in Figure 9.
Referring to Figure 9, a skid deck 109 is centrally mounted on the superstructure 107 adjacent a gantry crane 110. On the other side of the gantry crane 110 is a riser deck and laydown area 335. Between the crane 108 and the skid deck 109 are a subsea laydown area and equipment stumps 340, remotely operated vehicles 341, and a subsea control unit 342. Also located on the superstructure 107 are a gas compressor 343, air compressor 344, and firewater pumps 345. Coiled tubing drilling equipment 111 of conventional form (described below) is mounted adjacent the gantry crane 110, including but not limited to a laydown area, power pack, control unit, goose neck, injector head, conveyor, reels, and blowout preventors. A slickline contractor 302 and an electric line contractor 301 may be disposed by the coiled tubing drilling equipment 111. A
separator assembly 112 and ancillary drilling support equipment assembly 106 are also mounted on the superstructure 107. The separator assembly 112 may include, but is not limited to, separators 310A-D, chokes 311, a heater treater 312, a cuttings treatment unit 313, mud cleaning unit 314, produced water cleaning unit 315, metering gas oil unit 316, and chemical injection unit 317. The ancillary drilling support equipment assembly 106 may include but is not limited to kill mud unit 320, completion fluid unit 321, active mud tanks 322 and 323, hexanol (HeOH) unit 324, spare unit 325, waste unit 326, cuttings waste unit 327, mud pumps 328, and cement unit 329. Between the drilling support equipment assembly 106 and the separator assembly 112 are a process control unit 330 and a laboratory 331.
All other equipment relied upon to achieve the required direct well intervention is also mounted on the superstructure 107. The separator assembly 112 is connected to an appropriately positioned flare stack (not shown), for example at the stern (not shown) of the vessel 10 and to the storage tanks (not shown) of the vessel 10 so as to enable produced hydrocarbon fluids to be stored for subsequent transport.
In use, the vessel 10 is dynamically positioned above a subsea well or pipeline. The skid deck 109 is then moved to an outboard position (not shown) over the subsea well or the pipeline to enable the coiled tubing equipment 111 to be coupled to a riser above the subsea well for drilling or to a tap 80 or 90 (see Figures 1-4) installed within the pipeline 20. Appropriate interventions can then be made via the tubular member or coiled tubing drilling can be conducted in a manner which produces a multiphase mixture of the hydrocarbon fluid that is subsequently separated into its different phases in the separator assembly 112.
Figure 10 shows an alternate arrangement of the vessel 10 for mounting equipment for use with the present invention. As an alternative to providing a skid deck displaceable to an outboard position, as shown in Figures 8-9, the drilling and/or intervention equipment could be mounted adjacent a moon pool 113 or 114 extending through the deck of the vessel 10. Particularly, the components are mounted adjacent moon pools 113 and 114 extending vertically through the structure of the vessel 10. Three cranes 115, 116, and 117 can extend over the moon pools 113 and 114 and areas indicating cargo manifolds 118, a derrick module 119, and a lay down area 120. Area 121 houses gas compression and process units, area 122 a flare boom, area 123 a flare knock-out drum skid, and area 124 a further lay down area served by a crane 125.
When employing a standard double hull shuttle tanker, the modifications required to produce the vessel 10 illustrated in Figure 10 which can function in accordance with the present invention would include an upgrade of the dynamic positioning capability, installation of a first moon pool for intervention and/or drilling work, installation of a second moon pool for remotely operated vehicle work, mounting of cranes, process equipment and lay down areas for deck-mounted equipment, and the mounting of flare facilities and associated utilities.
Figures 1-4 show the vessel 10 of the present invention, which is capable of diverting flow from a pipeline 20 and/or remediating the pipeline during a satellite pipeline operation. A superstructure 215 mounted on legs exists on the vessel 10 and has a hole 218 therein for lowering intervention equipment therethrough. The vessel 10, in the embodiment shown, includes a hole 213 in its floor essentially in line with the hole 218 for lowering intervention equipment therethrough. Referring to Figure 1, in the satellite pipeline operation, the pipeline 20 is located at or near the floor 30 of a body of water 40. The pipeline 20 initially transports well fluid 45, typically hydrocarbon fluid, from a wellbore 50 disposed in the floor 30 to a satellite storage unit 55 disposed at least partially above a surface 60 of the body of water 40.
The wellbore 50 is drilled into the floor 30 to a depth at which well fluid 45 exists. The wellbore 50 may be completed with casing 51, as shown in Figures 1-4, or may remain an open hole wellbore with no casing disposed therein. The pipeline 20 is connected to production tubing 52. The production tubing 52 is located within the wellbore 50 and extends at least to an area of interest (not shown) in the floor 30, which is a depth at which the well fluid 45 exists.
The production tubing 52 typically includes packing elements (not shown) disposed around its outer diameter which extend to the wellbore 50 above and below the area of interest in the floor 30 to isolate the area of interest within the wellbore 50.
Perforations (not shown) are inserted into the production tubing 52 across from the area of interest in the wellbore 50, and perforations (not shown) are likewise inserted into the area of interest in the wellbore 50. Well fluid 45 thus flows from the area of interest in the wellbore 50 into an annular area 53 between the outer diameter of the production tubing 52 and the wellbore 50, then up through the production tubing 52 disposed within the wellbore 50 and into the pipeline 20.
The satellite storage unit 55 is capable of storing well fluid 45 received from the pipeline 20. The satellite storage unit 55 may also possess well fluid processing capabilities. In addition to storing and/or processing well fluid 45 from the pipeline 20, the satellite storage unit 55 may also receive well fluid 60 from any number of additional pipelines 65. Each additional pipeline 65 is connected to production tubing (not shown) inserted within a wellbore (not shown), as described above in relation to production tubing 52 within the wellbore 50, at a different location within the floor 30 than the wellbore 50.
In Figure 1, a problem area 70 exists in the pipeline 20 which must be treated in some manner to resume the desired well fluid 45 flow through the pipeline 20. The problem area 70 may include, but is not limited to, partial or total blockage of flow in the pipeline 20 due to precipitation build-up on the inside of the pipeline 20 which must be removed from the pipeline 20, paraffin deposits on the inside of the pipeline 20 which must be descaled or removed, or gas hydration within the pipeline 20. The problem area 70 may also include bends, holes, or corrosion damage to the pipeline 20 which must be repaired. Additionally, the problem area 70 may include stuck equipment which must be dislodged from within the pipeline such as a stuck pig.
Because the problem area 70 disrupts the desired flow of the well fluid 45, an intervention or remediation of the pipeline 20 must be performed. The intervention may include dislodging stuck equipment, removing build-up or deposits in the pipeline 20 causing partial or total blockage of the pipeline 20, and/or repairing damage to the pipeline 20. In all of the above intervention situations, the pipeline 20 must be physically invaded in some fashion to fix the problem area 20 and restore ordinary fluid flow 45 from the wellbore 50 to the satellite storage unit 55.
3105 00'76 The vessel 10 or tanker of the present invention is employed to fix the problem area 70. The vessel 10 may be disposed on the surface 60 of the water 40, partially below the surface 60, or completely below the surface 60. Within the vessel 10 is a second tubular body 12, preferably coiled tubing. A first tubular body 11, also preferably coiled tubing, extends from the vessel 10 into the water 40. The first tubular body 11 may be inserted into a riser pipe (not shown) which extends from the vessel 10 to the floor 30. At an upper end, the first tubular body 11 is sealably connected to a storage tank 13 for storing produced well fluid from the wellbore 50, which may be connected to a processing unit (not shown) on the vessel 10 for processing well fluid 45. The processing unit may include liquid separation equipment. The first tubular body 11 may comprise three tubular sections, including 11 A, 11 B, and 11 C. At its lower end, tubular section 11A is connected, preferably threadedly connected, to an upper end of tubular section 11 B. Tubular section 11 B is a portion of a blow out preventer 9. The blow out preventer 9 includes a large valve 8 which may be closed to control well fluids 45.
The valve 8 is typically closed remotely through hydraulic actuators (not shown).
Tubular section 11B is connected, preferably threadedly connected, at its lower end to an upper end of tubular section 11 C.
Connected to the pipeline 20 in Figure 1 is a first tap 80 which is capable of fluid communication with the pipeline 20 through a first hole 84 in the pipeline 20. The first tap 80 is a tubular body having a valve 81 disposed therein for selective disruption of fluid flow through the tubular body. The first tap 80 is connected to the pipeline 20 through a first clamp 82 disposed around the pipeline 20 and is held in sealing engagement with the pipeline 20 due to sealing members 83A, 83B, 83C, and 83D. Any number of sealing members 83A-D may be employed to secure sealed fluid communication between the first tap 80 and the pipeline 20.
Referring now to Figure 3, a second tap 90 is installed in the pipeline 20 between the problem area 70 and the first tap 80. The second tap 90 is a tubular body with a second valve 91 therein to selectively obstruct fluid flow through the tubular body. A second clamp 92 is sealably disposed around the pipeline 20 by sealing members 93A-D to provide sealed fluid communication between the second tap 90 and the pipeline 20 through a second hole 94 in the pipeline 20.
In operation, the wellbore 50 is drilled into the floor 30 and lined with casing 51, and the pipeline 20 is connected at one end to production tubing 52 within the wellbore 50 and at the opposite end to the satellite storage unit 55.
Fluid flow 45 continues essentially uninhibited through the pipeline 20 from the area of interest in the wellbore 50 to the satellite storage unit 55 until a problem area 70 develops in the pipeline. The vessel 10 is located above the pipeline near the problem area 70 to conduct a pipeline intervention operation and remove or repair the problem area 70.
Once the vessel 10 is positioned above the pipeline 20 near the problem area 70, a first tap 80, with the first valve 81 in the closed position, is installed into the pipeline 20 between the problem area 70 and the wellbore 50. To install the first tap 80, a cutting tool (not shown) such as a milling tool, which is known to those skilled in the art, may be utilized to drill the first hole 84 in the pipeline 20.
The first clamp 82 is opened and positioned around the pipeline 20 at the desired point of insertion of the first tap 80. The sealing members 83A-D disposed between the first clamp 82 and the pipeline 20 are used to produce and maintain a fluid-tight sealed connection between the first tap 80 and the pipeline 20.
After installation of the first tap 80, the first tubular member 11 is lowered from the vessel 10 through the hole 113 in the floor of the vessel 10, which may be the skid deck 109 in the outboard position of Figures 8-9 or the moon pool 113 or 114 of Figure 10, depending upon the configuration of the vessel 10 which is used.
Next, the lower end of the first tubular member 11 is connected, preferably threadedly connected, to the upper end of the first tap 80. The first valve 81 is then opened to allow well fluid 45 to flow along a sealed path from the perforations in the wellbore 50 into the production tubing 52 through the perforations in the production tubing 52, and into the pipeline 20. Then the fluid flow 45 is diverted from further flow through the pipeline 20 to flow up through first tap 80 and the first tubular member 11 into the storage tank 13. From the storage tank 13, the well fluid 45 may be diverted to the processing unit which may exist on the vessel 10, or, in the alternative, may eventually be transported to another facility for processing. Figure 2 shows production of the well fluid 45 diverted through the first tap 80 to the vessel 10 for storage and/or processing.
Once well fluid 45 flow is effectively diverted to the vessel 10, the intervention may be accomplished without interruption of the production of the well fluid 45. External patching or bending of the problem area 70 may be conducted without the installation of the additional second tap 90 if the problem area 70 is a hole or bend. If it is desired to intervene into the pipeline 20 by introduction of an object (not shown) or a treatment fluid 21 (see Figure 4) into the pipeline 20, the second tap 90 may be installed on the pipeline 20 between the problem area 70 and the first tap 80.
Installation of the second tap 90 proceeds much as the installation of the first tap 80. Again, the second valve 91 is in the closed position during the installation of the second tap 90. The cutting tool (not shown) such as the milling tool may be utilized to drill the second hole 94 in the pipeline 20. If it is desired to install the second tap 90 (or the first tap 80) at an angle with respect to the pipeline 20, a whipstock (not shown) may be used to guide the cutting tool (e.g., mill) into the pipeline 20 at an angle, as is known in relation to drilling deviated wellbores from parent wellbores. The second clamp 92 is then opened and positioned around the pipeline 20 at the desired point of insertion of the second tap 90.
The sealing members 93A-D disposed between the second clamp 92 and the pipeline 20 are used to produce and maintain a fluid-tight sealed connection between the second tap 90 and the pipeline 20. Figure 3 shows the second tap 90 installed at the pipeline 20 between the problem area 70 and the first tap 80, with the second valve 91 in the closed position.
After the second tap 90 is installed on the pipeline 20, the lower end of the second tubular body 12 is connected, preferably threadedly connected, to an upper end of the second tap 90. The second valve 91 is then opened to allow fluid communication between the vessel 10 and the pipeline 20. If it is desired to introduce an object into the second tubular body 12, then the object may be directly introduced into the upper end of the second tubular body 12. If, as is shown in Figure 4, it is desired to introduce treatment fluid 21 into the pipeline 20 to dislodge, disband, or dissolve partial or total blockage existing in the problem area 70, a storage tank 22 with the treatment fluid 21 housed therein is connected to the upper end of the second tubular body 12. As shown in Figure 4, the treatment fluid 21 is then introduced into the second tubular body 12 to flow through the second tap 90 and into the pipeline 20 toward the problem area 70.
The treatment fluid 21 may be separated from the well fluids present at the satellite storage unit 55 until the pipeline 20 flow between the wellbore 50 to the satellite storage unit 55 is restored. Figure 4 shows the intervention operation conducted through the second tap 90 and the pipeline 20 while production of the well fluid 45 continues uninterrupted from the wellbore 50, through the first tap 80, and into the vessel 10.
The pipeline intervention operation is conducted until the problem area 70 is effectively treated and no longer a threat to production of the well fluid 45.
Upon completion of the pipeline intervention operation, the treatment fluid 21 flow is halted so that treatment fluid 21 is no longer introduced into the second tubular body 12 from the vessel 10. The second valve 91 is then closed and the second tubular body 12 disconnected from the second tap 90. Next, the first valve 81 is closed and the first tubular member 11 disconnected from the first tap 80. The first tubular member 11 as well as the second tubular member 12 is then retrieved to the vessel 10.
Upon closing of the second valve 91 and the first valve 81, the resumed well fluid 45 flow through the pipeline 20 is ultimately essentially unaffected by the pipeline intervention operation. Closing the valves 91, 81 obstructs the alternate paths for the well fluid 45 flow which existed during the intervention operation.
Well fluid 45 may again flow from the wellbore 50 through the production tubing 52, into the pipeline 20, through the former problem area 70, and up into the satellite storage unit 55 for storage and/or processing. Advantageously, the production of well fluid 45 was accomplished either into the storage tank 13 or into the satellite storage unit 55 without interruption through the present invention.
It is understood that the above intervention method and apparatus may be utilized not only in repairing a problem area 70 in the pipeline 20, but also in installing and retrieving subsea equipment. The alternate route through the first tap 80 and the first tubular member 11 may be utilized to divert well fluid 45 flow while installing or retrieving equipment within the water 40 when the installing or retrieving involves physical invasion of the pipeline 20.
In another embodiment of the present invention, the vessel 10 may be utilized to drill into a formation 201 within the floor 30 of the body of water 40 using continuous casing 210. Figures 5-7 show the embodiment of the vessel 10 which is depicted in Figure 10, as the moon pool 113 is located in the bottom of the vessel 10. In the alternative, it is contemplated that the skid deck 109 arrangement of Figures 8-9 may also be utilized to communicate the continuous casing 210 into the formation 201 from the vessel 10.
Referring to Figure 5, the vessel 10 has a superstructure 215 disposed thereon, which is supported above the vessel floor 217 by legs 216. A hole 218 is disposed in the superstructure 215 above the moon pool 113 and substantially in axial line with the moon pool 113. Equipment utilized in the drilling process is lowered through the hole 218 in the superstructure 215 and the moon pool 113 at various stages of the operation.
A riser pipe 221 extends from the moon pool 113 to the ocean floor 30.
The riser pipe 221 provides a path through the body of water 40 to the floor through which the continuous casing 210 may be lowered.
The continuous casing 210 is located on the superstructure 215 on a reel 225. A drilling fluid source 226 is in fluid communication at some location with the continuous casing 210 to provide drilling fluid to the continuous casing 210 at various stages of the drilling operation. A spider 227 or other gripping apparatus having gripping members such as slips (not shown) is also disposed on the superstructure 215 around or within the hole 218 to act as a back-up gripping device during the drilling operation for the continuous casing 210.
Also located on the superstructure 215 is equipment which is utilized to lower as well as retrieve the continuous casing 210 to and from the reel 225 as desired during the drilling operation. To this end, an injector head 230 is disposed on the superstructure 215. The injector head 230 includes conveying members 232 and 233, which are substantially centered around the hole 218 and suspended above the hole 218 by supports 234 and 235. The conveying members 232 and 233 of the injector head 230 act essentially as conveyor belts and are moveable clockwise and counterclockwise around the axis of the conveying members 232 and 233 to lower or retrieve the continuous casing 210 into or out from the hole 218. Also utilized to lower and retrieve the continuous casing 210 is a conveyor belt 240 on a track 241. The conveyor belt 240 on the track 241 is located between the reel 225 and the injector head 230 to obtain the continuous casing 210 from the reel 225 and feed the continuous casing 210 into the injector head 230, or to return the continuous casing 210 to the reel 225 from the injector head 230. The injector head 230 and the conveyor belt 240 on the track 241, as described above, are known to those skilled in the art as a method of feeding continuous tubing. Other aspects of the method of feeding continuous tubing or continuous casing to drill a wellbore known to those skilled in the art are contemplated for use with the present invention.
The continuous casing 210 includes a mud motor 245 disposed therein connected by a releasable connection 246 to the inner diameter of the continuous casing 210. An expandable cutting structure 250 with perforations 260 therethrough for circulating drilling fluid and/or setting fluid is attached to the mud motor 245. The expandable cutting structure 250 includes a body (not shown) and a blade assembly (not shown) disposed on the body, as is disclosed in co-pending U.S. Patent Number 6,953,096 issued on October 11, 2005. As disclosed in the above-referenced application, the blade assembly is movable between a closed position whereby the expandable cutting structure 250 has a smaller outer diameter and an open position whereby the expandable cutting structure 250 has a larger outer diameter. The blade assembly may be moveable between the open position and the closed position through a hydraulic pressure differential created across nozzles (not shown) within the expandable cutting structure 250. The expandable cutting structure 250 may further include a release assembly for providing a secondary means to move the blade assembly from the open position to the closed position, as disclosed in the above-referenced application.
The mud motor 245 may include a shaft (not shown) and a motor operating system (not shown). The mud motor 245, which is the mechanism for rotating the cutting structure 250, is hollow to allow for fluid flow therethrough at various stages of the drilling operation and is preferably a hydraulic mud motor operated by fluids pumped therethrough. The motor operating system turns the shaft, which rotates the expandable cutting structure 250 for drilling into the formation 201. The described mud motor 245 is not the only mud motor available for use with the present invention, as other types of mud motors which are known to those skilled in the art are contemplated for use with the present invention.
In addition to the equipment for drilling with continuous casing 210 described above, the vessel 10 may include hydrocarbon fluid separation equipment (not shown) coupled to one or more storage units (not shown) to receive separated hydrocarbon fluids from the wellbore 270. With the addition of storage capacity, the vessel can collect produced hydrocarbon fluid during drilling with the continuous casing 210, thus eliminating the need for a separate vessel in the event that hydrocarbon fluid is produced during drilling.
In operation, referring to Figure 5, the vessel 10 is located above the floor 30 of the body of water 40, at or near the surface 60 of the body of water 40, so that the hole 218 in the superstructure 215 and the moon pool 113 are substantially aligned with the location at which it is desired to drill into the formation 201. The riser pipe 221 is lowered through the moon pool 113 to connect the vessel floor 217 to the floor 30 of the body of water 40 so that the continuous casing 210 and/or other tools may be lowered into the formation 201 without the interference of the body of water 40 in the drilling process. The continuous casing 210 is then pulled from the reel 225 onto the conveyor belt 240, and the conveyor belt 240 moves counterclockwise along the track 241 to feed the continuous casing 210 into the injector head 230 between the conveying members 232 and 233. The expandable cutting structure 250 is retracted at this point in the operation. The gripping members of the spider 227 are unactivated. Figure 5 illustrates this stage in the drilling operation.
Next, the continuous casing 210 is lowered through the hole 218 in the superstructure 215, through the moon pool 113, and through the riser pipe 221.
Before the continuous casing 210 reaches the floor 30, the expandable cutting structure 250 is expanded, preferably due to hydraulic pressure. The continuous casing 210 is then lowered into the formation 201 while the mud motor 245 imparts torque to the cutting structure 250, thereby drilling a wellbore 270. While the expandable cutting structure 250 is drilling into the formation 201, drilling fluid is circulated from the drilling fluid source 226 into the continuous casing 210, then into the mud motor 245, through the perforations 260 in the expandable cutting structure 250, up through an annulus 275 between the continuous casing 210 and the wellbore 270, up through an annulus 280 between the continuous casing 210 and the riser pipe 221, and up to the vessel 10 for storage or recirculation.
The fluid is circulated to carry cuttings and/or debris from the formation 201, which are produced to the surface during drilling, and to facilitate a path for the drilling of the continuous casing 210 into the formation 201. Figure 6 shows the continuous casing 210 drilling into the formation 201.
The continuous casing 210 is drilled to the desired depth within the formation 201. At this point in the operation, setting fluid is introduced into the continuous casing 210 and circulated into the annulus 275 to set the continuous casing 210 within the wellbore. The expandable cutting structure 250 is then retracted to allow it to fit through the continuous casing 210, and a cutting tool (not shown) is utilized to sever the continuous casing 210 at the floor 30. The conveyor 240 may be manipulated to move clockwise around the track 241 to return the cut-off portion of the continuous casing 210 residing above the floor 30 to the reel 225.
To retrieve the mud motor 245 and the retracted expandable cutting structure 250 from the continuous casing 210, a wireline 290 is lowered from the superstructure 215. The wireline 290 is manipulated into a slot 291 located within the mud motor 245 and then pulled upward, pushed downward, or turned (when the releasable connection 246 is a threadable connection) to release the releasable connection 246, which is preferably a shearable connection which is sheared by pulling upward or pushing downward on the wireline 290. Releasing the releasable connection 246 allows the mud motor 245 and expandable cutting structure 250 to be moveable with respect to the continuous casing 210. Figure shows the wireline 290 retrieving the expandable cutting structure 250 and the mud motor 245 from within the continuous casing 210. The wireline 290 is pulled through the moon pool 113 to the vessel 10 along with the expandable cutting structure 250 and the mud motor 245. Any other apparatus and method for retrieving the mud motor 245 and the cutting structure 250 known by those skilled in the art may be utilized with the present invention.
The drilling method of Figures 5-7 and the vessel 10 which is used to accomplish the drilling advantageously allow the wellbore 270 to be drilled into the formation 201 with one run-in of the continuous casing 210. The wellbore 270 is now ready for subsequent operations such as hydrocarbon production operations.
The same vessel 10 which was used for continuous casing 210 drilling described in Figures 5-7 may also be utilized for intervention operations described in Figures 1-4 if a pipeline 20 is used to produce fluids 45 from the wellbore 270 to the satellite storage unit 55.
The drilling method of Figures 5-7 is especially useful when employing the vessel 10 when drilling an offshore wellbore 270 in an underbalanced condition. Drilling in an underbalanced condition involves maintaining a positive pressure at the surface of the wellbore 270. Underbalanced drilling avoids damage to the wellbore 270 which can result from overbalanced drilling conditions when the drilling fluids invade the formation 201. Underbalanced drilling allows more efficient and faster hydrocarbon production from the formation 201.
Because underbalanced wells produce significant volumes of hydrocarbons, the smaller remotely operated vehicles available are insufficient to store the produced fluids.
The vessel 10 is capable of storing the volumes of fluid produced during underbalanced drilling. Furthermore, when drilling in an underbalanced state, the produced hydrocarbon fluid is a multiphase mixture of gas, solids, and liquids requiring separation. The drilling method of Figures 5-7 allows the capabilities of drilling with continuous casing 210, producing the hydrocarbons, storing the hydrocarbons with the storage equipment, and separating the produced multiphase mixture with the separating equipment using the same vessel 10. For a more detailed description of underbalanced drilling and the problems, especially problems with the resulting multiphase mixture, encountered when drilling underbalanced, refer to U.S. Patent Publication Number 2004-0007131, entitled "Closed Loop Multiphase Underbalanced Drilling Process", filed on July 10, by Chitty et a!..
While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
BRIEF DESCRIPTION OF THE DRAWINGS
So that the manner in which the above recited features of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
Figure 1 is a sectional view of a satellite pipeline operation. A first tap is inserted into the pipeline for connection to a vessel at or near the surface of the water.
Figure 2 is a sectional view of the satellite pipeline operation of Figure 1, with a first tubular member lowered from the vessel and connected to the first tap to divert fluid flow from the pipeline to the vessel.
Figure 3 is a sectional view of the satellite pipeline operation of Figure 1, with a second tap inserted into the pipeline downstream from the first tap to remediate the pipeline.
Figure 4 is a sectional view of the satellite pipeline operation of Figure 1, with a second tubular member lowered from the vessel and connected to the second tap to remediate the pipeline.
Figure 5 is a sectional view of a drilling operation with continuous casing, where the drilling operation is performed from a vessel at or near the surface of the water. The continuous casing is poised above a hole in the floor of the vessel prior to drilling.
Figure 6 is a sectional view of the drilling operation of Figure 5, where the cutting structure operatively attached to the continuous casing drills through the ocean floor and into the formation to form a wellbore.
Figure 7 is a sectional view of the drilling operation of Figure 5, where the continuous casing is drilled into the formation to a desired depth. The continuous casing is severed at a location, and the cutting structure is retrieved from the wellbore.
Figure 8 is a side view of an embodiment of a vessel which may house and facilitate use of equipment for remediating a pipeline or drilling a wellbore.
Figure 9 is a schematic layout diagram of pipeline intervention equipment on the vessel of Figure 8.
Figure 10 is a schematic view of an alternate embodiment of a vessel which defines moon pools through which drilling or intervention may be performed.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT
Figure 8 illustrates a vessel 10 embodying the present invention. Figure 8 is based on a drawing extracted from "First Olsen Tankers" and shows a shuttle tanker of the type widely used in the North Sea. In the vessel 10, the only modification made to the standard shuttle tanker is the mounting of a superstructure 107 above the main deck (not shown) of the vessel 10, for example at a height of approximately 3 meters so as to exist above the installed deck pipes and vents (not shown). A standard North Sea specified shuttle tanker with dynamic positioning can be readily charted and fitted with a new deck above the installed deck pipes and vents, upon which deck can be installed, for example, the following equipment: a skid mounted derrick riser handling unit with subsea control panel; stumps for the subsea well intervention equipment; a pipe rack;
coiled tubing reels, a control unit, and a power pack; a cementing unit and blender, production test equipment including a choke manifold, heater treater, separators, degassing boot and gas flare; tanks for kill mud; a closed circulation system for handling drilling mud and drilled solids during underbalanced drilling;
storage tanks for chemical and solid wastes; cranes for subsea equipment and supplies;
remote controlled vehicles for working and observation tasks; and water supplies for cooling and fire fighting services (see below). All the equipment necessary for pipeline intervention and/or drilling is mounted on the superstructure 107, including a crane 108. The detailed layout of the equipment mounted on the superstructure 107 of Figure 8 is shown in Figure 9.
Referring to Figure 9, a skid deck 109 is centrally mounted on the superstructure 107 adjacent a gantry crane 110. On the other side of the gantry crane 110 is a riser deck and laydown area 335. Between the crane 108 and the skid deck 109 are a subsea laydown area and equipment stumps 340, remotely operated vehicles 341, and a subsea control unit 342. Also located on the superstructure 107 are a gas compressor 343, air compressor 344, and firewater pumps 345. Coiled tubing drilling equipment 111 of conventional form (described below) is mounted adjacent the gantry crane 110, including but not limited to a laydown area, power pack, control unit, goose neck, injector head, conveyor, reels, and blowout preventors. A slickline contractor 302 and an electric line contractor 301 may be disposed by the coiled tubing drilling equipment 111. A
separator assembly 112 and ancillary drilling support equipment assembly 106 are also mounted on the superstructure 107. The separator assembly 112 may include, but is not limited to, separators 310A-D, chokes 311, a heater treater 312, a cuttings treatment unit 313, mud cleaning unit 314, produced water cleaning unit 315, metering gas oil unit 316, and chemical injection unit 317. The ancillary drilling support equipment assembly 106 may include but is not limited to kill mud unit 320, completion fluid unit 321, active mud tanks 322 and 323, hexanol (HeOH) unit 324, spare unit 325, waste unit 326, cuttings waste unit 327, mud pumps 328, and cement unit 329. Between the drilling support equipment assembly 106 and the separator assembly 112 are a process control unit 330 and a laboratory 331.
All other equipment relied upon to achieve the required direct well intervention is also mounted on the superstructure 107. The separator assembly 112 is connected to an appropriately positioned flare stack (not shown), for example at the stern (not shown) of the vessel 10 and to the storage tanks (not shown) of the vessel 10 so as to enable produced hydrocarbon fluids to be stored for subsequent transport.
In use, the vessel 10 is dynamically positioned above a subsea well or pipeline. The skid deck 109 is then moved to an outboard position (not shown) over the subsea well or the pipeline to enable the coiled tubing equipment 111 to be coupled to a riser above the subsea well for drilling or to a tap 80 or 90 (see Figures 1-4) installed within the pipeline 20. Appropriate interventions can then be made via the tubular member or coiled tubing drilling can be conducted in a manner which produces a multiphase mixture of the hydrocarbon fluid that is subsequently separated into its different phases in the separator assembly 112.
Figure 10 shows an alternate arrangement of the vessel 10 for mounting equipment for use with the present invention. As an alternative to providing a skid deck displaceable to an outboard position, as shown in Figures 8-9, the drilling and/or intervention equipment could be mounted adjacent a moon pool 113 or 114 extending through the deck of the vessel 10. Particularly, the components are mounted adjacent moon pools 113 and 114 extending vertically through the structure of the vessel 10. Three cranes 115, 116, and 117 can extend over the moon pools 113 and 114 and areas indicating cargo manifolds 118, a derrick module 119, and a lay down area 120. Area 121 houses gas compression and process units, area 122 a flare boom, area 123 a flare knock-out drum skid, and area 124 a further lay down area served by a crane 125.
When employing a standard double hull shuttle tanker, the modifications required to produce the vessel 10 illustrated in Figure 10 which can function in accordance with the present invention would include an upgrade of the dynamic positioning capability, installation of a first moon pool for intervention and/or drilling work, installation of a second moon pool for remotely operated vehicle work, mounting of cranes, process equipment and lay down areas for deck-mounted equipment, and the mounting of flare facilities and associated utilities.
Figures 1-4 show the vessel 10 of the present invention, which is capable of diverting flow from a pipeline 20 and/or remediating the pipeline during a satellite pipeline operation. A superstructure 215 mounted on legs exists on the vessel 10 and has a hole 218 therein for lowering intervention equipment therethrough. The vessel 10, in the embodiment shown, includes a hole 213 in its floor essentially in line with the hole 218 for lowering intervention equipment therethrough. Referring to Figure 1, in the satellite pipeline operation, the pipeline 20 is located at or near the floor 30 of a body of water 40. The pipeline 20 initially transports well fluid 45, typically hydrocarbon fluid, from a wellbore 50 disposed in the floor 30 to a satellite storage unit 55 disposed at least partially above a surface 60 of the body of water 40.
The wellbore 50 is drilled into the floor 30 to a depth at which well fluid 45 exists. The wellbore 50 may be completed with casing 51, as shown in Figures 1-4, or may remain an open hole wellbore with no casing disposed therein. The pipeline 20 is connected to production tubing 52. The production tubing 52 is located within the wellbore 50 and extends at least to an area of interest (not shown) in the floor 30, which is a depth at which the well fluid 45 exists.
The production tubing 52 typically includes packing elements (not shown) disposed around its outer diameter which extend to the wellbore 50 above and below the area of interest in the floor 30 to isolate the area of interest within the wellbore 50.
Perforations (not shown) are inserted into the production tubing 52 across from the area of interest in the wellbore 50, and perforations (not shown) are likewise inserted into the area of interest in the wellbore 50. Well fluid 45 thus flows from the area of interest in the wellbore 50 into an annular area 53 between the outer diameter of the production tubing 52 and the wellbore 50, then up through the production tubing 52 disposed within the wellbore 50 and into the pipeline 20.
The satellite storage unit 55 is capable of storing well fluid 45 received from the pipeline 20. The satellite storage unit 55 may also possess well fluid processing capabilities. In addition to storing and/or processing well fluid 45 from the pipeline 20, the satellite storage unit 55 may also receive well fluid 60 from any number of additional pipelines 65. Each additional pipeline 65 is connected to production tubing (not shown) inserted within a wellbore (not shown), as described above in relation to production tubing 52 within the wellbore 50, at a different location within the floor 30 than the wellbore 50.
In Figure 1, a problem area 70 exists in the pipeline 20 which must be treated in some manner to resume the desired well fluid 45 flow through the pipeline 20. The problem area 70 may include, but is not limited to, partial or total blockage of flow in the pipeline 20 due to precipitation build-up on the inside of the pipeline 20 which must be removed from the pipeline 20, paraffin deposits on the inside of the pipeline 20 which must be descaled or removed, or gas hydration within the pipeline 20. The problem area 70 may also include bends, holes, or corrosion damage to the pipeline 20 which must be repaired. Additionally, the problem area 70 may include stuck equipment which must be dislodged from within the pipeline such as a stuck pig.
Because the problem area 70 disrupts the desired flow of the well fluid 45, an intervention or remediation of the pipeline 20 must be performed. The intervention may include dislodging stuck equipment, removing build-up or deposits in the pipeline 20 causing partial or total blockage of the pipeline 20, and/or repairing damage to the pipeline 20. In all of the above intervention situations, the pipeline 20 must be physically invaded in some fashion to fix the problem area 20 and restore ordinary fluid flow 45 from the wellbore 50 to the satellite storage unit 55.
3105 00'76 The vessel 10 or tanker of the present invention is employed to fix the problem area 70. The vessel 10 may be disposed on the surface 60 of the water 40, partially below the surface 60, or completely below the surface 60. Within the vessel 10 is a second tubular body 12, preferably coiled tubing. A first tubular body 11, also preferably coiled tubing, extends from the vessel 10 into the water 40. The first tubular body 11 may be inserted into a riser pipe (not shown) which extends from the vessel 10 to the floor 30. At an upper end, the first tubular body 11 is sealably connected to a storage tank 13 for storing produced well fluid from the wellbore 50, which may be connected to a processing unit (not shown) on the vessel 10 for processing well fluid 45. The processing unit may include liquid separation equipment. The first tubular body 11 may comprise three tubular sections, including 11 A, 11 B, and 11 C. At its lower end, tubular section 11A is connected, preferably threadedly connected, to an upper end of tubular section 11 B. Tubular section 11 B is a portion of a blow out preventer 9. The blow out preventer 9 includes a large valve 8 which may be closed to control well fluids 45.
The valve 8 is typically closed remotely through hydraulic actuators (not shown).
Tubular section 11B is connected, preferably threadedly connected, at its lower end to an upper end of tubular section 11 C.
Connected to the pipeline 20 in Figure 1 is a first tap 80 which is capable of fluid communication with the pipeline 20 through a first hole 84 in the pipeline 20. The first tap 80 is a tubular body having a valve 81 disposed therein for selective disruption of fluid flow through the tubular body. The first tap 80 is connected to the pipeline 20 through a first clamp 82 disposed around the pipeline 20 and is held in sealing engagement with the pipeline 20 due to sealing members 83A, 83B, 83C, and 83D. Any number of sealing members 83A-D may be employed to secure sealed fluid communication between the first tap 80 and the pipeline 20.
Referring now to Figure 3, a second tap 90 is installed in the pipeline 20 between the problem area 70 and the first tap 80. The second tap 90 is a tubular body with a second valve 91 therein to selectively obstruct fluid flow through the tubular body. A second clamp 92 is sealably disposed around the pipeline 20 by sealing members 93A-D to provide sealed fluid communication between the second tap 90 and the pipeline 20 through a second hole 94 in the pipeline 20.
In operation, the wellbore 50 is drilled into the floor 30 and lined with casing 51, and the pipeline 20 is connected at one end to production tubing 52 within the wellbore 50 and at the opposite end to the satellite storage unit 55.
Fluid flow 45 continues essentially uninhibited through the pipeline 20 from the area of interest in the wellbore 50 to the satellite storage unit 55 until a problem area 70 develops in the pipeline. The vessel 10 is located above the pipeline near the problem area 70 to conduct a pipeline intervention operation and remove or repair the problem area 70.
Once the vessel 10 is positioned above the pipeline 20 near the problem area 70, a first tap 80, with the first valve 81 in the closed position, is installed into the pipeline 20 between the problem area 70 and the wellbore 50. To install the first tap 80, a cutting tool (not shown) such as a milling tool, which is known to those skilled in the art, may be utilized to drill the first hole 84 in the pipeline 20.
The first clamp 82 is opened and positioned around the pipeline 20 at the desired point of insertion of the first tap 80. The sealing members 83A-D disposed between the first clamp 82 and the pipeline 20 are used to produce and maintain a fluid-tight sealed connection between the first tap 80 and the pipeline 20.
After installation of the first tap 80, the first tubular member 11 is lowered from the vessel 10 through the hole 113 in the floor of the vessel 10, which may be the skid deck 109 in the outboard position of Figures 8-9 or the moon pool 113 or 114 of Figure 10, depending upon the configuration of the vessel 10 which is used.
Next, the lower end of the first tubular member 11 is connected, preferably threadedly connected, to the upper end of the first tap 80. The first valve 81 is then opened to allow well fluid 45 to flow along a sealed path from the perforations in the wellbore 50 into the production tubing 52 through the perforations in the production tubing 52, and into the pipeline 20. Then the fluid flow 45 is diverted from further flow through the pipeline 20 to flow up through first tap 80 and the first tubular member 11 into the storage tank 13. From the storage tank 13, the well fluid 45 may be diverted to the processing unit which may exist on the vessel 10, or, in the alternative, may eventually be transported to another facility for processing. Figure 2 shows production of the well fluid 45 diverted through the first tap 80 to the vessel 10 for storage and/or processing.
Once well fluid 45 flow is effectively diverted to the vessel 10, the intervention may be accomplished without interruption of the production of the well fluid 45. External patching or bending of the problem area 70 may be conducted without the installation of the additional second tap 90 if the problem area 70 is a hole or bend. If it is desired to intervene into the pipeline 20 by introduction of an object (not shown) or a treatment fluid 21 (see Figure 4) into the pipeline 20, the second tap 90 may be installed on the pipeline 20 between the problem area 70 and the first tap 80.
Installation of the second tap 90 proceeds much as the installation of the first tap 80. Again, the second valve 91 is in the closed position during the installation of the second tap 90. The cutting tool (not shown) such as the milling tool may be utilized to drill the second hole 94 in the pipeline 20. If it is desired to install the second tap 90 (or the first tap 80) at an angle with respect to the pipeline 20, a whipstock (not shown) may be used to guide the cutting tool (e.g., mill) into the pipeline 20 at an angle, as is known in relation to drilling deviated wellbores from parent wellbores. The second clamp 92 is then opened and positioned around the pipeline 20 at the desired point of insertion of the second tap 90.
The sealing members 93A-D disposed between the second clamp 92 and the pipeline 20 are used to produce and maintain a fluid-tight sealed connection between the second tap 90 and the pipeline 20. Figure 3 shows the second tap 90 installed at the pipeline 20 between the problem area 70 and the first tap 80, with the second valve 91 in the closed position.
After the second tap 90 is installed on the pipeline 20, the lower end of the second tubular body 12 is connected, preferably threadedly connected, to an upper end of the second tap 90. The second valve 91 is then opened to allow fluid communication between the vessel 10 and the pipeline 20. If it is desired to introduce an object into the second tubular body 12, then the object may be directly introduced into the upper end of the second tubular body 12. If, as is shown in Figure 4, it is desired to introduce treatment fluid 21 into the pipeline 20 to dislodge, disband, or dissolve partial or total blockage existing in the problem area 70, a storage tank 22 with the treatment fluid 21 housed therein is connected to the upper end of the second tubular body 12. As shown in Figure 4, the treatment fluid 21 is then introduced into the second tubular body 12 to flow through the second tap 90 and into the pipeline 20 toward the problem area 70.
The treatment fluid 21 may be separated from the well fluids present at the satellite storage unit 55 until the pipeline 20 flow between the wellbore 50 to the satellite storage unit 55 is restored. Figure 4 shows the intervention operation conducted through the second tap 90 and the pipeline 20 while production of the well fluid 45 continues uninterrupted from the wellbore 50, through the first tap 80, and into the vessel 10.
The pipeline intervention operation is conducted until the problem area 70 is effectively treated and no longer a threat to production of the well fluid 45.
Upon completion of the pipeline intervention operation, the treatment fluid 21 flow is halted so that treatment fluid 21 is no longer introduced into the second tubular body 12 from the vessel 10. The second valve 91 is then closed and the second tubular body 12 disconnected from the second tap 90. Next, the first valve 81 is closed and the first tubular member 11 disconnected from the first tap 80. The first tubular member 11 as well as the second tubular member 12 is then retrieved to the vessel 10.
Upon closing of the second valve 91 and the first valve 81, the resumed well fluid 45 flow through the pipeline 20 is ultimately essentially unaffected by the pipeline intervention operation. Closing the valves 91, 81 obstructs the alternate paths for the well fluid 45 flow which existed during the intervention operation.
Well fluid 45 may again flow from the wellbore 50 through the production tubing 52, into the pipeline 20, through the former problem area 70, and up into the satellite storage unit 55 for storage and/or processing. Advantageously, the production of well fluid 45 was accomplished either into the storage tank 13 or into the satellite storage unit 55 without interruption through the present invention.
It is understood that the above intervention method and apparatus may be utilized not only in repairing a problem area 70 in the pipeline 20, but also in installing and retrieving subsea equipment. The alternate route through the first tap 80 and the first tubular member 11 may be utilized to divert well fluid 45 flow while installing or retrieving equipment within the water 40 when the installing or retrieving involves physical invasion of the pipeline 20.
In another embodiment of the present invention, the vessel 10 may be utilized to drill into a formation 201 within the floor 30 of the body of water 40 using continuous casing 210. Figures 5-7 show the embodiment of the vessel 10 which is depicted in Figure 10, as the moon pool 113 is located in the bottom of the vessel 10. In the alternative, it is contemplated that the skid deck 109 arrangement of Figures 8-9 may also be utilized to communicate the continuous casing 210 into the formation 201 from the vessel 10.
Referring to Figure 5, the vessel 10 has a superstructure 215 disposed thereon, which is supported above the vessel floor 217 by legs 216. A hole 218 is disposed in the superstructure 215 above the moon pool 113 and substantially in axial line with the moon pool 113. Equipment utilized in the drilling process is lowered through the hole 218 in the superstructure 215 and the moon pool 113 at various stages of the operation.
A riser pipe 221 extends from the moon pool 113 to the ocean floor 30.
The riser pipe 221 provides a path through the body of water 40 to the floor through which the continuous casing 210 may be lowered.
The continuous casing 210 is located on the superstructure 215 on a reel 225. A drilling fluid source 226 is in fluid communication at some location with the continuous casing 210 to provide drilling fluid to the continuous casing 210 at various stages of the drilling operation. A spider 227 or other gripping apparatus having gripping members such as slips (not shown) is also disposed on the superstructure 215 around or within the hole 218 to act as a back-up gripping device during the drilling operation for the continuous casing 210.
Also located on the superstructure 215 is equipment which is utilized to lower as well as retrieve the continuous casing 210 to and from the reel 225 as desired during the drilling operation. To this end, an injector head 230 is disposed on the superstructure 215. The injector head 230 includes conveying members 232 and 233, which are substantially centered around the hole 218 and suspended above the hole 218 by supports 234 and 235. The conveying members 232 and 233 of the injector head 230 act essentially as conveyor belts and are moveable clockwise and counterclockwise around the axis of the conveying members 232 and 233 to lower or retrieve the continuous casing 210 into or out from the hole 218. Also utilized to lower and retrieve the continuous casing 210 is a conveyor belt 240 on a track 241. The conveyor belt 240 on the track 241 is located between the reel 225 and the injector head 230 to obtain the continuous casing 210 from the reel 225 and feed the continuous casing 210 into the injector head 230, or to return the continuous casing 210 to the reel 225 from the injector head 230. The injector head 230 and the conveyor belt 240 on the track 241, as described above, are known to those skilled in the art as a method of feeding continuous tubing. Other aspects of the method of feeding continuous tubing or continuous casing to drill a wellbore known to those skilled in the art are contemplated for use with the present invention.
The continuous casing 210 includes a mud motor 245 disposed therein connected by a releasable connection 246 to the inner diameter of the continuous casing 210. An expandable cutting structure 250 with perforations 260 therethrough for circulating drilling fluid and/or setting fluid is attached to the mud motor 245. The expandable cutting structure 250 includes a body (not shown) and a blade assembly (not shown) disposed on the body, as is disclosed in co-pending U.S. Patent Number 6,953,096 issued on October 11, 2005. As disclosed in the above-referenced application, the blade assembly is movable between a closed position whereby the expandable cutting structure 250 has a smaller outer diameter and an open position whereby the expandable cutting structure 250 has a larger outer diameter. The blade assembly may be moveable between the open position and the closed position through a hydraulic pressure differential created across nozzles (not shown) within the expandable cutting structure 250. The expandable cutting structure 250 may further include a release assembly for providing a secondary means to move the blade assembly from the open position to the closed position, as disclosed in the above-referenced application.
The mud motor 245 may include a shaft (not shown) and a motor operating system (not shown). The mud motor 245, which is the mechanism for rotating the cutting structure 250, is hollow to allow for fluid flow therethrough at various stages of the drilling operation and is preferably a hydraulic mud motor operated by fluids pumped therethrough. The motor operating system turns the shaft, which rotates the expandable cutting structure 250 for drilling into the formation 201. The described mud motor 245 is not the only mud motor available for use with the present invention, as other types of mud motors which are known to those skilled in the art are contemplated for use with the present invention.
In addition to the equipment for drilling with continuous casing 210 described above, the vessel 10 may include hydrocarbon fluid separation equipment (not shown) coupled to one or more storage units (not shown) to receive separated hydrocarbon fluids from the wellbore 270. With the addition of storage capacity, the vessel can collect produced hydrocarbon fluid during drilling with the continuous casing 210, thus eliminating the need for a separate vessel in the event that hydrocarbon fluid is produced during drilling.
In operation, referring to Figure 5, the vessel 10 is located above the floor 30 of the body of water 40, at or near the surface 60 of the body of water 40, so that the hole 218 in the superstructure 215 and the moon pool 113 are substantially aligned with the location at which it is desired to drill into the formation 201. The riser pipe 221 is lowered through the moon pool 113 to connect the vessel floor 217 to the floor 30 of the body of water 40 so that the continuous casing 210 and/or other tools may be lowered into the formation 201 without the interference of the body of water 40 in the drilling process. The continuous casing 210 is then pulled from the reel 225 onto the conveyor belt 240, and the conveyor belt 240 moves counterclockwise along the track 241 to feed the continuous casing 210 into the injector head 230 between the conveying members 232 and 233. The expandable cutting structure 250 is retracted at this point in the operation. The gripping members of the spider 227 are unactivated. Figure 5 illustrates this stage in the drilling operation.
Next, the continuous casing 210 is lowered through the hole 218 in the superstructure 215, through the moon pool 113, and through the riser pipe 221.
Before the continuous casing 210 reaches the floor 30, the expandable cutting structure 250 is expanded, preferably due to hydraulic pressure. The continuous casing 210 is then lowered into the formation 201 while the mud motor 245 imparts torque to the cutting structure 250, thereby drilling a wellbore 270. While the expandable cutting structure 250 is drilling into the formation 201, drilling fluid is circulated from the drilling fluid source 226 into the continuous casing 210, then into the mud motor 245, through the perforations 260 in the expandable cutting structure 250, up through an annulus 275 between the continuous casing 210 and the wellbore 270, up through an annulus 280 between the continuous casing 210 and the riser pipe 221, and up to the vessel 10 for storage or recirculation.
The fluid is circulated to carry cuttings and/or debris from the formation 201, which are produced to the surface during drilling, and to facilitate a path for the drilling of the continuous casing 210 into the formation 201. Figure 6 shows the continuous casing 210 drilling into the formation 201.
The continuous casing 210 is drilled to the desired depth within the formation 201. At this point in the operation, setting fluid is introduced into the continuous casing 210 and circulated into the annulus 275 to set the continuous casing 210 within the wellbore. The expandable cutting structure 250 is then retracted to allow it to fit through the continuous casing 210, and a cutting tool (not shown) is utilized to sever the continuous casing 210 at the floor 30. The conveyor 240 may be manipulated to move clockwise around the track 241 to return the cut-off portion of the continuous casing 210 residing above the floor 30 to the reel 225.
To retrieve the mud motor 245 and the retracted expandable cutting structure 250 from the continuous casing 210, a wireline 290 is lowered from the superstructure 215. The wireline 290 is manipulated into a slot 291 located within the mud motor 245 and then pulled upward, pushed downward, or turned (when the releasable connection 246 is a threadable connection) to release the releasable connection 246, which is preferably a shearable connection which is sheared by pulling upward or pushing downward on the wireline 290. Releasing the releasable connection 246 allows the mud motor 245 and expandable cutting structure 250 to be moveable with respect to the continuous casing 210. Figure shows the wireline 290 retrieving the expandable cutting structure 250 and the mud motor 245 from within the continuous casing 210. The wireline 290 is pulled through the moon pool 113 to the vessel 10 along with the expandable cutting structure 250 and the mud motor 245. Any other apparatus and method for retrieving the mud motor 245 and the cutting structure 250 known by those skilled in the art may be utilized with the present invention.
The drilling method of Figures 5-7 and the vessel 10 which is used to accomplish the drilling advantageously allow the wellbore 270 to be drilled into the formation 201 with one run-in of the continuous casing 210. The wellbore 270 is now ready for subsequent operations such as hydrocarbon production operations.
The same vessel 10 which was used for continuous casing 210 drilling described in Figures 5-7 may also be utilized for intervention operations described in Figures 1-4 if a pipeline 20 is used to produce fluids 45 from the wellbore 270 to the satellite storage unit 55.
The drilling method of Figures 5-7 is especially useful when employing the vessel 10 when drilling an offshore wellbore 270 in an underbalanced condition. Drilling in an underbalanced condition involves maintaining a positive pressure at the surface of the wellbore 270. Underbalanced drilling avoids damage to the wellbore 270 which can result from overbalanced drilling conditions when the drilling fluids invade the formation 201. Underbalanced drilling allows more efficient and faster hydrocarbon production from the formation 201.
Because underbalanced wells produce significant volumes of hydrocarbons, the smaller remotely operated vehicles available are insufficient to store the produced fluids.
The vessel 10 is capable of storing the volumes of fluid produced during underbalanced drilling. Furthermore, when drilling in an underbalanced state, the produced hydrocarbon fluid is a multiphase mixture of gas, solids, and liquids requiring separation. The drilling method of Figures 5-7 allows the capabilities of drilling with continuous casing 210, producing the hydrocarbons, storing the hydrocarbons with the storage equipment, and separating the produced multiphase mixture with the separating equipment using the same vessel 10. For a more detailed description of underbalanced drilling and the problems, especially problems with the resulting multiphase mixture, encountered when drilling underbalanced, refer to U.S. Patent Publication Number 2004-0007131, entitled "Closed Loop Multiphase Underbalanced Drilling Process", filed on July 10, by Chitty et a!..
While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
Claims (91)
1. A method of intervening in a pipeline, comprising:
providing a pipeline for transporting fluid flow from an offshore well to a location;
inserting a tap into the existing pipeline;
diverting the fluid flow through the tap to a storage site; and intervening in the pipeline.
providing a pipeline for transporting fluid flow from an offshore well to a location;
inserting a tap into the existing pipeline;
diverting the fluid flow through the tap to a storage site; and intervening in the pipeline.
2. The method of claim 1, wherein the well is underbalanced.
3. The method of claim 1, wherein diverting the fluid flow to the storage site comprises diverting the fluid flow to an offshore tanker.
4. The method of claim 1, wherein the tap is inserted into the pipeline between the well and the storage site.
5. The method of claim 1, wherein intervening in the pipeline comprises inserting a second tap into the pipeline downstream from the diversion of fluid flow to the storage site.
6. The method of claim 5, wherein coiled tubing is lowered from the storage site and inserted into the tap for intervening in the pipeline.
7. The method of claim 6, wherein the coiled tubing is lowered through a moon pool disposed in a vessel, wherein the vessel includes the storage site.
8. The method of claim 6, wherein the coiled tubing is lowered through a skid deck displaced to an outboard position.
9. The method of claim 1, wherein intervening in the pipeline occurs downstream with respect to initial fluid flow through the pipeline to the location from the diverting of the fluid flow to the storage site.
10. The method of claim 1, wherein intervening in the pipeline comprises removing blockage of the fluid flow within the pipeline.
11. The method of claim 10, wherein removing blockage comprises injecting acid through coiled tubing inserted in the pipeline.
12. The method of claim 10, wherein removing blockage comprises drilling into the pipeline and physically removing the blockage.
13. The method of claim 1, wherein intervening comprises removing a pig stuck in the pipeline.
14. The method of claim 1, wherein intervening comprises descaling the pipeline.
15. The method of claim 1, wherein intervening comprises removing paraffin from within the pipeline.
16. The method of claim 1, wherein intervening comprises repairing damage to the pipeline.
17. The method of claim 1, wherein the diverting and the intervening are accomplished from the same location.
18. The method of claim 17, wherein the location is an offshore tanker.
19. An apparatus for remediating an offshore pipeline and producing well fluids, comprising:
a vessel capable of storing well fluids flowing through the pipeline from a well to a location;
a first tubular body disposed on the vessel for diverting well fluid flow from the pipeline to the vessel for storing; and a second tubular body disposed on the vessel for remediating the pipeline.
a vessel capable of storing well fluids flowing through the pipeline from a well to a location;
a first tubular body disposed on the vessel for diverting well fluid flow from the pipeline to the vessel for storing; and a second tubular body disposed on the vessel for remediating the pipeline.
20. The apparatus of claim 19, wherein the first tubular body and the second tubular body are mounted on a superstructure above a main deck of the vessel.
21. The apparatus of claim 19, wherein the vessel is capable of diverting well fluid flow through the first tubular body while remediating the pipeline through the second tubular body.
22. The apparatus of claim 21, wherein the vessel is capable of remediating the pipeline without interruption of production of well fluids.
23. The apparatus of claim 19, wherein the first tubular body is a riser.
24. The apparatus of claim 19, wherein the second tubular body is coiled tubing.
25. The apparatus of claim 19, wherein the first tubular body is connected to a first tap inserted into the pipeline.
26. The apparatus of claim 25, wherein the second tubular body is connected to a second tap inserted into the pipeline.
27. The apparatus of claim 26, wherein the second tap is inserted into the pipeline downstream from the first tap inserted into the pipeline.
28. The apparatus of claim 19, wherein the vessel is capable of processing well fluids flowing through the pipeline from the well.
29. A method of intervening in a pipeline, comprising:
providing a pipeline for transporting fluid flow from an offshore well to a location;
diverting the fluid flow to a storage site, wherein diverting the fluid flow to the storage site comprises inserting a tap into the pipeline and flowing the fluid flow through the tap to the storage site; and intervening in the pipeline, wherein the diverting and the intervening are accomplished from the same location and the location is an offshore tanker.
providing a pipeline for transporting fluid flow from an offshore well to a location;
diverting the fluid flow to a storage site, wherein diverting the fluid flow to the storage site comprises inserting a tap into the pipeline and flowing the fluid flow through the tap to the storage site; and intervening in the pipeline, wherein the diverting and the intervening are accomplished from the same location and the location is an offshore tanker.
30. The method of claim 29, wherein the tap is inserted into the pipeline between the well and the storage site.
31. The method of claim 29, wherein the well is underbalanced.
32. The method of claim 29, wherein intervening in the pipeline occurs downstream with respect to initial fluid flow through the pipeline to the location from the diverting of the fluid flow to the storage site.
33. The method of claim 29, wherein intervening in the pipeline comprises removing blockage of the fluid flow within the pipeline.
34. The method of claim 33, wherein removing blockage comprises injecting acid through coiled tubing inserted in the pipeline.
35. The method of claim 33, wherein removing blockage comprises drilling into the pipeline and physically removing the blockage.
36. The method of claim 29, wherein intervening comprises removing a pig stuck in the pipeline.
37. The method of claim 29, wherein intervening comprises descaling the pipeline.
38. The method of claim 29, wherein intervening comprises removing paraffin from within the pipeline.
39. The method of claim 29, wherein intervening comprises repairing damage to the pipeline.
40. The method of claim 29, wherein intervening comprises dislodging wellbore equipment stuck in the pipeline.
41. The method of claim 29, further comprising analyzing the fluid flow to determine whether a build-up has formed on an inside of the pipeline.
42. The method of claim 41, wherein intervening comprises removing the build-up in the pipeline.
43. The method of claim 42, wherein removing build-up comprises injecting acid through a coiled tubing inserted in the pipeline.
44. The method of claim 42, wherein removing build-up comprises drilling into the pipeline and physically removing the build-up.
45. A method of intervening in a pipeline, comprising:
providing a pipeline for transporting fluid flow from an offshore well to a location;
diverting the fluid flow to a storage site; and intervening in the pipeline, wherein intervening in the pipeline comprises inserting a tap into the pipeline downstream from the diversion of fluid flow to the storage site and wherein a coiled tubing is lowered from the storage site through a moon pool disposed in a vessel and inserted into the tap for intervening in the pipeline.
providing a pipeline for transporting fluid flow from an offshore well to a location;
diverting the fluid flow to a storage site; and intervening in the pipeline, wherein intervening in the pipeline comprises inserting a tap into the pipeline downstream from the diversion of fluid flow to the storage site and wherein a coiled tubing is lowered from the storage site through a moon pool disposed in a vessel and inserted into the tap for intervening in the pipeline.
46. A method of intervening in a pipeline, comprising:
providing a pipeline for transporting fluid flow from an offshore well to a location;
diverting the fluid flow to a storage site; and intervening in the pipeline, wherein intervening in the pipeline comprises inserting a tap into the pipeline downstream from the diversion of fluid flow to the storage site and wherein a coiled tubing is lowered from the storage site through a skid deck displaced to an outboard position and inserted into the tap for intervening in the pipeline.
providing a pipeline for transporting fluid flow from an offshore well to a location;
diverting the fluid flow to a storage site; and intervening in the pipeline, wherein intervening in the pipeline comprises inserting a tap into the pipeline downstream from the diversion of fluid flow to the storage site and wherein a coiled tubing is lowered from the storage site through a skid deck displaced to an outboard position and inserted into the tap for intervening in the pipeline.
47. A method of intervening in a pipeline, comprising:
providing a pipeline for transporting fluid flow from an offshore well to a location;
diverting the fluid flow to a storage site, wherein diverting the fluid flow to the storage site comprises inserting a tap into the pipeline and flowing the fluid flow through the tap to the storage site; and intervening in the pipeline, wherein the diverting and the intervening are accomplished from the same location and the location is a floating storage tank.
providing a pipeline for transporting fluid flow from an offshore well to a location;
diverting the fluid flow to a storage site, wherein diverting the fluid flow to the storage site comprises inserting a tap into the pipeline and flowing the fluid flow through the tap to the storage site; and intervening in the pipeline, wherein the diverting and the intervening are accomplished from the same location and the location is a floating storage tank.
48. The method of claim 47, wherein the tap is inserted into the pipeline between the well and the storage site.
49. The method of claim 47, wherein intervening in the pipeline comprises lowering a coiled tubing into a tap in the pipeline.
50. The method of claim 49, wherein the coiled tubing is lowered through a moon pool positioned proximate the storage site.
51. The method of claim 49, wherein the coiled tubing is lowered through a skid deck positioned proximate the storage site.
52. A method of intervening in an existing pipeline that transports production fluid from an offshore well to a primary location, the method comprising:
inserting a first tap in the existing pipeline;
diverting the production fluid to a storage site at a secondary location via the first tap;
inserting a second tap in the existing pipeline as the production fluid is diverted to the storage site; and intervening in the existing pipeline through the second tap as the production fluid is diverted to the storage site.
inserting a first tap in the existing pipeline;
diverting the production fluid to a storage site at a secondary location via the first tap;
inserting a second tap in the existing pipeline as the production fluid is diverted to the storage site; and intervening in the existing pipeline through the second tap as the production fluid is diverted to the storage site.
53. A method of intervening in a pipeline that transports production fluid from an offshore well to a primary storage unit, the method comprising:
inserting a tap into the pipeline to establish a first communication pathway between a secondary storage unit at an offshore location and the pipeline;
diverting the production fluid through the first communication pathway to the secondary storage unit;
establishing a second communication pathway between the offshore location and the pipeline; and intervening in the pipeline through the second communication pathway as production fluid is diverted to the secondary storage unit.
inserting a tap into the pipeline to establish a first communication pathway between a secondary storage unit at an offshore location and the pipeline;
diverting the production fluid through the first communication pathway to the secondary storage unit;
establishing a second communication pathway between the offshore location and the pipeline; and intervening in the pipeline through the second communication pathway as production fluid is diverted to the secondary storage unit.
54. A method of removing a blockage in an existing pipeline that transports fluid flow from an offshore well to a location, the method comprising:
inserting a first tap at a first location along the existing pipeline;
diverting the fluid flow from the existing pipeline through the first tap to a storage site on an offshore vessel;
inserting a second tap at a second location along the existing pipeline, wherein the second location is between the first location and the blockage, and wherein inserting the second tap is accomplished after establishing a fluid communication path through the first tap to the storage site on the offshore vessel; and removing the blockage in the existing pipeline by intervening from the offshore vessel through the second tap while fluid flow is diverted through the first tap.
inserting a first tap at a first location along the existing pipeline;
diverting the fluid flow from the existing pipeline through the first tap to a storage site on an offshore vessel;
inserting a second tap at a second location along the existing pipeline, wherein the second location is between the first location and the blockage, and wherein inserting the second tap is accomplished after establishing a fluid communication path through the first tap to the storage site on the offshore vessel; and removing the blockage in the existing pipeline by intervening from the offshore vessel through the second tap while fluid flow is diverted through the first tap.
55. A method of intervening in an existing pipeline that transports wellbore fluid flow from an offshore well to a primary location, the method comprising:
forming a first tap in the existing pipeline;
diverting the wellbore fluid flow through the first tap to a storage tank at a secondary location;
forming a second tap in the existing pipeline while the wellbore fluid flow is diverted to the storage tank via the first tap; and intervening in the existing pipeline through the second tap while the wellbore fluid flow is diverted to the storage tank via the first tap.
forming a first tap in the existing pipeline;
diverting the wellbore fluid flow through the first tap to a storage tank at a secondary location;
forming a second tap in the existing pipeline while the wellbore fluid flow is diverted to the storage tank via the first tap; and intervening in the existing pipeline through the second tap while the wellbore fluid flow is diverted to the storage tank via the first tap.
56. The method of claim 55, wherein the well is underbalanced.
57. The method of claim 55, wherein intervening in the pipeline occurs downstream with respect to initial wellbore fluid flow through the pipeline to the location from the diverting of the wellbore fluid flow to the storage site.
58. The method of claim 55, wherein intervening in the pipeline comprises removing blockage within the pipeline.
59. The method of claim 58, wherein removing blockage comprises injecting acid through coiled tubing inserted in the pipeline.
60. The method of claim 58, wherein removing blockage comprises drilling in the pipeline to remove the blockage.
61. The method of claim 55, wherein intervening comprises removing a pig stuck in the pipeline.
62. The method of claim 55, wherein intervening comprises descaling the pipeline.
63. The method of claim 55, wherein intervening comprises removing paraffin from within the pipeline.
64. The method of claim 55, wherein intervening comprises repairing damage to the pipeline.
65. The method of claim 55, wherein intervening comprises dislodging wellbore equipment stuck in the pipeline.
66. The method of claim 55, further comprising analyzing the wellbore fluid flow to determine whether a build-up has formed on an inside of the pipeline.
67. The method of claim 66, wherein intervening comprises removing the build-up in the pipeline.
68. The method of claim 67, wherein removing build-up comprises injecting acid through a coiled tubing inserted in the pipeline.
69. The method of claim 67, wherein removing build-up comprises drilling in the pipeline to remove the build-up.
70. A method of intervening in a pipeline that transports fluid from an offshore well to a primary location, the method comprising:
connecting a first tubular between a floating vessel and the pipeline via a first tap;
diverting wellbore fluid through the first tubular to a secondary location comprising a storage tank on the floating vessel;
connecting a second tubular between the floating vessel and the pipeline via a second tap; and intervening in the pipeline through the second tubular while wellbore fluid is diverted to the floating vessel via the first tubular.
connecting a first tubular between a floating vessel and the pipeline via a first tap;
diverting wellbore fluid through the first tubular to a secondary location comprising a storage tank on the floating vessel;
connecting a second tubular between the floating vessel and the pipeline via a second tap; and intervening in the pipeline through the second tubular while wellbore fluid is diverted to the floating vessel via the first tubular.
71. The method of claim 70, wherein intervening comprises removing a pig stuck in the pipeline.
72. The method of claim 70, wherein intervening comprises descaling the pipeline.
73 The method of claim 70, wherein intervening comprises removing paraffin from within the pipeline.
74. The method of claim 70, wherein intervening comprises repairing damage to the pipeline.
75. The method of claim 70, wherein intervening in the pipeline comprises lowering a coiled tubing into a tap in the pipeline.
76. The method of claim 70, wherein the coiled tubing is lowered through a moon pool positioned proximate the storage site.
77. The method of claim 70, wherein the coiled tubing is lowered through a skid deck positioned proximate the storage site.
78. The method of claim 70, wherein intervening in the pipeline occurs downstream with respect to initial wellbore fluid flow through the pipeline to the location from the diverting of the wellbore fluid flow to the storage tank.
79. The method of claim 70, wherein intervening in the pipeline comprises removing blockage within the pipeline.
80. A method of intervening in a pipeline that transports fluid from an offshore well to a primary storage unit, the method comprising:
establishing a first communication pathway between a secondary storage unit at an offshore location and the pipeline via a first tap;
diverting wellbore fluid through the first communication pathway to the secondary storage unit;
establishing a second communication pathway between the offshore location and the pipeline via a second tap; and intervening in the pipeline through the second communication pathway while wellbore fluid is diverted to the secondary storage unit.
establishing a first communication pathway between a secondary storage unit at an offshore location and the pipeline via a first tap;
diverting wellbore fluid through the first communication pathway to the secondary storage unit;
establishing a second communication pathway between the offshore location and the pipeline via a second tap; and intervening in the pipeline through the second communication pathway while wellbore fluid is diverted to the secondary storage unit.
81. The method of claim 80, wherein intervening in the pipeline comprises lowering a coiled tubing through the second communication pathway.
82. The method of claim 81, wherein the coiled tubing is lowered through a moon pool on the offshore location.
83. The method of claim 81, wherein the coiled tubing is lowered through a skid deck on the offshore location.
84. The method of claim 80, wherein intervening in the pipeline occurs downstream with respect to initial wellbore fluid flow through the pipeline to the location from the diverting of the wellbore fluid flow to the offshore location.
85. The method of claim 80, wherein intervening in the pipeline comprises removing blockage of the fluid flow within the pipeline.
86. The method of claim 85, wherein removing blockage comprises injecting acid through coiled tubing inserted in the pipeline.
87. A method of removing a blockage in an existing pipeline that transports wellbore fluid flow from an offshore well to a location, the method comprising:
forming a first tap at a first location along the existing pipeline;
diverting the wellbore fluid flow from the existing pipeline through the first tap to a storage tank on an offshore vessel;
forming a second tap at a second location along the existing pipeline, wherein the second location is between the first location and the blockage, and wherein forming the second tap is accomplished after establishing a fluid communication path through the first tap to the storage tank on the offshore vessel; and removing the blockage in the existing pipeline by intervening from the offshore vessel through the second tap while wellbore fluid is diverted through the first tap.
forming a first tap at a first location along the existing pipeline;
diverting the wellbore fluid flow from the existing pipeline through the first tap to a storage tank on an offshore vessel;
forming a second tap at a second location along the existing pipeline, wherein the second location is between the first location and the blockage, and wherein forming the second tap is accomplished after establishing a fluid communication path through the first tap to the storage tank on the offshore vessel; and removing the blockage in the existing pipeline by intervening from the offshore vessel through the second tap while wellbore fluid is diverted through the first tap.
88. The method of claim 87, wherein intervening comprises lowering a coiled tubing into the second tap.
89. A method of intervening in an existing pipeline that transports wellbore fluid flow from a well to a primary storage unit, the method comprising:
positioning a floating vessel proximate the existing pipeline;
connecting a first tubular between a secondary storage unit on the floating vessel and the existing pipeline to form a diversionary flow path via a first tap;
connecting a second tubular between the floating vessel and the existing pipeline to form an intervention flow path via a second tap; and intervening in the existing pipeline through the intervention flow path while wellbore fluid flows through the diversionary flow path.
positioning a floating vessel proximate the existing pipeline;
connecting a first tubular between a secondary storage unit on the floating vessel and the existing pipeline to form a diversionary flow path via a first tap;
connecting a second tubular between the floating vessel and the existing pipeline to form an intervention flow path via a second tap; and intervening in the existing pipeline through the intervention flow path while wellbore fluid flows through the diversionary flow path.
90. The method of claim 80, wherein the offshore location is a floating vessel.
91. The method of claim 89, wherein the connecting a second tubular is accomplished while wellbore fluid flows through the diversionary flow path.
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/618,093 US7650944B1 (en) | 2003-07-11 | 2003-07-11 | Vessel for well intervention |
US10/618,093 | 2003-07-11 |
Publications (2)
Publication Number | Publication Date |
---|---|
CA2473073A1 CA2473073A1 (en) | 2005-01-11 |
CA2473073C true CA2473073C (en) | 2010-11-09 |
Family
ID=33452702
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
CA2473073A Expired - Fee Related CA2473073C (en) | 2003-07-11 | 2004-07-07 | Vessel for well intervention |
Country Status (6)
Country | Link |
---|---|
US (1) | US7650944B1 (en) |
EP (1) | EP1496297B1 (en) |
AU (1) | AU2004203054B2 (en) |
BR (1) | BRPI0402753B1 (en) |
CA (1) | CA2473073C (en) |
NO (1) | NO335948B1 (en) |
Families Citing this family (27)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
KR100678842B1 (en) | 2006-06-29 | 2007-02-06 | 대우조선해양 주식회사 | Lng regasification ship with fire-fighting device arranged in a turret and method for extinguishing a fire using the fire-fighting device |
EP3241733A1 (en) | 2008-02-15 | 2017-11-08 | Itrec B.V. | Offshore drilling vessel |
US20100059990A1 (en) * | 2008-09-05 | 2010-03-11 | Avery Fred L | Single ended clamp fitting |
US8360155B2 (en) * | 2008-09-05 | 2013-01-29 | Quality Connector Systems | Equalizer stopple fitting with integral pressure equalization fitting |
US20100059998A1 (en) * | 2008-09-05 | 2010-03-11 | Avery Fred L | Bypass fitting |
WO2010151661A2 (en) * | 2009-06-25 | 2010-12-29 | Cameron International Corporation | Sampling skid for subsea wells |
US8322431B2 (en) * | 2009-09-04 | 2012-12-04 | Halliburton Energy Services Inc. | Wellbore servicing compositions and methods of making and using same |
US20110176874A1 (en) * | 2010-01-19 | 2011-07-21 | Halliburton Energy Services, Inc. | Coiled Tubing Compensation System |
EP2633154A2 (en) * | 2010-10-28 | 2013-09-04 | Gulfstream Services, Inc. | Method and apparatus for evacuating hydrocarbons from a distressed well |
AP3645A (en) * | 2010-11-18 | 2016-03-16 | Shell Internationale Res Maatcvhappij B V | Water intake riser assembly for an off-shore structure, and method of producing a liquefied hydrocarbon stream and method of producing a vaporous hydrocarbon stream |
US8622139B2 (en) * | 2010-12-15 | 2014-01-07 | Vetco Gray Inc. | Emergency subsea wellhead closure devices |
US8950499B2 (en) * | 2011-07-26 | 2015-02-10 | Chevron U.S.A. Inc. | Pipe-in-pipe apparatus, and methods and systems |
US8783358B2 (en) * | 2011-09-16 | 2014-07-22 | Chevron U.S.A. Inc. | Methods and systems for circulating fluid within the annulus of a flexible pipe riser |
BR112014020343A2 (en) * | 2012-02-20 | 2020-10-27 | Saudi Arabian Oil Company | apparatus to contain leaks in the longitudinal portion of the pipeline pipeline |
KR101465733B1 (en) * | 2013-07-05 | 2014-11-28 | 삼성중공업 주식회사 | Apparatus and method for recovering of remaining oil in waste pipe line and method for recovering of waste pipe line |
US9540907B1 (en) | 2013-08-28 | 2017-01-10 | Jaco du Plessis | In-line fire control system for a hydrocarbon fluid stream |
RU2536525C1 (en) * | 2013-09-06 | 2014-12-27 | Николай Александрович Саврасов | System for subsea oil or gas field development |
RU2567586C2 (en) * | 2014-03-27 | 2015-11-10 | Российская Федерация, от имени которой выступает государственный заказчик (Министерство промышленности и торговли Российской Федерации) | Guide bell of drilling research ship for frilling without riser |
GB2524845B (en) * | 2014-04-05 | 2019-01-02 | Paradigm Flow Services Ltd | Apparatus and method for treating subsea fluid conduits |
WO2016057126A1 (en) * | 2014-10-10 | 2016-04-14 | Exxonmobil Upstream Research Company | Bubble pump utilization for vertical flow line liquid unloading |
GB201501432D0 (en) | 2015-01-28 | 2015-03-11 | Paradigm Flow Services Ltd | Method and apparatus for performing operations in fluid conduits |
SG11201804748PA (en) * | 2016-02-03 | 2018-08-30 | Fmc Technologies | Systems for removing blockages in subsea flowlines and equipment |
US10794126B2 (en) | 2016-08-30 | 2020-10-06 | Nabors Drilling Technologies Usa, Inc. | Dual-activity mast |
US10982508B2 (en) * | 2016-10-25 | 2021-04-20 | Stress Engineering Services, Inc. | Pipeline insulated remediation system and installation method |
CN109930999B (en) * | 2019-04-01 | 2020-06-30 | 无锡锡钻地质装备有限公司 | Geological exploration drill bit and manufacturing process thereof |
WO2021016367A1 (en) * | 2019-07-23 | 2021-01-28 | Bp Corporation North America Inc. | Systems and methods for identifying blockages in subsea conduits |
BR102019025811A2 (en) * | 2019-12-05 | 2021-06-15 | Petróleo Brasileiro S.A. - Petrobras | METHOD OF CLEARING FLEXIBLE PIPES USING FLEXITUBO FROM A WELL INTERVENTION RIG |
Family Cites Families (704)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US122514A (en) | 1872-01-09 | Improvement in rock-drills | ||
US3123160A (en) | 1964-03-03 | Retrievable subsurface well bore apparatus | ||
US3124023A (en) | 1964-03-10 | Dies for pipe and tubing tongs | ||
US3006415A (en) | 1961-10-31 | Cementing apparatus | ||
US1077772A (en) | 1913-01-25 | 1913-11-04 | Fred Richard Weathersby | Drill. |
US1185582A (en) | 1914-07-13 | 1916-05-30 | Edward Bignell | Pile. |
US1301285A (en) | 1916-09-01 | 1919-04-22 | Frank W A Finley | Expansible well-casing. |
US1342424A (en) | 1918-09-06 | 1920-06-08 | Shepard M Cotten | Method and apparatus for constructing concrete piles |
US1471526A (en) | 1920-07-19 | 1923-10-23 | Rowland O Pickin | Rotary orill bit |
US1418766A (en) | 1920-08-02 | 1922-06-06 | Guiberson Corp | Well-casing spear |
US1585069A (en) | 1924-12-18 | 1926-05-18 | William E Youle | Casing spear |
US1728136A (en) | 1926-10-21 | 1929-09-10 | Lewis E Stephens | Casing spear |
US1830625A (en) | 1927-02-16 | 1931-11-03 | George W Schrock | Drill for oil and gas wells |
US1777592A (en) | 1929-07-08 | 1930-10-07 | Thomas Idris | Casing spear |
US1998833A (en) | 1930-03-17 | 1935-04-23 | Baker Oil Tools Inc | Cementing guide |
US1825026A (en) | 1930-07-07 | 1931-09-29 | Thomas Idris | Casing spear |
US1842638A (en) | 1930-09-29 | 1932-01-26 | Wilson B Wigle | Elevating apparatus |
US1880218A (en) | 1930-10-01 | 1932-10-04 | Richard P Simmons | Method of lining oil wells and means therefor |
US1917135A (en) | 1932-02-17 | 1933-07-04 | Littell James | Well apparatus |
US2105885A (en) | 1932-03-30 | 1938-01-18 | Frank J Hinderliter | Hollow trip casing spear |
US2049450A (en) | 1933-08-23 | 1936-08-04 | Macclatchie Mfg Company | Expansible cutter tool |
US2017451A (en) | 1933-11-21 | 1935-10-15 | Baash Ross Tool Co | Packing casing bowl |
US1981525A (en) | 1933-12-05 | 1934-11-20 | Bailey E Price | Method of and apparatus for drilling oil wells |
US2060352A (en) | 1936-06-20 | 1936-11-10 | Reed Roller Bit Co | Expansible bit |
US2167338A (en) | 1937-07-26 | 1939-07-25 | U C Murcell Inc | Welding and setting well casing |
US2216895A (en) | 1939-04-06 | 1940-10-08 | Reed Roller Bit Co | Rotary underreamer |
US2228503A (en) | 1939-04-25 | 1941-01-14 | Boyd | Liner hanger |
US2214429A (en) | 1939-10-24 | 1940-09-10 | William J Miller | Mud box |
US2324679A (en) | 1940-04-26 | 1943-07-20 | Cox Nellie Louise | Rock boring and like tool |
GB540027A (en) | 1940-04-26 | 1941-10-02 | Percy Cox | Improvements in and relating to rock boring and like tools |
US2305062A (en) | 1940-05-09 | 1942-12-15 | C M P Fishing Tool Corp | Cementing plug |
US2295803A (en) | 1940-07-29 | 1942-09-15 | Charles M O'leary | Cement shoe |
US2370832A (en) | 1941-08-19 | 1945-03-06 | Baker Oil Tools Inc | Removable well packer |
US2379800A (en) | 1941-09-11 | 1945-07-03 | Texas Co | Signal transmission system |
US2414719A (en) | 1942-04-25 | 1947-01-21 | Stanolind Oil & Gas Co | Transmission system |
US2522444A (en) | 1946-07-20 | 1950-09-12 | Donovan B Grable | Well fluid control |
US2641444A (en) | 1946-09-03 | 1953-06-09 | Signal Oil & Gas Co | Method and apparatus for drilling boreholes |
US2499630A (en) | 1946-12-05 | 1950-03-07 | Paul B Clark | Casing expander |
US2668689A (en) | 1947-11-07 | 1954-02-09 | C & C Tool Corp | Automatic power tongs |
US2621742A (en) | 1948-08-26 | 1952-12-16 | Cicero C Brown | Apparatus for cementing well liners |
US2536458A (en) | 1948-11-29 | 1951-01-02 | Theodor R Munsinger | Pipe rotating device for oil wells |
US2720267A (en) | 1949-12-12 | 1955-10-11 | Cicero C Brown | Sealing assemblies for well packers |
US2610690A (en) | 1950-08-10 | 1952-09-16 | Guy M Beatty | Mud box |
US2627891A (en) | 1950-11-28 | 1953-02-10 | Paul B Clark | Well pipe expander |
US2743495A (en) | 1951-05-07 | 1956-05-01 | Nat Supply Co | Method of making a composite cutter |
GB716761A (en) | 1952-01-29 | 1954-10-13 | Standard Oil Dev Co | Improvements in or relating to drill assemblies |
GB709365A (en) | 1952-01-29 | 1954-05-19 | Standard Oil Dev Co | Improvements in or relating to drill assemblies |
US2765146A (en) | 1952-02-09 | 1956-10-02 | Jr Edward B Williams | Jetting device for rotary drilling apparatus |
US2805043A (en) | 1952-02-09 | 1957-09-03 | Jr Edward B Williams | Jetting device for rotary drilling apparatus |
US2650314A (en) | 1952-02-12 | 1953-08-25 | George W Hennigh | Special purpose electric motor |
US2764329A (en) | 1952-03-10 | 1956-09-25 | Lucian W Hampton | Load carrying attachment for bicycles, motorcycles, and the like |
US2663073A (en) | 1952-03-19 | 1953-12-22 | Acrometal Products Inc | Method of forming spools |
US2743087A (en) | 1952-10-13 | 1956-04-24 | Layne | Under-reaming tool |
US2738011A (en) | 1953-02-17 | 1956-03-13 | Thomas S Mabry | Means for cementing well liners |
US2741907A (en) | 1953-04-27 | 1956-04-17 | Genender Louis | Locksmithing tool |
US2692059A (en) | 1953-07-15 | 1954-10-19 | Standard Oil Dev Co | Device for positioning pipe in a drilling derrick |
SU112631A1 (en) | 1956-01-10 | 1957-11-30 | Г.С. Баршай | Hydraulic drive for plug-in bit opening mechanism |
GB792886A (en) | 1956-04-13 | 1958-04-02 | Fritz Huntsinger | Well pipe and flexible joints therefor |
US2978047A (en) | 1957-12-03 | 1961-04-04 | Vaan Walter H De | Collapsible drill bit assembly and method of drilling |
US3054100A (en) | 1958-06-04 | 1962-09-11 | Gen Precision Inc | Signalling system |
US3159219A (en) | 1958-05-13 | 1964-12-01 | Byron Jackson Inc | Cementing plugs and float equipment |
US3087546A (en) | 1958-08-11 | 1963-04-30 | Brown J Woolley | Methods and apparatus for removing defective casing or pipe from well bores |
GB838833A (en) | 1958-08-25 | 1960-06-22 | Archer William Kammerer | Expansible rotary drill bit |
US2953406A (en) | 1958-11-24 | 1960-09-20 | A D Timmons | Casing spear |
US3041901A (en) | 1959-05-20 | 1962-07-03 | Dowty Rotol Ltd | Make-up and break-out mechanism for drill pipe joints |
US3090031A (en) | 1959-09-29 | 1963-05-14 | Texaco Inc | Signal transmission system |
GB881358A (en) | 1960-02-12 | 1961-11-01 | Archer William Kammerer | Retrievable drilling apparatus for bore holes |
US3117636A (en) | 1960-06-08 | 1964-01-14 | John L Wilcox | Casing bit with a removable center |
US3111179A (en) | 1960-07-26 | 1963-11-19 | A And B Metal Mfg Company Inc | Jet nozzle |
BE621348A (en) | 1961-08-25 | |||
US3102599A (en) | 1961-09-18 | 1963-09-03 | Continental Oil Co | Subterranean drilling process |
US3191680A (en) | 1962-03-14 | 1965-06-29 | Pan American Petroleum Corp | Method of setting metallic liners in wells |
US3131769A (en) | 1962-04-09 | 1964-05-05 | Baker Oil Tools Inc | Hydraulic anchors for tubular strings |
US3122811A (en) | 1962-06-29 | 1964-03-03 | Lafayette E Gilreath | Hydraulic slip setting apparatus |
US3169592A (en) | 1962-10-22 | 1965-02-16 | Lamphere Jean K | Retrievable drill bit |
US3193116A (en) | 1962-11-23 | 1965-07-06 | Exxon Production Research Co | System for removing from or placing pipe in a well bore |
US3191677A (en) | 1963-04-29 | 1965-06-29 | Myron M Kinley | Method and apparatus for setting liners in tubing |
US3239004A (en) * | 1963-06-10 | 1966-03-08 | Kobe Inc | Apparatus for running equipment into and out of offshore well completions |
NL6411125A (en) | 1963-09-25 | 1965-03-26 | ||
US3353599A (en) | 1964-08-04 | 1967-11-21 | Gulf Oil Corp | Method and apparatus for stabilizing formations |
DE1216822B (en) | 1965-03-27 | 1966-05-18 | Beteiligungs & Patentverw Gmbh | Tunneling machine |
US3346045A (en) * | 1965-05-20 | 1967-10-10 | Exxon Production Research Co | Operation in a submarine well |
US3380528A (en) | 1965-09-24 | 1968-04-30 | Tri State Oil Tools Inc | Method and apparatus of removing well pipe from a well bore |
US3419079A (en) | 1965-10-23 | 1968-12-31 | Schlumberger Technology Corp | Well tool with expansible anchor |
US3392609A (en) | 1966-06-24 | 1968-07-16 | Abegg & Reinhold Co | Well pipe spinning unit |
US3390609A (en) | 1966-08-23 | 1968-07-02 | Army Usa | Firing mechanism for cannons |
US3477527A (en) | 1967-06-05 | 1969-11-11 | Global Marine Inc | Kelly and drill pipe spinner-stabber |
US3635105A (en) | 1967-10-17 | 1972-01-18 | Byron Jackson Inc | Power tong head and assembly |
US3518903A (en) | 1967-12-26 | 1970-07-07 | Byron Jackson Inc | Combined power tong and backup tong assembly |
GB1277461A (en) | 1968-06-05 | 1972-06-14 | Wadsworth Walton Mount | Method and apparatus for joining ends of pipe sections by driven force fit and joints formed thereby |
US3489220A (en) | 1968-08-02 | 1970-01-13 | J C Kinley | Method and apparatus for repairing pipe in wells |
US3548936A (en) | 1968-11-15 | 1970-12-22 | Dresser Ind | Well tools and gripping members therefor |
US3747675A (en) | 1968-11-25 | 1973-07-24 | C Brown | Rotary drive connection for casing drilling string |
US3552507A (en) | 1968-11-25 | 1971-01-05 | Cicero C Brown | System for rotary drilling of wells using casing as the drill string |
FR1604950A (en) | 1968-12-31 | 1971-05-15 | ||
US3575245A (en) | 1969-02-05 | 1971-04-20 | Servco Co | Apparatus for expanding holes |
US3552508A (en) | 1969-03-03 | 1971-01-05 | Cicero C Brown | Apparatus for rotary drilling of wells using casing as the drill pipe |
US3606664A (en) | 1969-04-04 | 1971-09-21 | Exxon Production Research Co | Leak-proof threaded connections |
US3570598A (en) | 1969-05-05 | 1971-03-16 | Glenn D Johnson | Constant strain jar |
US3550684A (en) | 1969-06-03 | 1970-12-29 | Schlumberger Technology Corp | Methods and apparatus for facilitating the descent of well tools through deviated well bores |
US3566505A (en) | 1969-06-09 | 1971-03-02 | Hydrotech Services | Apparatus for aligning two sections of pipe |
US3559739A (en) | 1969-06-20 | 1971-02-02 | Chevron Res | Method and apparatus for providing continuous foam circulation in wells |
DE1937349B2 (en) | 1969-07-23 | 1973-08-23 | Leo Gottwald KG, 4000 Dusseldorf | CRANE WITH ROTATING UPPER CARRIAGE |
US3552509A (en) | 1969-09-11 | 1971-01-05 | Cicero C Brown | Apparatus for rotary drilling of wells using casing as drill pipe |
US3603413A (en) | 1969-10-03 | 1971-09-07 | Christensen Diamond Prod Co | Retractable drill bits |
US3552510A (en) | 1969-10-08 | 1971-01-05 | Cicero C Brown | Apparatus for rotary drilling of wells using casing as the drill pipe |
US3624760A (en) | 1969-11-03 | 1971-11-30 | Albert G Bodine | Sonic apparatus for installing a pile jacket, casing member or the like in an earthen formation |
US3602302A (en) | 1969-11-10 | 1971-08-31 | Westinghouse Electric Corp | Oil production system |
BE757087A (en) | 1969-12-03 | 1971-04-06 | Gardner Denver Co | REMOTELY CONTROLLED DRILL ROD UNSCREWING MECHANISM |
US3691624A (en) | 1970-01-16 | 1972-09-19 | John C Kinley | Method of expanding a liner |
US3603411A (en) | 1970-01-19 | 1971-09-07 | Christensen Diamond Prod Co | Retractable drill bits |
US3603412A (en) | 1970-02-02 | 1971-09-07 | Baker Oil Tools Inc | Method and apparatus for drilling in casing from the top of a borehole |
US3662842A (en) | 1970-04-14 | 1972-05-16 | Automatic Drilling Mach | Automatic coupling system |
US3696332A (en) | 1970-05-25 | 1972-10-03 | Shell Oil Co | Telemetering drill string with self-cleaning connectors |
US3808916A (en) | 1970-09-24 | 1974-05-07 | Robbins & Ass J | Earth drilling machine |
US3656564A (en) | 1970-12-03 | 1972-04-18 | Cicero C Brown | Apparatus for rotary drilling of wells using casing as the drill pipe |
US3669190A (en) | 1970-12-21 | 1972-06-13 | Otis Eng Corp | Methods of completing a well |
US3692126A (en) | 1971-01-29 | 1972-09-19 | Frank C Rushing | Retractable drill bit apparatus |
US3785193A (en) | 1971-04-10 | 1974-01-15 | Kinley J | Liner expanding apparatus |
US3838613A (en) | 1971-04-16 | 1974-10-01 | Byron Jackson Inc | Motion compensation system for power tong apparatus |
US3776991A (en) | 1971-06-30 | 1973-12-04 | P Marcus | Injection blow molding method |
US3851492A (en) * | 1971-09-29 | 1974-12-03 | Seascope Services Inc | Apparatus and method for offshore operations |
US3746330A (en) | 1971-10-28 | 1973-07-17 | W Taciuk | Drill stem shock absorber |
GB1306568A (en) | 1971-11-09 | 1973-02-14 | Fox F K | Rotary drilling tool for use in well bores |
US3760894A (en) | 1971-11-10 | 1973-09-25 | M Pitifer | Replaceable blade drilling bits |
US3729057A (en) | 1971-11-30 | 1973-04-24 | Werner Ind Inc | Travelling drill bit |
US3691825A (en) | 1971-12-03 | 1972-09-19 | Norman D Dyer | Rotary torque indicator for well drilling apparatus |
US3776320A (en) | 1971-12-23 | 1973-12-04 | C Brown | Rotating drive assembly |
SU395557A1 (en) | 1971-12-30 | 1973-08-28 | Всесоюзный иаучно исследовательский институт буровой техники | DEVICE FOR DRILLING WELLS 12 |
SU415346A1 (en) | 1972-03-03 | 1974-02-15 | ||
SU481689A1 (en) | 1972-06-09 | 1975-08-25 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Dilator |
FR2209038B1 (en) | 1972-12-06 | 1977-07-22 | Petroles Cie Francaise | |
US3881375A (en) | 1972-12-12 | 1975-05-06 | Borg Warner | Pipe tong positioning system |
US4054426A (en) | 1972-12-20 | 1977-10-18 | White Gerald W | Thin film treated drilling bit cones |
SU461218A1 (en) | 1973-04-23 | 1975-02-25 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Inserted chetyrehsharoshechnoe chisel |
FR2234448B1 (en) | 1973-06-25 | 1977-12-23 | Petroles Cie Francaise | |
US3840128A (en) | 1973-07-09 | 1974-10-08 | N Swoboda | Racking arm for pipe sections, drill collars, riser pipe, and the like used in well drilling operations |
US3870114A (en) | 1973-07-23 | 1975-03-11 | Stabilator Ab | Drilling apparatus especially for ground drilling |
US3848684A (en) | 1973-08-02 | 1974-11-19 | Tri State Oil Tools Inc | Apparatus for rotary drilling |
US3857450A (en) | 1973-08-02 | 1974-12-31 | W Guier | Drilling apparatus |
SU501139A1 (en) | 1973-12-14 | 1976-01-30 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Well spreader |
US3913687A (en) | 1974-03-04 | 1975-10-21 | Ingersoll Rand Co | Pipe handling system |
US3915244A (en) | 1974-06-06 | 1975-10-28 | Cicero C Brown | Break out elevators for rotary drive assemblies |
US3934660A (en) | 1974-07-02 | 1976-01-27 | Nelson Daniel E | Flexpower deep well drill |
US3964556A (en) | 1974-07-10 | 1976-06-22 | Gearhart-Owen Industries, Inc. | Downhole signaling system |
SU585266A1 (en) | 1974-07-26 | 1977-12-25 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники Вниибт | Device for mounting the work-face motor to a drill string |
SU583278A1 (en) | 1974-08-30 | 1977-12-05 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Insertable bladed expander bit |
US4077525A (en) | 1974-11-14 | 1978-03-07 | Lamb Industries, Inc. | Derrick mounted apparatus for the manipulation of pipe |
US3947009A (en) | 1974-12-23 | 1976-03-30 | Bucyrus-Erie Company | Drill shock absorber |
US3945444A (en) | 1975-04-01 | 1976-03-23 | The Anaconda Company | Split bit casing drill |
US3980143A (en) | 1975-09-30 | 1976-09-14 | Driltech, Inc. | Holding wrench for drill strings |
SU601390A1 (en) | 1976-01-12 | 1978-04-05 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Device for building up axial force on insert tool during raising |
DE2604063A1 (en) | 1976-02-03 | 1977-08-04 | Miguel Kling | SELF-PROPELLING AND SELF-LOCKING DEVICE FOR DRIVING ON CANALS AND FORMED BY LONG DISTANCES |
SU581238A1 (en) | 1976-02-23 | 1977-11-25 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Device for catching insertion tool |
US4183555A (en) | 1976-04-02 | 1980-01-15 | Martin Charles F | Methods and joints for connecting tubular members |
US4049066A (en) | 1976-04-19 | 1977-09-20 | Richey Vernon T | Apparatus for reducing annular back pressure near the drill bit |
US4054332A (en) | 1976-05-03 | 1977-10-18 | Gardner-Denver Company | Actuation means for roller guide bushing for drill rig |
GB1516491A (en) | 1976-05-06 | 1978-07-05 | A Z Int Tool Co | Well drilling method and apparatus therefor |
US4100968A (en) | 1976-08-30 | 1978-07-18 | Charles George Delano | Technique for running casing |
US4189185A (en) | 1976-09-27 | 1980-02-19 | Tri-State Oil Tool Industries, Inc. | Method for producing chambered blast holes |
US4257442A (en) | 1976-09-27 | 1981-03-24 | Claycomb Jack R | Choke for controlling the flow of drilling mud |
US4127927A (en) | 1976-09-30 | 1978-12-05 | Hauk Ernest D | Method of gaging and joining pipe |
US4082144A (en) | 1976-11-01 | 1978-04-04 | Dresser Industries, Inc. | Method and apparatus for running and retrieving logging instruments in highly deviated well bores |
US4064939A (en) | 1976-11-01 | 1977-12-27 | Dresser Industries, Inc. | Method and apparatus for running and retrieving logging instruments in highly deviated well bores |
US4186628A (en) | 1976-11-30 | 1980-02-05 | General Electric Company | Rotary drill bit and method for making same |
US4100981A (en) | 1977-02-04 | 1978-07-18 | Chaffin John D | Earth boring apparatus for geological drilling and coring |
SU655843A1 (en) | 1977-03-22 | 1979-04-05 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Detachable joint of dovetail type |
US4142739A (en) | 1977-04-18 | 1979-03-06 | Compagnie Maritime d'Expertise, S.A. | Pipe connector apparatus having gripping and sealing means |
SE411139B (en) | 1977-04-29 | 1979-12-03 | Sandvik Ab | DRILLING DEVICE |
US4125162A (en) * | 1977-05-13 | 1978-11-14 | Otis Engineering Corporation | Well flow system and method |
US4095865A (en) | 1977-05-23 | 1978-06-20 | Shell Oil Company | Telemetering drill string with piped electrical conductor |
US4133396A (en) | 1977-11-04 | 1979-01-09 | Smith International, Inc. | Drilling and casing landing apparatus and method |
SU659260A1 (en) | 1977-12-05 | 1979-04-30 | Предприятие П/Я Р-6209 | Method of producing thick sheets from aluminium, refractory and titanium alloys |
GB1575104A (en) | 1977-12-08 | 1980-09-17 | Marconi Co Ltd | Load moving devices |
US4173457A (en) | 1978-03-23 | 1979-11-06 | Alloys, Incorporated | Hardfacing composition of nickel-bonded sintered chromium carbide particles and tools hardfaced thereof |
US4280380A (en) | 1978-06-02 | 1981-07-28 | Rockwell International Corporation | Tension control of fasteners |
US4194383A (en) | 1978-06-22 | 1980-03-25 | Gulf & Western Manufacturing Company | Modular transducer assembly for rolling mill roll adjustment mechanism |
SU781312A1 (en) | 1978-07-03 | 1980-11-23 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Blade-type expanding tool |
US4274777A (en) | 1978-08-04 | 1981-06-23 | Scaggs Orville C | Subterranean well pipe guiding apparatus |
US4175619A (en) | 1978-09-11 | 1979-11-27 | Davis Carl A | Well collar or shoe and cementing/drilling process |
US4221269A (en) | 1978-12-08 | 1980-09-09 | Hudson Ray E | Pipe spinner |
US4252465A (en) * | 1979-02-13 | 1981-02-24 | Shell Oil Company | Pipeline gel plug |
US4241878A (en) | 1979-02-26 | 1980-12-30 | 3U Partners | Nozzle and process |
US4281722A (en) | 1979-05-15 | 1981-08-04 | Long Year Company | Retractable bit system |
US4345613A (en) * | 1979-05-21 | 1982-08-24 | Internorth, Inc. | Pressure-operated portable siphon apparatus for removing concentrations of liquid from a gas pipeline |
US4274778A (en) | 1979-06-05 | 1981-06-23 | Putnam Paul S | Mechanized stand handling apparatus for drilling rigs |
DE2925400C2 (en) | 1979-06-23 | 1983-11-10 | Siegfried 7971 Aichstetten Gebhart | Device for sawing bricks, panels, wood, pipes and the like |
SU899820A1 (en) | 1979-06-29 | 1982-01-23 | Всесоюзный Ордена Трудового Красного Знамени Научно-Исследовательский Институт Буровой Техники | Device for locating the inserted instrument in drill pipe string |
US4262693A (en) | 1979-07-02 | 1981-04-21 | Bernhardt & Frederick Co., Inc. | Kelly valve |
GB2057534B (en) * | 1979-07-26 | 1983-02-16 | Mobell Blowout Services Ltd | Tool jig for oil well blow-out control |
US4287949A (en) | 1980-01-07 | 1981-09-08 | Mwl Tool And Supply Company | Setting tools and liner hanger assembly |
US4277197A (en) | 1980-01-14 | 1981-07-07 | Kearney-National, Inc. | Telescoping tool and coupling means therefor |
MX153352A (en) | 1980-03-11 | 1986-10-01 | Carlor Ramirez Jauregui | IMPROVEMENTS IN CONTRACTIL DRILL FOR DRILLING WELLS |
US4320915A (en) | 1980-03-24 | 1982-03-23 | Varco International, Inc. | Internal elevator |
US4336415A (en) | 1980-05-16 | 1982-06-22 | Walling John B | Flexible production tubing |
US4311195A (en) | 1980-07-14 | 1982-01-19 | Baker International Corporation | Hydraulically set well packer |
FR2488973B1 (en) * | 1980-08-22 | 1985-09-06 | Petroles Cie Francaise | METHOD AND DEVICE FOR INTERVENING ON AN UNDERWATER PIPE |
US4392534A (en) | 1980-08-23 | 1983-07-12 | Tsukamoto Seiki Co., Ltd. | Composite nozzle for earth boring and bore enlarging bits |
US4315553A (en) | 1980-08-25 | 1982-02-16 | Stallings Jimmie L | Continuous circulation apparatus for air drilling well bore operations |
SU955765A1 (en) | 1981-02-09 | 1995-01-20 | Всесоюзный Научно-Исследовательский Институт Буровой Техники | Inserted tree cone drill bit |
US4483399A (en) | 1981-02-12 | 1984-11-20 | Colgate Stirling A | Method of deep drilling |
US4407378A (en) | 1981-03-11 | 1983-10-04 | Smith International, Inc. | Nozzle retention method for rock bits |
US4446745A (en) | 1981-04-10 | 1984-05-08 | Baker International Corporation | Apparatus for counting turns when making threaded joints including an increased resolution turns counter |
US4396076A (en) | 1981-04-27 | 1983-08-02 | Hachiro Inoue | Under-reaming pile bore excavator |
US4437363A (en) | 1981-06-29 | 1984-03-20 | Joy Manufacturing Company | Dual camming action jaw assembly and power tong |
US4450857A (en) * | 1981-08-10 | 1984-05-29 | Hughes Tool Company | Device for tapping and plugging a fluid conductor |
US4460053A (en) | 1981-08-14 | 1984-07-17 | Christensen, Inc. | Drill tool for deep wells |
GB2108552B (en) | 1981-09-17 | 1985-01-23 | Sumitomo Metal Mining Co | Earth boring apparatus |
US4396077A (en) | 1981-09-21 | 1983-08-02 | Strata Bit Corporation | Drill bit with carbide coated cutting face |
DE3138870C1 (en) | 1981-09-30 | 1983-07-21 | Weatherford Oil Tool Gmbh, 3012 Langenhagen | Device for screwing pipes |
US4427063A (en) | 1981-11-09 | 1984-01-24 | Halliburton Company | Retrievable bridge plug |
US4445734A (en) | 1981-12-04 | 1984-05-01 | Hughes Tool Company | Telemetry drill pipe with pressure sensitive contacts |
US4441328A (en) * | 1981-12-08 | 1984-04-10 | Brister, Incorporated | Method and apparatus for forming a temporary plug in a submarine conduit |
FR2522144A1 (en) | 1982-02-24 | 1983-08-26 | Vallourec | METHOD AND DEVICE FOR ENSURING THE CORRECT VISE OF A TUBULAR JOINT HAVING A SCREW LIMITATION BIT |
FR2523635A1 (en) | 1982-03-17 | 1983-09-23 | Bretagne Atel Chantiers | DEVICE FOR MOUNTING A DRILL ROD TRAIN AND FOR TRAINING IN ROTATION AND TRANSLATION |
FR2523637A1 (en) | 1982-03-17 | 1983-09-23 | Eimco Secoma | RETRACTABLE FLOWER GUIDE FOR DRILLING AND BOLTING SLIDERS |
US4474243A (en) | 1982-03-26 | 1984-10-02 | Exxon Production Research Co. | Method and apparatus for running and cementing pipe |
DE3213464A1 (en) | 1982-04-10 | 1983-10-13 | Schaubstahl-Werke, 5910 Kreuztal | Device for cutting longitudinal slits in the circumference of manhole pipes |
US4489793A (en) | 1982-05-10 | 1984-12-25 | Roy Boren | Control method and apparatus for fluid delivery in a rotary drill string |
USRE34063E (en) | 1982-06-01 | 1992-09-15 | Monitoring torque in tubular goods | |
US4738145A (en) | 1982-06-01 | 1988-04-19 | Tubular Make-Up Specialists, Inc. | Monitoring torque in tubular goods |
US4440220A (en) | 1982-06-04 | 1984-04-03 | Mcarthur James R | System for stabbing well casing |
US4413682A (en) | 1982-06-07 | 1983-11-08 | Baker Oil Tools, Inc. | Method and apparatus for installing a cementing float shoe on the bottom of a well casing |
US4676310A (en) | 1982-07-12 | 1987-06-30 | Scherbatskoy Serge Alexander | Apparatus for transporting measuring and/or logging equipment in a borehole |
US4449596A (en) | 1982-08-03 | 1984-05-22 | Varco International, Inc. | Drilling of wells with top drive unit |
US4579484A (en) * | 1982-08-20 | 1986-04-01 | T. D. Williamson, Inc. | Underwater tapping machine |
US4466498A (en) | 1982-09-24 | 1984-08-21 | Bardwell Allen E | Detachable shoe plates for large diameter drill bits |
US4681158A (en) | 1982-10-07 | 1987-07-21 | Mobil Oil Corporation | Casing alignment tool |
US4605268A (en) | 1982-11-08 | 1986-08-12 | Nl Industries, Inc. | Transformer cable connector |
US4463814A (en) | 1982-11-26 | 1984-08-07 | Advanced Drilling Corporation | Down-hole drilling apparatus |
US4760882A (en) | 1983-02-02 | 1988-08-02 | Exxon Production Research Company | Method for primary cementing a well with a drilling mud which may be converted to cement using chemical initiators with or without additional irradiation |
US4515045A (en) | 1983-02-22 | 1985-05-07 | Spetsialnoe Konstruktorskoe Bjuro Seismicheskoi Tekhniki | Automatic wrench for screwing a pipe string together and apart |
US4604724A (en) | 1983-02-22 | 1986-08-05 | Gomelskoe Spetsialnoe Konstruktorsko-Tekhnologicheskoe Bjuro Seismicheskoi Tekhniki S Opytnym Proizvodstvom | Automated apparatus for handling elongated well elements such as pipes |
US4489794A (en) | 1983-05-02 | 1984-12-25 | Varco International, Inc. | Link tilting mechanism for well rigs |
US4630691A (en) | 1983-05-19 | 1986-12-23 | Hooper David W | Annulus bypass peripheral nozzle jet pump pressure differential drilling tool and method for well drilling |
US4494424A (en) | 1983-06-24 | 1985-01-22 | Bates Darrell R | Chain-powered pipe tong device |
SE454196C (en) | 1983-09-23 | 1991-10-24 | Jan Persson | EARTH AND MOUNTAIN DRILLING DEVICE CONCERNING BORING AND LINING OF THE DRILL |
GB8326736D0 (en) | 1983-10-06 | 1983-11-09 | Salvesen Drilling Services | Analysis of torque applied to joint |
US4683962A (en) | 1983-10-06 | 1987-08-04 | True Martin E | Spinner for use in connecting pipe joints |
US4544041A (en) | 1983-10-25 | 1985-10-01 | Rinaldi Roger E | Well casing inserting and well bore drilling method and means |
US4646827A (en) | 1983-10-26 | 1987-03-03 | Cobb William O | Tubing anchor assembly |
NO154578C (en) | 1984-01-25 | 1986-10-29 | Maritime Hydraulics As | BRIDGE DRILLING DEVICE. |
US4652195A (en) | 1984-01-26 | 1987-03-24 | Mcarthur James R | Casing stabbing and positioning apparatus |
US4921386A (en) | 1988-06-06 | 1990-05-01 | John Harrel | Device for positioning and stabbing casing from a remote selectively variable location |
US5049020A (en) | 1984-01-26 | 1991-09-17 | John Harrel | Device for positioning and stabbing casing from a remote selectively variable location |
US4529045A (en) | 1984-03-26 | 1985-07-16 | Varco International, Inc. | Top drive drilling unit with rotatable pipe support |
US4589495A (en) | 1984-04-19 | 1986-05-20 | Weatherford U.S., Inc. | Apparatus and method for inserting flow control means into a well casing |
US4651837A (en) | 1984-05-31 | 1987-03-24 | Mayfield Walter G | Downhole retrievable drill bit |
US4649777A (en) | 1984-06-21 | 1987-03-17 | David Buck | Back-up power tongs |
US4759239A (en) | 1984-06-29 | 1988-07-26 | Hughes Tool Company | Wrench assembly for a top drive sub |
US4832552A (en) | 1984-07-10 | 1989-05-23 | Michael Skelly | Method and apparatus for rotary power driven swivel drilling |
CA1239634A (en) | 1984-07-27 | 1988-07-26 | William D. Stringfellow | Weight compensating elevator |
US4604818A (en) | 1984-08-06 | 1986-08-12 | Kabushiki Kaisha Tokyo Seisakusho | Under reaming pile bore excavating bucket and method of its excavation |
FR2568935B1 (en) | 1984-08-08 | 1986-09-05 | Petroles Cie Francaise | DRILL PIPE CONNECTION, PARTICULARLY FOR CROSSING A LOSS OF TRAFFIC AREA |
US4595058A (en) | 1984-08-28 | 1986-06-17 | Shell Oil Company | Turbulence cementing sub |
SU1304470A1 (en) | 1984-08-31 | 1995-01-20 | Всесоюзный Научно-Исследовательский Институт Буровой Техники | Method for core drilling |
HU195559B (en) | 1984-09-04 | 1988-05-30 | Janos Fenyvesi | Drilling rig of continuous operation |
US4605077A (en) | 1984-12-04 | 1986-08-12 | Varco International, Inc. | Top drive drilling systems |
GB2170528A (en) | 1985-01-26 | 1986-08-06 | Ed Oscar Seabourn | Casing extender |
US4580631A (en) | 1985-02-13 | 1986-04-08 | Joe R. Brown | Liner hanger with lost motion coupling |
US4655286A (en) | 1985-02-19 | 1987-04-07 | Ctc Corporation | Method for cementing casing or liners in an oil well |
US4616706A (en) * | 1985-02-21 | 1986-10-14 | Exxon Production Research Co. | Apparatus for performing subsea through-the-flowline operations |
US4825947A (en) | 1985-02-22 | 1989-05-02 | Mikolajczyk Raymond F | Apparatus for use in cementing a casing string within a well bore |
US4625796A (en) | 1985-04-01 | 1986-12-02 | Varco International, Inc. | Well pipe stabbing and back-up apparatus |
US4667752A (en) | 1985-04-11 | 1987-05-26 | Hughes Tool Company | Top head drive well drilling apparatus with stabbing guide |
US4709766A (en) | 1985-04-26 | 1987-12-01 | Varco International, Inc. | Well pipe handling machine |
SE461345B (en) | 1985-06-03 | 1990-02-05 | Sandvik Rock Tools Ab | SETTING AND DEVICE CAREFULLY DOWNLOAD FEEDING ROOMS BY ORIGINAL MARK AND ORIGINAL CONSTRUCTIONS |
DE3523221A1 (en) | 1985-06-28 | 1987-01-02 | Svetozar Dipl Ing Marojevic | Method of screwing pipes |
US4686873A (en) | 1985-08-12 | 1987-08-18 | Becor Western Inc. | Casing tong assembly |
FR2588297B1 (en) | 1985-10-09 | 1987-12-04 | Soletanche | DEVICE FOR UNDERWATER DRILLING OF FOUNDATIONS |
US4693316A (en) | 1985-11-20 | 1987-09-15 | Halliburton Company | Round mandrel slip joint |
US4671358A (en) | 1985-12-18 | 1987-06-09 | Mwl Tool Company | Wiper plug cementing system and method of use thereof |
US4691587A (en) | 1985-12-20 | 1987-09-08 | General Motors Corporation | Steering column with selectively adjustable and preset preferred positions |
US4709599A (en) | 1985-12-26 | 1987-12-01 | Buck David A | Compensating jaw assembly for power tongs |
FR2600172B1 (en) | 1986-01-17 | 1988-08-26 | Inst Francais Du Petrole | DEVICE FOR INSTALLING SEISMIC SENSORS IN A PETROLEUM PRODUCTION WELL |
US4678031A (en) | 1986-01-27 | 1987-07-07 | Blandford David M | Rotatable reciprocating collar for borehole casing |
US4681162A (en) | 1986-02-19 | 1987-07-21 | Boyd's Bit Service, Inc. | Borehole drill pipe continuous side entry or exit apparatus and method |
SE460141B (en) | 1986-02-24 | 1989-09-11 | Santrade Ltd | DRILLING TOOL FOR ROTATION AND / OR SHIPPING DRILLING INCLUDING AN Eccentric Rifle AND RIDER INCLUDED IN SUCH A DRILLING TOOL |
FR2596803B1 (en) | 1986-04-02 | 1988-06-24 | Elf Aquitaine | SIMULTANEOUS DRILLING AND TUBING DEVICE |
US4699224A (en) | 1986-05-12 | 1987-10-13 | Sidewinder Joint Venture | Method and apparatus for lateral drilling in oil and gas wells |
DE3617227A1 (en) | 1986-05-22 | 1987-11-26 | Wirth Co Kg Masch Bohr | DEVICE WITH AN END OF A TUBE CLAMPABLE SPIDER OR THE LIKE. |
US4744426A (en) | 1986-06-02 | 1988-05-17 | Reed John A | Apparatus for reducing hydro-static pressure at the drill bit |
GB8616006D0 (en) | 1986-07-01 | 1986-08-06 | Framo Dev Ltd | Drilling system |
US4765401A (en) | 1986-08-21 | 1988-08-23 | Varco International, Inc. | Apparatus for handling well pipe |
FR2605657A1 (en) | 1986-10-22 | 1988-04-29 | Soletanche | METHOD FOR PRODUCING A PIEU IN SOIL, DRILLING MACHINE AND DEVICE FOR IMPLEMENTING SAID METHOD |
US4725179A (en) | 1986-11-03 | 1988-02-16 | Lee C. Moore Corporation | Automated pipe racking apparatus |
US5717334A (en) | 1986-11-04 | 1998-02-10 | Paramagnetic Logging, Inc. | Methods and apparatus to produce stick-slip motion of logging tool attached to a wireline drawn upward by a continuously rotating wireline drum |
US4676312A (en) | 1986-12-04 | 1987-06-30 | Donald E. Mosing | Well casing grip assurance system |
US4788544A (en) | 1987-01-08 | 1988-11-29 | Hughes Tool Company - Usa | Well bore data transmission system |
US4778008A (en) | 1987-03-05 | 1988-10-18 | Exxon Production Research Company | Selectively releasable and reengagable expansion joint for subterranean well tubing strings |
US4843945A (en) | 1987-03-09 | 1989-07-04 | National-Oilwell | Apparatus for making and breaking threaded well pipe connections |
NO881445L (en) | 1987-04-02 | 1988-10-03 | Apache Corp | APPLICATION FOR APPLICATION OF TORQUE TO A RUBBER PART IN AN EARTH DRILL. |
US4821814A (en) | 1987-04-02 | 1989-04-18 | 501 W-N Apache Corporation | Top head drive assembly for earth drilling machine and components thereof |
US4762187A (en) | 1987-07-29 | 1988-08-09 | W-N Apache Corporation | Internal wrench for a top head drive assembly |
US4836064A (en) | 1987-04-10 | 1989-06-06 | Slator Damon T | Jaws for power tongs and back-up units |
US4813493A (en) | 1987-04-14 | 1989-03-21 | Triten Corporation | Hydraulic top drive for wells |
US4813495A (en) | 1987-05-05 | 1989-03-21 | Conoco Inc. | Method and apparatus for deepwater drilling |
US4901069A (en) | 1987-07-16 | 1990-02-13 | Schlumberger Technology Corporation | Apparatus for electromagnetically coupling power and data signals between a first unit and a second unit and in particular between well bore apparatus and the surface |
US4806928A (en) | 1987-07-16 | 1989-02-21 | Schlumberger Technology Corporation | Apparatus for electromagnetically coupling power and data signals between well bore apparatus and the surface |
US4800968A (en) | 1987-09-22 | 1989-01-31 | Triten Corporation | Well apparatus with tubular elevator tilt and indexing apparatus and methods of their use |
US4781359A (en) | 1987-09-23 | 1988-11-01 | National-Oilwell | Sub assembly for a swivel |
CA1302391C (en) | 1987-10-09 | 1992-06-02 | Keith M. Haney | Compact casing tongs for use on top head drive earth drilling machine |
US4836299A (en) | 1987-10-19 | 1989-06-06 | Bodine Albert G | Sonic method and apparatus for installing monitor wells for the surveillance and control of earth contamination |
US4883125A (en) | 1987-12-11 | 1989-11-28 | Atlantic Richfield Company | Cementing oil and gas wells using converted drilling fluid |
CA1270479A (en) | 1987-12-14 | 1990-06-19 | Jerome Labrosse | Tubing bit opener |
US4791997A (en) | 1988-01-07 | 1988-12-20 | Vetco Gray Inc. | Pipe handling apparatus and method |
US4878546A (en) | 1988-02-12 | 1989-11-07 | Triten Corporation | Self-aligning top drive |
US4793422A (en) | 1988-03-16 | 1988-12-27 | Hughes Tool Company - Usa | Articulated elevator links for top drive drill rig |
GB2216926B (en) | 1988-04-06 | 1992-08-12 | Jumblefierce Limited | Drilling method and apparatus |
SU1618870A1 (en) | 1988-04-19 | 1991-01-07 | Украинский научно-исследовательский институт природных газов | Method of cementing wells |
US4880058A (en) | 1988-05-16 | 1989-11-14 | Lindsey Completion Systems, Inc. | Stage cementing valve |
SE8802142L (en) | 1988-06-08 | 1989-12-09 | Diamant Boart Craelius Ab | DEVICE FOR THE MAINTENANCE OF A TOOL INSIDE A PIPE IN THE MARKET |
US4848469A (en) | 1988-06-15 | 1989-07-18 | Baker Hughes Incorporated | Liner setting tool and method |
NO169399C (en) | 1988-06-27 | 1992-06-17 | Noco As | DEVICE FOR DRILLING HOLES IN GROUND GROUPS |
US4854386A (en) | 1988-08-01 | 1989-08-08 | Texas Iron Works, Inc. | Method and apparatus for stage cementing a liner in a well bore having a casing |
US4962579A (en) | 1988-09-02 | 1990-10-16 | Exxon Production Research Company | Torque position make-up of tubular connections |
US4854383A (en) | 1988-09-27 | 1989-08-08 | Texas Iron Works, Inc. | Manifold arrangement for use with a top drive power unit |
GB2224481A (en) | 1988-11-04 | 1990-05-09 | Heerema Engineering | Improvements in internal elevators |
US4899816A (en) | 1989-01-24 | 1990-02-13 | Paul Mine | Apparatus for guiding wireline |
GB8901918D0 (en) | 1989-01-28 | 1989-03-15 | Franks Casing Crews Uk Limited | Control system |
US4962819A (en) | 1989-02-01 | 1990-10-16 | Drilex Systems, Inc. | Mud saver valve with replaceable inner sleeve |
US5044388A (en) * | 1989-02-13 | 1991-09-03 | Dresser Industries, Inc. | Perforating gun pressure bleed device |
US5009265A (en) | 1989-09-07 | 1991-04-23 | Drilex Systems, Inc. | Packer for wellhead repair unit |
US5036927A (en) | 1989-03-10 | 1991-08-06 | W-N Apache Corporation | Apparatus for gripping a down hole tubular for rotation |
US4936382A (en) | 1989-03-31 | 1990-06-26 | Seaboard-Arval Corporation | Drive pipe adaptor |
US4909741A (en) | 1989-04-10 | 1990-03-20 | Atlantic Richfield Company | Wellbore tool swivel connector |
US5456317A (en) | 1989-08-31 | 1995-10-10 | Union Oil Co | Buoyancy assisted running of perforated tubulars |
IE903114A1 (en) | 1989-08-31 | 1991-03-13 | Union Oil Co | Well casing flotation device and method |
US4960173A (en) | 1989-10-26 | 1990-10-02 | Baker Hughes Incorporated | Releasable well tool stabilizer |
BR8905595A (en) | 1989-11-01 | 1991-05-07 | Petroleo Brasileiro Sa | INTERVENTION SYSTEM EXPANSION AND REPAIR OF SUBMARINE LINES OPERATOR BY REMOTE OPERATION VEHICLE |
US5022472A (en) | 1989-11-14 | 1991-06-11 | Masx Energy Services Group, Inc. | Hydraulic clamp for rotary drilling head |
US5096465A (en) | 1989-12-13 | 1992-03-17 | Norton Company | Diamond metal composite cutter and method for making same |
US4962822A (en) | 1989-12-15 | 1990-10-16 | Numa Tool Company | Downhole drill bit and bit coupling |
DE3942438A1 (en) | 1989-12-22 | 1991-07-11 | Eastman Christensen Co | DEVICE FOR DRILLING A SUB-DRILLING OR DEFLECTING DRILL OF A PARTICULARLY PIPED HOLE |
US4997042A (en) | 1990-01-03 | 1991-03-05 | Jordan Ronald A | Casing circulator and method |
US5191939A (en) | 1990-01-03 | 1993-03-09 | Tam International | Casing circulator and method |
US5069297A (en) | 1990-01-24 | 1991-12-03 | Rudolph E. Krueger, Inc. | Drill pipe/casing protector and method |
US5251709A (en) | 1990-02-06 | 1993-10-12 | Richardson Allan S | Drilling rig |
US5082069A (en) | 1990-03-01 | 1992-01-21 | Atlantic Richfield Company | Combination drivepipe/casing and installation method for offshore well |
US5176518A (en) | 1990-03-14 | 1993-01-05 | Fokker Aircraft B.V. | Movement simulator |
US5908049A (en) | 1990-03-15 | 1999-06-01 | Fiber Spar And Tube Corporation | Spoolable composite tubular member with energy conductors |
US5172765A (en) | 1990-03-15 | 1992-12-22 | Conoco Inc. | Method using spoolable composite tubular member with energy conductors |
US5097870A (en) | 1990-03-15 | 1992-03-24 | Conoco Inc. | Composite tubular member with multiple cells |
BR9106334A (en) | 1990-04-12 | 1993-04-20 | H T C A S Companhia Dinamarque | DRILLING HOLE, FORMATION PROCESS AND APPLIANCE FOR CARRYING OUT THE PROCESS |
US5224540A (en) | 1990-04-26 | 1993-07-06 | Halliburton Company | Downhole tool apparatus with non-metallic components and methods of drilling thereof |
US5271468A (en) | 1990-04-26 | 1993-12-21 | Halliburton Company | Downhole tool apparatus with non-metallic components and methods of drilling thereof |
US5062756A (en) | 1990-05-01 | 1991-11-05 | John Harrel | Device for positioning and stabbing casing from a remote selectively variable location |
US5027914A (en) | 1990-06-04 | 1991-07-02 | Wilson Steve B | Pilot casing mill |
US5074366A (en) | 1990-06-21 | 1991-12-24 | Baker Hughes Incorporated | Method and apparatus for horizontal drilling |
US5148875A (en) | 1990-06-21 | 1992-09-22 | Baker Hughes Incorporated | Method and apparatus for horizontal drilling |
US5141063A (en) | 1990-08-08 | 1992-08-25 | Quesenbury Jimmy B | Restriction enhancement drill |
GB9019416D0 (en) | 1990-09-06 | 1990-10-24 | Frank S Int Ltd | Device for applying torque to a tubular member |
US5083356A (en) | 1990-10-04 | 1992-01-28 | Exxon Production Research Company | Collar load support tubing running procedure |
US5085273A (en) | 1990-10-05 | 1992-02-04 | Davis-Lynch, Inc. | Casing lined oil or gas well |
BR9005125A (en) * | 1990-10-12 | 1992-06-30 | Petroleo Brasileiro Sa | PROCESS FOR LAUNCHING SCRAPERS, PARTICULARLY FOR SUBMARINE PETROLEUM POWDER LINES |
US5060542A (en) | 1990-10-12 | 1991-10-29 | Hawk Industries, Inc. | Apparatus and method for making and breaking joints in drill pipe strings |
FR2668198B1 (en) | 1990-10-19 | 1997-01-10 | Elf Aquitaine | MOTORIZED INJECTION HEAD WITH A DYNAMOMETRIC MEASUREMENT ASSEMBLY. |
US5052483A (en) | 1990-11-05 | 1991-10-01 | Bestline Liner Systems | Sand control adapter |
US5152554A (en) | 1990-12-18 | 1992-10-06 | Lafleur Petroleum Services, Inc. | Coupling apparatus |
US5160925C1 (en) | 1991-04-17 | 2001-03-06 | Halliburton Co | Short hop communication link for downhole mwd system |
US5156213A (en) | 1991-05-03 | 1992-10-20 | Halliburton Company | Well completion method and apparatus |
US5191932A (en) | 1991-07-09 | 1993-03-09 | Douglas Seefried | Oilfield cementing tool and method |
FR2679957B1 (en) | 1991-08-02 | 1998-12-04 | Inst Francais Du Petrole | METHOD AND DEVICE FOR PERFORMING MEASUREMENTS AND / OR INTERVENTIONS IN A WELL BORE OR DURING DRILLING. |
FR2679958B1 (en) | 1991-08-02 | 1997-06-27 | Inst Francais Du Petrole | SYSTEM, SUPPORT FOR PERFORMING MEASUREMENTS OR INTERVENTIONS IN A WELLBORE OR DURING DRILLING, AND USES THEREOF. |
US5197553A (en) | 1991-08-14 | 1993-03-30 | Atlantic Richfield Company | Drilling with casing and retrievable drill bit |
US5271472A (en) | 1991-08-14 | 1993-12-21 | Atlantic Richfield Company | Drilling with casing and retrievable drill bit |
US5186265A (en) | 1991-08-22 | 1993-02-16 | Atlantic Richfield Company | Retrievable bit and eccentric reamer assembly |
US5294228A (en) | 1991-08-28 | 1994-03-15 | W-N Apache Corporation | Automatic sequencing system for earth drilling machine |
DE4129709C1 (en) | 1991-09-06 | 1992-12-03 | Bergwerksverband Gmbh | |
NO173750C (en) | 1991-09-30 | 1994-01-26 | Wepco As | Circulating Equipment |
DE4133802C1 (en) | 1991-10-12 | 1992-10-22 | Manfred 5210 Troisdorf De Hawerkamp | Thermoplastics thrust pipe - has respective plug and socket ends with opposed angle cone design so it can mate with next section |
US5199496A (en) * | 1991-10-18 | 1993-04-06 | Texaco, Inc. | Subsea pumping device incorporating a wellhead aspirator |
US5168942A (en) | 1991-10-21 | 1992-12-08 | Atlantic Richfield Company | Resistivity measurement system for drilling with casing |
US5255751A (en) | 1991-11-07 | 1993-10-26 | Huey Stogner | Oilfield make-up and breakout tool for top drive drilling systems |
US5351767A (en) | 1991-11-07 | 1994-10-04 | Globral Marine Inc. | Drill pipe handling |
US5183364A (en) * | 1991-11-26 | 1993-02-02 | Hardwig Ronald B | Device for installing an in-line valve |
US5255741A (en) | 1991-12-11 | 1993-10-26 | Mobil Oil Corporation | Process and apparatus for completing a well in an unconsolidated formation |
US5238074A (en) | 1992-01-06 | 1993-08-24 | Baker Hughes Incorporated | Mosaic diamond drag bit cutter having a nonuniform wear pattern |
US5291956A (en) | 1992-04-15 | 1994-03-08 | Union Oil Company Of California | Coiled tubing drilling apparatus and method |
US5234052A (en) | 1992-05-01 | 1993-08-10 | Davis-Lynch, Inc. | Cementing apparatus |
US5311952A (en) | 1992-05-22 | 1994-05-17 | Schlumberger Technology Corporation | Apparatus and method for directional drilling with downhole motor on coiled tubing |
MY108743A (en) | 1992-06-09 | 1996-11-30 | Shell Int Research | Method of greating a wellbore in an underground formation |
FR2692315B1 (en) | 1992-06-12 | 1994-09-02 | Inst Francais Du Petrole | System and method for drilling and equipping a lateral well, application to the exploitation of oil fields. |
US5233742A (en) | 1992-06-29 | 1993-08-10 | Gray N Monroe | Method and apparatus for controlling tubular connection make-up |
US5285204A (en) | 1992-07-23 | 1994-02-08 | Conoco Inc. | Coil tubing string and downhole generator |
US5318122A (en) | 1992-08-07 | 1994-06-07 | Baker Hughes, Inc. | Method and apparatus for sealing the juncture between a vertical well and one or more horizontal wells using deformable sealing means |
US5322127C1 (en) | 1992-08-07 | 2001-02-06 | Baker Hughes Inc | Method and apparatus for sealing the juncture between a vertical well and one or more horizontal wells |
US5524180A (en) | 1992-08-10 | 1996-06-04 | Computer Motion, Inc. | Automated endoscope system for optimal positioning |
US5340182A (en) | 1992-09-04 | 1994-08-23 | Varco International, Inc. | Safety elevator |
DE59209119D1 (en) | 1992-10-21 | 1998-02-12 | Weatherford Lamb | Load positioning device |
US5343951A (en) | 1992-10-22 | 1994-09-06 | Shell Oil Company | Drilling and cementing slim hole wells |
US5343950A (en) | 1992-10-22 | 1994-09-06 | Shell Oil Company | Drilling and cementing extended reach boreholes |
US5332048A (en) | 1992-10-23 | 1994-07-26 | Halliburton Company | Method and apparatus for automatic closed loop drilling system |
US5355967A (en) | 1992-10-30 | 1994-10-18 | Union Oil Company Of California | Underbalance jet pump drilling method |
US5297833A (en) | 1992-11-12 | 1994-03-29 | W-N Apache Corporation | Apparatus for gripping a down hole tubular for support and rotation |
US5323858A (en) | 1992-11-18 | 1994-06-28 | Atlantic Richfield Company | Case cementing method and system |
US5320178A (en) | 1992-12-08 | 1994-06-14 | Atlantic Richfield Company | Sand control screen and installation method for wells |
DE4244587A1 (en) | 1992-12-28 | 1994-07-07 | Mannesmann Ag | Pipe string with threaded pipes and a sleeve connecting them |
US5305839A (en) | 1993-01-19 | 1994-04-26 | Masx Energy Services Group, Inc. | Turbine pump ring for drilling heads |
US5284210A (en) | 1993-02-04 | 1994-02-08 | Helms Charles M | Top entry sub arrangement |
US5354150A (en) | 1993-02-08 | 1994-10-11 | Canales Joe M | Technique for making up threaded pipe joints into a pipeline |
US5361859A (en) | 1993-02-12 | 1994-11-08 | Baker Hughes Incorporated | Expandable gage bit for drilling and method of drilling |
US5560440A (en) | 1993-02-12 | 1996-10-01 | Baker Hughes Incorporated | Bit for subterranean drilling fabricated from separately-formed major components |
IT1272119B (en) * | 1993-03-22 | 1997-06-11 | Snam Progetti | PROCEDURE PERFECTED FOR THE AUTOMATIC REPAIR OF UNDERWATER PIPES PARTICULARLY SUITABLE FOR HIGH BOTTOMS AND RELATED EQUIPMENT. |
GB2276886B (en) | 1993-03-19 | 1997-04-23 | Smith International | Rock bits with hard facing |
US5388651A (en) | 1993-04-20 | 1995-02-14 | Bowen Tools, Inc. | Top drive unit torque break-out system |
US5379835A (en) | 1993-04-26 | 1995-01-10 | Halliburton Company | Casing cementing equipment |
US5386746A (en) | 1993-05-26 | 1995-02-07 | Hawk Industries, Inc. | Apparatus for making and breaking joints in drill pipe strings |
RU2109907C1 (en) | 1993-06-16 | 1998-04-27 | Даун Хоул Текнолоджиз Пти.Лтд. | Drilling member |
US5332043A (en) | 1993-07-20 | 1994-07-26 | Abb Vetco Gray Inc. | Wellhead connector |
US5433279A (en) | 1993-07-20 | 1995-07-18 | Tessari; Robert M. | Portable top drive assembly |
US5826651A (en) | 1993-09-10 | 1998-10-27 | Weatherford/Lamb, Inc. | Wellbore single trip milling |
US5887655A (en) | 1993-09-10 | 1999-03-30 | Weatherford/Lamb, Inc | Wellbore milling and drilling |
US5887668A (en) | 1993-09-10 | 1999-03-30 | Weatherford/Lamb, Inc. | Wellbore milling-- drilling |
US5787978A (en) | 1995-03-31 | 1998-08-04 | Weatherford/Lamb, Inc. | Multi-face whipstock with sacrificial face element |
DE4334378C2 (en) | 1993-10-08 | 1999-01-14 | Weatherford Oil Tool | Device for aligning hanging loads |
US5392715A (en) | 1993-10-12 | 1995-02-28 | Osaka Gas Company, Ltd. | In-pipe running robot and method of running the robot |
US5542472A (en) | 1993-10-25 | 1996-08-06 | Camco International, Inc. | Metal coiled tubing with signal transmitting passageway |
JPH07158124A (en) | 1993-12-02 | 1995-06-20 | Nagaoka:Kk | Screen for well having uniform outside diameter |
US5402856A (en) | 1993-12-21 | 1995-04-04 | Amoco Corporation | Anti-whirl underreamer |
US5588916A (en) | 1994-02-17 | 1996-12-31 | Duramax, Inc. | Torque control device for rotary mine drilling machine |
US5836395A (en) | 1994-08-01 | 1998-11-17 | Weatherford/Lamb, Inc. | Valve for wellbore use |
US5472057A (en) | 1994-04-11 | 1995-12-05 | Atlantic Richfield Company | Drilling with casing and retrievable bit-motor assembly |
US5461905A (en) | 1994-04-19 | 1995-10-31 | Bilco Tools, Inc. | Method and apparatus for testing oilfield tubular threaded connections |
US5435400B1 (en) | 1994-05-25 | 1999-06-01 | Atlantic Richfield Co | Lateral well drilling |
ES2180634T3 (en) | 1994-05-28 | 2003-02-16 | Kenneth Mackintosh | WELL ACCESS TOOL. |
GB9411228D0 (en) | 1994-06-04 | 1994-07-27 | Camco Drilling Group Ltd | A modulated bias unit for rotary drilling |
IT1266026B1 (en) | 1994-06-14 | 1996-12-16 | Soilmec Spa | DEVICE FOR THE LOADING AND SCREWING OF RODS AND LINING PIPES COMPONENTS OF A DRILLING BATTERY |
US5452923A (en) | 1994-06-28 | 1995-09-26 | Canadian Fracmaster Ltd. | Coiled tubing connector |
GB9413141D0 (en) | 1994-06-30 | 1994-08-24 | Exploration And Production Nor | Downhole data transmission |
US5577566A (en) | 1995-08-09 | 1996-11-26 | Weatherford U.S., Inc. | Releasing tool |
US6547017B1 (en) | 1994-09-07 | 2003-04-15 | Smart Drilling And Completion, Inc. | Rotary drill bit compensating for changes in hardness of geological formations |
US5615747A (en) | 1994-09-07 | 1997-04-01 | Vail, Iii; William B. | Monolithic self sharpening rotary drill bit having tungsten carbide rods cast in steel alloys |
US5526880A (en) | 1994-09-15 | 1996-06-18 | Baker Hughes Incorporated | Method for multi-lateral completion and cementing the juncture with lateral wellbores |
RU2079633C1 (en) | 1994-09-22 | 1997-05-20 | Товарищество с ограниченной ответственностью "ЛОКС" | Method of drilling of additional wellbore from production string |
US5547029A (en) | 1994-09-27 | 1996-08-20 | Rubbo; Richard P. | Surface controlled reservoir analysis and management system |
US5503234A (en) | 1994-09-30 | 1996-04-02 | Clanton; Duane | 2×4 drilling and hoisting system |
US5501286A (en) | 1994-09-30 | 1996-03-26 | Bowen Tools, Inc. | Method and apparatus for displacing a top drive torque track |
US5494122A (en) | 1994-10-04 | 1996-02-27 | Smith International, Inc. | Composite nozzles for rock bits |
US5553672A (en) | 1994-10-07 | 1996-09-10 | Baker Hughes Incorporated | Setting tool for a downhole tool |
US5894897A (en) | 1994-10-14 | 1999-04-20 | Vail Iii William Banning | Method and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
US6868906B1 (en) | 1994-10-14 | 2005-03-22 | Weatherford/Lamb, Inc. | Closed-loop conveyance systems for well servicing |
US6857486B2 (en) | 2001-08-19 | 2005-02-22 | Smart Drilling And Completion, Inc. | High power umbilicals for subterranean electric drilling machines and remotely operated vehicles |
US7100710B2 (en) | 1994-10-14 | 2006-09-05 | Weatherford/Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
US7108084B2 (en) | 1994-10-14 | 2006-09-19 | Weatherford/Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
US7013997B2 (en) | 1994-10-14 | 2006-03-21 | Weatherford/Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
US7040420B2 (en) | 1994-10-14 | 2006-05-09 | Weatherford/Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
US7147068B2 (en) | 1994-10-14 | 2006-12-12 | Weatherford / Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
US6397946B1 (en) | 1994-10-14 | 2002-06-04 | Smart Drilling And Completion, Inc. | Closed-loop system to compete oil and gas wells closed-loop system to complete oil and gas wells c |
US6158531A (en) | 1994-10-14 | 2000-12-12 | Smart Drilling And Completion, Inc. | One pass drilling and completion of wellbores with drill bit attached to drill string to make cased wellbores to produce hydrocarbons |
US5551521A (en) | 1994-10-14 | 1996-09-03 | Vail, Iii; William B. | Method and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
US6263987B1 (en) | 1994-10-14 | 2001-07-24 | Smart Drilling And Completion, Inc. | One pass drilling and completion of extended reach lateral wellbores with drill bit attached to drill string to produce hydrocarbons from offshore platforms |
US5566769A (en) | 1994-10-31 | 1996-10-22 | Eckel Manufacturing Company, Inc. | Tubular rotation tool for snubbing operations |
US5497840A (en) | 1994-11-15 | 1996-03-12 | Bestline Liner Systems | Process for completing a well |
US5667023B1 (en) | 1994-11-22 | 2000-04-18 | Baker Hughes Inc | Method and apparatus for drilling and completing wells |
EP0713953B1 (en) | 1994-11-22 | 2002-10-02 | Baker Hughes Incorporated | Method of drilling and completing wells |
US5477925A (en) | 1994-12-06 | 1995-12-26 | Baker Hughes Incorporated | Method for multi-lateral completion and cementing the juncture with lateral wellbores |
US5842149A (en) | 1996-10-22 | 1998-11-24 | Baker Hughes Incorporated | Closed loop drilling system |
MY121223A (en) | 1995-01-16 | 2006-01-28 | Shell Int Research | Method of creating a casing in a borehole |
US5732776A (en) | 1995-02-09 | 1998-03-31 | Baker Hughes Incorporated | Downhole production well control system and method |
US5829520A (en) | 1995-02-14 | 1998-11-03 | Baker Hughes Incorporated | Method and apparatus for testing, completion and/or maintaining wellbores using a sensor device |
GB9503830D0 (en) | 1995-02-25 | 1995-04-19 | Camco Drilling Group Ltd | "Improvements in or relating to steerable rotary drilling systems" |
GB9504968D0 (en) | 1995-03-11 | 1995-04-26 | Brit Bit Limited | Improved casing shoe |
US5651420A (en) | 1995-03-17 | 1997-07-29 | Baker Hughes, Inc. | Drilling apparatus with dynamic cuttings removal and cleaning |
US5566772A (en) | 1995-03-24 | 1996-10-22 | Davis-Lynch, Inc. | Telescoping casing joint for landing a casting string in a well bore |
US5735351A (en) | 1995-03-27 | 1998-04-07 | Helms; Charles M. | Top entry apparatus and method for a drilling assembly |
US5584343A (en) | 1995-04-28 | 1996-12-17 | Davis-Lynch, Inc. | Method and apparatus for filling and circulating fluid in a wellbore during casing running operations |
US5575344A (en) | 1995-05-12 | 1996-11-19 | Reedrill Corp. | Rod changing system |
US5540279A (en) | 1995-05-16 | 1996-07-30 | Halliburton Company | Downhole tool apparatus with non-metallic packer element retaining shoes |
US5743344A (en) | 1995-05-18 | 1998-04-28 | Down Hole Technologies Pty. Ltd. | System for in situ replacement of cutting means for a ground drill |
US5542473A (en) | 1995-06-01 | 1996-08-06 | Pringle; Ronald E. | Simplified sealing and anchoring device for a well tool |
US5661888A (en) | 1995-06-07 | 1997-09-02 | Exxon Production Research Company | Apparatus and method for improved oilfield connections |
AUPN357995A0 (en) | 1995-06-15 | 1995-07-06 | Rear, Ian Graeme | Down hole hammer assembly |
US5711382A (en) | 1995-07-26 | 1998-01-27 | Hansen; James | Automated oil rig servicing system |
AUPN505295A0 (en) | 1995-08-28 | 1995-09-21 | Down Hole Technologies Pty Ltd | Retraction system for a latching mechanism of the tool |
GB9519247D0 (en) * | 1995-09-21 | 1995-11-22 | Coflexip Stena Offshore Ltd | Improvements in or relating to pipeline pigging |
US5791417A (en) | 1995-09-22 | 1998-08-11 | Weatherford/Lamb, Inc. | Tubular window formation |
US5921285A (en) | 1995-09-28 | 1999-07-13 | Fiberspar Spoolable Products, Inc. | Composite spoolable tube |
DE59508569D1 (en) | 1995-10-09 | 2000-08-17 | Baker Hughes Inc | Method and drill for drilling holes in underground formations |
US6196336B1 (en) | 1995-10-09 | 2001-03-06 | Baker Hughes Incorporated | Method and apparatus for drilling boreholes in earth formations (drilling liner systems) |
US5878815A (en) | 1995-10-26 | 1999-03-09 | Marathon Oil Company | Assembly and process for drilling and completing multiple wells |
US5842530A (en) | 1995-11-03 | 1998-12-01 | Canadian Fracmaster Ltd. | Hybrid coiled tubing/conventional drilling unit |
US5697442A (en) | 1995-11-13 | 1997-12-16 | Halliburton Company | Apparatus and methods for use in cementing a casing string within a well bore |
FR2741907B3 (en) | 1995-11-30 | 1998-02-20 | Drillflex | METHOD AND INSTALLATION FOR DRILLING AND LINERING A WELL, IN PARTICULAR AN OIL DRILLING WELL, BY MEANS OF INITIALLY FLEXIBLE BUTTED TUBULAR SECTIONS, AND HARDENED IN SITU |
GB2307939B (en) | 1995-12-09 | 2000-06-14 | Weatherford Oil Tool | Apparatus for gripping a pipe |
US5828003A (en) | 1996-01-29 | 1998-10-27 | Dowell -- A Division of Schlumberger Technology Corporation | Composite coiled tubing apparatus and methods |
BR9600249A (en) | 1996-01-29 | 1997-12-23 | Petroleo Brasileiro Sa | Method and apparatus for the disposal of subsea oil production |
US6065550A (en) | 1996-02-01 | 2000-05-23 | Gardes; Robert | Method and system for drilling and completing underbalanced multilateral wells utilizing a dual string technique in a live well |
US5720356A (en) | 1996-02-01 | 1998-02-24 | Gardes; Robert | Method and system for drilling underbalanced radial wells utilizing a dual string technique in a live well |
GB9603402D0 (en) | 1996-02-17 | 1996-04-17 | Camco Drilling Group Ltd | Improvements in or relating to rotary drill bits |
US5785132A (en) | 1996-02-29 | 1998-07-28 | Richardson; Allan S. | Backup tool and method for preventing rotation of a drill string |
GB9605801D0 (en) | 1996-03-20 | 1996-05-22 | Head Philip | A casing and method of installing the casing in a well and apparatus therefore |
US6085851A (en) | 1996-05-03 | 2000-07-11 | Transocean Offshore Inc. | Multi-activity offshore exploration and/or development drill method and apparatus |
US5823264A (en) | 1996-05-03 | 1998-10-20 | Halliburton Energy Services, Inc. | Travel joint for use in a subterranean well |
GB2313860B (en) | 1996-06-06 | 2000-11-01 | Paul Bernard Lee | Adjustable roller reamer |
US5833002A (en) | 1996-06-20 | 1998-11-10 | Baker Hughes Incorporated | Remote control plug-dropping head |
US5706894A (en) | 1996-06-20 | 1998-01-13 | Frank's International, Inc. | Automatic self energizing stop collar |
US5931231A (en) | 1996-06-27 | 1999-08-03 | Bucyrus International, Inc. | Blast hole drill pipe gripping mechanism |
US5794703A (en) | 1996-07-03 | 1998-08-18 | Ctes, L.C. | Wellbore tractor and method of moving an item through a wellbore |
GB9614761D0 (en) | 1996-07-13 | 1996-09-04 | Schlumberger Ltd | Downhole tool and method |
GB2315696A (en) | 1996-07-31 | 1998-02-11 | Weatherford Lamb | Mechanism for connecting and disconnecting tubulars |
US5890537A (en) | 1996-08-13 | 1999-04-06 | Schlumberger Technology Corporation | Wiper plug launching system for cementing casing and liners |
US5971086A (en) | 1996-08-19 | 1999-10-26 | Robert M. Bee | Pipe gripping die |
US6056060A (en) | 1996-08-23 | 2000-05-02 | Weatherford/Lamb, Inc. | Compensator system for wellbore tubulars |
US5850877A (en) | 1996-08-23 | 1998-12-22 | Weatherford/Lamb, Inc. | Joint compensator |
NO302774B1 (en) | 1996-09-13 | 1998-04-20 | Hitec Asa | Device for use in connection with feeding of feeding pipes |
AU738284C (en) | 1996-09-23 | 2002-06-13 | Halliburton Energy Services, Inc. | Autonomous downhole oilfield tool |
US5947213A (en) | 1996-12-02 | 1999-09-07 | Intelligent Inspection Corporation | Downhole tools using artificial intelligence based control |
US5735348A (en) | 1996-10-04 | 1998-04-07 | Frank's International, Inc. | Method and multi-purpose apparatus for dispensing and circulating fluid in wellbore casing |
US5918673A (en) | 1996-10-04 | 1999-07-06 | Frank's International, Inc. | Method and multi-purpose apparatus for dispensing and circulating fluid in wellbore casing |
US6279654B1 (en) | 1996-10-04 | 2001-08-28 | Donald E. Mosing | Method and multi-purpose apparatus for dispensing and circulating fluid in wellbore casing |
AU732227B2 (en) | 1996-10-15 | 2001-04-12 | National Oilwell Varco, L.P. | Continuous circulation drilling method |
US6688394B1 (en) | 1996-10-15 | 2004-02-10 | Coupler Developments Limited | Drilling methods and apparatus |
US6059051A (en) | 1996-11-04 | 2000-05-09 | Baker Hughes Incorporated | Integrated directional under-reamer and stabilizer |
US5839519A (en) | 1996-11-08 | 1998-11-24 | Sandvik Ab | Methods and apparatus for attaching a casing to a drill bit in overburden drilling equipment |
US5813456A (en) | 1996-11-12 | 1998-09-29 | Milner; John E. | Retrievable bridge plug and retrieving tool |
JP3187726B2 (en) | 1996-12-05 | 2001-07-11 | 日本海洋掘削株式会社 | Composite pipe lifting device for deep water drilling |
GB2320270B (en) | 1996-12-06 | 2001-01-17 | Psl Tools Ltd | Downhole tool |
FR2757426B1 (en) | 1996-12-19 | 1999-01-29 | Inst Francais Du Petrole | WATER-BASED FOAMING COMPOSITION - MANUFACTURING METHOD |
US5803666A (en) | 1996-12-19 | 1998-09-08 | Keller; Carl E. | Horizontal drilling method and apparatus |
US5890549A (en) | 1996-12-23 | 1999-04-06 | Sprehe; Paul Robert | Well drilling system with closed circulation of gas drilling fluid and fire suppression apparatus |
US5791410A (en) | 1997-01-17 | 1998-08-11 | Frank's Casing Crew & Rental Tools, Inc. | Apparatus and method for improved tubular grip assurance |
US6360633B2 (en) | 1997-01-29 | 2002-03-26 | Weatherford/Lamb, Inc. | Apparatus and method for aligning tubulars |
GB9703854D0 (en) | 1997-02-25 | 1997-04-16 | Weir Pumps Ltd | Improvements in downhole pumps |
US5950742A (en) | 1997-04-15 | 1999-09-14 | Camco International Inc. | Methods and related equipment for rotary drilling |
US5960881A (en) | 1997-04-22 | 1999-10-05 | Jerry P. Allamon | Downhole surge pressure reduction system and method of use |
US6464004B1 (en) | 1997-05-09 | 2002-10-15 | Mark S. Crawford | Retrievable well monitor/controller system |
US6085838A (en) | 1997-05-27 | 2000-07-11 | Schlumberger Technology Corporation | Method and apparatus for cementing a well |
WO1998054499A1 (en) * | 1997-05-30 | 1998-12-03 | Fmc Corporation | Pig delivery and transport system for subsea wells |
US6234257B1 (en) | 1997-06-02 | 2001-05-22 | Schlumberger Technology Corporation | Deployable sensor apparatus and method |
US5860474A (en) | 1997-06-26 | 1999-01-19 | Atlantic Richfield Company | Through-tubing rotary drilling |
US5839515A (en) | 1997-07-07 | 1998-11-24 | Halliburton Energy Services, Inc. | Slip retaining system for downhole tools |
US6119772A (en) | 1997-07-14 | 2000-09-19 | Pruet; Glen | Continuous flow cylinder for maintaining drilling fluid circulation while connecting drill string joints |
US5957225A (en) | 1997-07-31 | 1999-09-28 | Bp Amoco Corporation | Drilling assembly and method of drilling for unstable and depleted formations |
MY122241A (en) | 1997-08-01 | 2006-04-29 | Shell Int Research | Creating zonal isolation between the interior and exterior of a well system |
US6275938B1 (en) | 1997-08-28 | 2001-08-14 | Microsoft Corporation | Security enhancement for untrusted executable code |
US7140445B2 (en) | 1997-09-02 | 2006-11-28 | Weatherford/Lamb, Inc. | Method and apparatus for drilling with casing |
GB9718543D0 (en) | 1997-09-02 | 1997-11-05 | Weatherford Lamb | Method and apparatus for aligning tubulars |
US6742596B2 (en) | 2001-05-17 | 2004-06-01 | Weatherford/Lamb, Inc. | Apparatus and methods for tubular makeup interlock |
US6536520B1 (en) | 2000-04-17 | 2003-03-25 | Weatherford/Lamb, Inc. | Top drive casing system |
US7509722B2 (en) | 1997-09-02 | 2009-03-31 | Weatherford/Lamb, Inc. | Positioning and spinning device |
US5988273A (en) | 1997-09-03 | 1999-11-23 | Abb Vetco Gray Inc. | Coiled tubing completion system |
US6179055B1 (en) | 1997-09-05 | 2001-01-30 | Schlumberger Technology Corporation | Conveying a tool along a non-vertical well |
US5971079A (en) | 1997-09-05 | 1999-10-26 | Mullins; Albert Augustus | Casing filling and circulating apparatus |
US5954131A (en) | 1997-09-05 | 1999-09-21 | Schlumberger Technology Corporation | Method and apparatus for conveying a logging tool through an earth formation |
US6098717A (en) | 1997-10-08 | 2000-08-08 | Formlock, Inc. | Method and apparatus for hanging tubulars in wells |
US6199641B1 (en) | 1997-10-21 | 2001-03-13 | Tesco Corporation | Pipe gripping device |
US6296066B1 (en) | 1997-10-27 | 2001-10-02 | Halliburton Energy Services, Inc. | Well system |
US6012878A (en) * | 1997-12-02 | 2000-01-11 | Tdw Delaware, Inc. | Pressure balanced subsea tapping machine |
US6527493B1 (en) | 1997-12-05 | 2003-03-04 | Varco I/P, Inc. | Handling of tube sections in a rig for subsoil drilling |
US5921332A (en) | 1997-12-29 | 1999-07-13 | Sandvik Ab | Apparatus for facilitating removal of a casing of an overburden drilling equipment from a bore |
US5984007A (en) | 1998-01-09 | 1999-11-16 | Halliburton Energy Services, Inc. | Chip resistant buttons for downhole tools having slip elements |
GB2333542B (en) | 1998-01-24 | 2002-12-11 | Downhole Products Plc | Downhole tool |
US6200068B1 (en) * | 1998-02-06 | 2001-03-13 | Sonsub, Inc. | Hot tap fluid blaster apparatus and method of using same |
US6367566B1 (en) | 1998-02-20 | 2002-04-09 | Gilman A. Hill | Down hole, hydrodynamic well control, blowout prevention |
CA2261495A1 (en) | 1998-03-13 | 1999-09-13 | Praful C. Desai | Method for milling casing and drilling formation |
EP1075584B1 (en) * | 1998-03-30 | 2009-10-14 | Kellogg Brown & Root, Inc. | Extended reach tie-back system |
DK1071863T3 (en) | 1998-04-14 | 2004-01-26 | Welltec Aps | Connection to drill pipe |
US6070500A (en) | 1998-04-20 | 2000-06-06 | White Bear Energy Serives Ltd. | Rotatable die holder |
US6390190B2 (en) | 1998-05-11 | 2002-05-21 | Offshore Energy Services, Inc. | Tubular filling system |
US6142246A (en) | 1998-05-15 | 2000-11-07 | Petrolphysics Partners Lp | Multiple lateral hydraulic drilling apparatus and method |
GB2364728B (en) | 1998-05-16 | 2002-12-04 | Duncan Cuthill | Method of and apparatus for installing a pile underwater to create a mooring anchorage |
US6135208A (en) | 1998-05-28 | 2000-10-24 | Halliburton Energy Services, Inc. | Expandable wellbore junction |
CA2273568C (en) | 1998-06-04 | 2007-08-14 | Philip Head | A method of installing a casing in a well and apparatus therefor |
EP0962384A1 (en) | 1998-06-05 | 1999-12-08 | Single Buoy Moorings Inc. | Loading arrangement |
AU751544B2 (en) | 1998-06-11 | 2002-08-22 | Weatherford Technology Holdings, Llc | A drilling tool |
CA2240559C (en) | 1998-06-12 | 2003-12-23 | Sandvik Ab | Embankment hammer |
US6012529A (en) | 1998-06-22 | 2000-01-11 | Mikolajczyk; Raymond F. | Downhole guide member for multiple casing strings |
US6170573B1 (en) | 1998-07-15 | 2001-01-09 | Charles G. Brunet | Freely moving oil field assembly for data gathering and or producing an oil well |
GB9815809D0 (en) | 1998-07-22 | 1998-09-16 | Appleton Robert P | Casing running tool |
US6220117B1 (en) | 1998-08-18 | 2001-04-24 | Baker Hughes Incorporated | Methods of high temperature infiltration of drill bits and infiltrating binder |
GB2340859A (en) | 1998-08-24 | 2000-03-01 | Weatherford Lamb | Method and apparatus for facilitating the connection of tubulars using a top drive |
US6079509A (en) | 1998-08-31 | 2000-06-27 | Robert Michael Bee | Pipe die method and apparatus |
US6202764B1 (en) | 1998-09-01 | 2001-03-20 | Muriel Wayne Ables | Straight line, pump through entry sub |
US6241036B1 (en) | 1998-09-16 | 2001-06-05 | Baker Hughes Incorporated | Reinforced abrasive-impregnated cutting elements, drill bits including same |
CA2345244C (en) | 1998-09-25 | 2009-04-21 | Robert Patrick Appleton | An apparatus for facilitating the connection of tubulars using a top drive |
AUPP683898A0 (en) | 1998-10-29 | 1998-11-26 | Dht Technologies Limited | Retractable drill bit system |
US6142545A (en) | 1998-11-13 | 2000-11-07 | Bj Services Company | Casing pushdown and rotating tool |
US6557640B1 (en) | 1998-12-07 | 2003-05-06 | Shell Oil Company | Lubrication and self-cleaning system for expansion mandrel |
US6863129B2 (en) | 1998-11-19 | 2005-03-08 | Schlumberger Technology Corporation | Method and apparatus for providing plural flow paths at a lateral junction |
US6186233B1 (en) | 1998-11-30 | 2001-02-13 | Weatherford Lamb, Inc. | Down hole assembly and method for forming a down hole window and at least one keyway in communication with the down hole window for use in multilateral wells |
US6725919B2 (en) | 1998-12-07 | 2004-04-27 | Shell Oil Company | Forming a wellbore casing while simultaneously drilling a wellbore |
CA2351176C (en) | 1998-12-12 | 2009-02-24 | Dresser Industries, Inc. | Apparatus for measuring downhole drilling efficiency parameters |
US6347674B1 (en) | 1998-12-18 | 2002-02-19 | Western Well Tool, Inc. | Electrically sequenced tractor |
DE69926802D1 (en) | 1998-12-22 | 2005-09-22 | Weatherford Lamb | METHOD AND DEVICE FOR PROFILING AND CONNECTING PIPES |
GB2347441B (en) | 1998-12-24 | 2003-03-05 | Weatherford Lamb | Apparatus and method for facilitating the connection of tubulars using a top drive |
GB2345074A (en) | 1998-12-24 | 2000-06-28 | Weatherford Lamb | Floating joint to facilitate the connection of tubulars using a top drive |
US6218328B1 (en) | 1998-12-29 | 2001-04-17 | Phillips Petroleum Company | Method of preparing a zeolite based catalyst material |
US6250405B1 (en) | 1999-01-06 | 2001-06-26 | Western Well Tool, Inc. | Drill pipe protector assembly |
DE60010647T2 (en) | 1999-01-11 | 2005-05-19 | Weatherford/Lamb, Inc., Houston | GRINDING UNIT WITH A MULTIDENCE OF EXTRACTS FOR USE IN A BOREOLE, AND METHOD FOR INTRODUCING SUCH A RADIATORY PURITY |
US6273189B1 (en) | 1999-02-05 | 2001-08-14 | Halliburton Energy Services, Inc. | Downhole tractor |
US6173777B1 (en) | 1999-02-09 | 2001-01-16 | Albert Augustus Mullins | Single valve for a casing filling and circulating apparatus |
US6429784B1 (en) | 1999-02-19 | 2002-08-06 | Dresser Industries, Inc. | Casing mounted sensors, actuators and generators |
US7311148B2 (en) | 1999-02-25 | 2007-12-25 | Weatherford/Lamb, Inc. | Methods and apparatus for wellbore construction and completion |
US6837313B2 (en) | 2002-01-08 | 2005-01-04 | Weatherford/Lamb, Inc. | Apparatus and method to reduce fluid pressure in a wellbore |
GB9904380D0 (en) | 1999-02-25 | 1999-04-21 | Petroline Wellsystems Ltd | Drilling method |
US6896075B2 (en) | 2002-10-11 | 2005-05-24 | Weatherford/Lamb, Inc. | Apparatus and methods for drilling with casing |
US6857487B2 (en) | 2002-12-30 | 2005-02-22 | Weatherford/Lamb, Inc. | Drilling with concentric strings of casing |
US6854533B2 (en) | 2002-12-20 | 2005-02-15 | Weatherford/Lamb, Inc. | Apparatus and method for drilling with casing |
US6691801B2 (en) | 1999-03-05 | 2004-02-17 | Varco I/P, Inc. | Load compensator for a pipe running tool |
US6637526B2 (en) | 1999-03-05 | 2003-10-28 | Varco I/P, Inc. | Offset elevator for a pipe running tool and a method of using a pipe running tool |
ATE373160T1 (en) | 1999-03-05 | 2007-09-15 | Varco Int | INSTALLATION AND REMOVAL DEVICE FOR PIPES |
GB2348223B (en) | 1999-03-11 | 2003-09-24 | Shell Internat Res Maatschhapp | Method of creating a casing in a borehole |
US6290432B1 (en) | 1999-04-06 | 2001-09-18 | Williams Field Services Gulf Coast Company, L.P. | Diverless subsea hot tap system |
DE60003651T2 (en) | 1999-04-09 | 2004-06-24 | Shell Internationale Research Maatschappij B.V. | METHOD FOR PRODUCING A HOLE IN A SUBSTRATE INFORMATION |
US6309002B1 (en) | 1999-04-09 | 2001-10-30 | Frank's Casing Crew And Rental Tools, Inc. | Tubular running tool |
US6431626B1 (en) | 1999-04-09 | 2002-08-13 | Frankis Casing Crew And Rental Tools, Inc. | Tubular running tool |
US6538576B1 (en) | 1999-04-23 | 2003-03-25 | Halliburton Energy Services, Inc. | Self-contained downhole sensor and method of placing and interrogating same |
GB9910238D0 (en) | 1999-05-05 | 1999-06-30 | Brit Bit Down Hole Tools | Improvements relating to subsea drilling of boreholes |
GB2349401B (en) | 1999-05-05 | 2003-06-04 | Smith International | Assembly and method for jarring a drilling drive pipe into undersea formation |
US6598677B1 (en) | 1999-05-20 | 2003-07-29 | Baker Hughes Incorporated | Hanging liners by pipe expansion |
OA11882A (en) | 1999-06-03 | 2006-03-28 | Shell Int Research | Method of creating a wellbore. |
US6446723B1 (en) | 1999-06-09 | 2002-09-10 | Schlumberger Technology Corporation | Cable connection to sensors in a well |
US6237684B1 (en) | 1999-06-11 | 2001-05-29 | Frank's Casing Crewand Rental Tools, Inc. | Pipe string handling apparatus and method |
NO20003824L (en) | 1999-07-27 | 2001-01-29 | Baker Hughes Inc | Reusable cutting and milling tools |
US6189621B1 (en) | 1999-08-16 | 2001-02-20 | Smart Drilling And Completion, Inc. | Smart shuttles to complete oil and gas wells |
US6371693B1 (en) * | 1999-08-27 | 2002-04-16 | Shell Oil Company | Making subsea pipelines ready for electrical heating |
US6343649B1 (en) | 1999-09-07 | 2002-02-05 | Halliburton Energy Services, Inc. | Methods and associated apparatus for downhole data retrieval, monitoring and tool actuation |
EA003012B1 (en) | 1999-09-15 | 2002-12-26 | Шелл Интернэшнл Рисерч Маатсхаппий Б.В. | System for enhancing fluid flow in a well |
US6315062B1 (en) | 1999-09-24 | 2001-11-13 | Vermeer Manufacturing Company | Horizontal directional drilling machine employing inertial navigation control system and method |
NO994854L (en) | 1999-10-06 | 2001-04-09 | Subsurface Technology As | Protective sleeve for flexible cables extending along the production string |
US6311792B1 (en) | 1999-10-08 | 2001-11-06 | Tesco Corporation | Casing clamp |
CA2287696C (en) | 1999-10-28 | 2005-11-22 | Leonardo Ritorto | Locking swivel device |
US6367552B1 (en) | 1999-11-30 | 2002-04-09 | Halliburton Energy Services, Inc. | Hydraulically metered travel joint |
US6419033B1 (en) | 1999-12-10 | 2002-07-16 | Baker Hughes Incorporated | Apparatus and method for simultaneous drilling and casing wellbores |
US6325148B1 (en) | 1999-12-22 | 2001-12-04 | Weatherford/Lamb, Inc. | Tools and methods for use with expandable tubulars |
EP1242711B1 (en) | 1999-12-22 | 2006-08-16 | Weatherford/Lamb, Inc. | Drilling bit for drilling while running casing |
GB9930450D0 (en) | 1999-12-23 | 2000-02-16 | Eboroil Sa | Subsea well intervention vessel |
US6227587B1 (en) | 2000-02-07 | 2001-05-08 | Emma Dee Gray | Combined well casing spider and elevator |
US6374924B2 (en) | 2000-02-18 | 2002-04-23 | Halliburton Energy Services, Inc. | Downhole drilling apparatus |
GB2373520B (en) | 2000-02-18 | 2004-11-24 | Halliburton Energy Serv Inc | Downhole drilling apparatus and method for use of same |
US6553825B1 (en) | 2000-02-18 | 2003-04-29 | Anthony R. Boyd | Torque swivel and method of using same |
EP1257728B1 (en) | 2000-02-22 | 2012-04-11 | Weatherford/Lamb, Inc. | Artificial lift apparatus with automated monitoring of fluid height in the borehole |
US6412554B1 (en) | 2000-03-14 | 2002-07-02 | Weatherford/Lamb, Inc. | Wellbore circulation system |
US7107875B2 (en) | 2000-03-14 | 2006-09-19 | Weatherford/Lamb, Inc. | Methods and apparatus for connecting tubulars while drilling |
CA2301963C (en) | 2000-03-22 | 2004-03-09 | Noetic Engineering Inc. | Method and apparatus for handling tubular goods |
US6427776B1 (en) | 2000-03-27 | 2002-08-06 | Weatherford/Lamb, Inc. | Sand removal and device retrieval tool |
WO2001073261A2 (en) * | 2000-03-27 | 2001-10-04 | Rockwater Limited | Riser with retrievable internal services |
US20020108748A1 (en) | 2000-04-12 | 2002-08-15 | Keyes Robert C. | Replaceable tong die inserts for pipe tongs |
GB0008988D0 (en) | 2000-04-13 | 2000-05-31 | Bbl Downhole Tools Ltd | Drill bit nozzle |
US7334650B2 (en) | 2000-04-13 | 2008-02-26 | Weatherford/Lamb, Inc. | Apparatus and methods for drilling a wellbore using casing |
US7296623B2 (en) | 2000-04-17 | 2007-11-20 | Weatherford/Lamb, Inc. | Methods and apparatus for applying torque and rotation to connections |
US7325610B2 (en) | 2000-04-17 | 2008-02-05 | Weatherford/Lamb, Inc. | Methods and apparatus for handling and drilling with tubulars or casing |
GB0010378D0 (en) | 2000-04-28 | 2000-06-14 | Bbl Downhole Tools Ltd | Expandable apparatus for drift and reaming a borehole |
CA2406663C (en) | 2000-05-05 | 2006-01-03 | Weatherford/Lamb, Inc. | Apparatus and methods for forming a lateral wellbore |
CA2335192A1 (en) | 2000-05-31 | 2001-11-30 | Vincent J. Kozak | Improvements in downhole tools |
US6349764B1 (en) | 2000-06-02 | 2002-02-26 | Oil & Gas Rental Services, Inc. | Drilling rig, pipe and support apparatus |
US6374506B1 (en) | 2000-06-16 | 2002-04-23 | Stp Nuclear Operating Company | Shaft centering tool for nuclear reactor coolant pump motor |
GB2364079B (en) | 2000-06-28 | 2004-11-17 | Renovus Ltd | Drill bits |
US6454007B1 (en) | 2000-06-30 | 2002-09-24 | Weatherford/Lamb, Inc. | Method and apparatus for casing exit system using coiled tubing |
US20030070841A1 (en) | 2000-06-30 | 2003-04-17 | S & S Trust | Shallow depth, coiled tubing horizontal drilling system |
US6554064B1 (en) | 2000-07-13 | 2003-04-29 | Halliburton Energy Services, Inc. | Method and apparatus for a sand screen with integrated sensors |
US6408943B1 (en) | 2000-07-17 | 2002-06-25 | Halliburton Energy Services, Inc. | Method and apparatus for placing and interrogating downhole sensors |
US6419014B1 (en) | 2000-07-20 | 2002-07-16 | Schlumberger Technology Corporation | Apparatus and method for orienting a downhole tool |
GB2365463B (en) | 2000-08-01 | 2005-02-16 | Renovus Ltd | Drilling method |
GB2365888B (en) | 2000-08-11 | 2002-07-24 | Renovus Ltd | Drilling apparatus |
US8171989B2 (en) | 2000-08-14 | 2012-05-08 | Schlumberger Technology Corporation | Well having a self-contained inter vention system |
US6392317B1 (en) | 2000-08-22 | 2002-05-21 | David R. Hall | Annular wire harness for use in drill pipe |
NO328641B1 (en) | 2000-09-01 | 2010-04-12 | Maersk Olie & Gas | Procedure for Stimulating a Well |
US7264050B2 (en) | 2000-09-22 | 2007-09-04 | Weatherford/Lamb, Inc. | Method and apparatus for controlling wellbore equipment |
US20040011534A1 (en) | 2002-07-16 | 2004-01-22 | Simonds Floyd Randolph | Apparatus and method for completing an interval of a wellbore while drilling |
GB2357530B (en) | 2000-11-04 | 2003-09-03 | Weatherford Lamb | Method and apparatus for gripping tubulars |
US6752211B2 (en) | 2000-11-10 | 2004-06-22 | Smith International, Inc. | Method and apparatus for multilateral junction |
GB0029285D0 (en) * | 2000-11-30 | 2001-01-17 | Alpha Thames Ltd | Pigging method and apparatus |
US6651737B2 (en) | 2001-01-24 | 2003-11-25 | Frank's Casing Crew And Rental Tools, Inc. | Collar load support system and method |
GB0103576D0 (en) | 2001-02-14 | 2001-03-28 | Axtech Ltd | Pump |
GB2372765A (en) | 2001-02-27 | 2002-09-04 | Philip Head | Use of coiled tubing and jet drilling to install a casing |
US6698595B2 (en) | 2001-04-19 | 2004-03-02 | Weatherford/Lamb, Inc. | Screen material |
US6702040B1 (en) | 2001-04-26 | 2004-03-09 | Floyd R. Sensenig | Telescopic drilling method |
US6745834B2 (en) | 2001-04-26 | 2004-06-08 | Schlumberger Technology Corporation | Complete trip system |
US6648562B1 (en) * | 2001-06-08 | 2003-11-18 | Charles D. Calkins | Apparatus for tapping a hole in a pipeline |
US6725924B2 (en) | 2001-06-15 | 2004-04-27 | Schlumberger Technology Corporation | System and technique for monitoring and managing the deployment of subsea equipment |
WO2003006778A1 (en) | 2001-07-09 | 2003-01-23 | Baker Hughes Inc | Drilling system and method for controlling equivalent circulating density during drilling of wellbores |
US6648075B2 (en) | 2001-07-13 | 2003-11-18 | Weatherford/Lamb, Inc. | Method and apparatus for expandable liner hanger with bypass |
GB2377951B (en) | 2001-07-25 | 2004-02-04 | Schlumberger Holdings | Method and system for drilling a wellbore having cable based telemetry |
US6877553B2 (en) | 2001-09-26 | 2005-04-12 | Weatherford/Lamb, Inc. | Profiled recess for instrumented expandable components |
US6655460B2 (en) | 2001-10-12 | 2003-12-02 | Weatherford/Lamb, Inc. | Methods and apparatus to control downhole tools |
US6679333B2 (en) | 2001-10-26 | 2004-01-20 | Canrig Drilling Technology, Ltd. | Top drive well casing system and method |
US6634430B2 (en) | 2001-12-20 | 2003-10-21 | Exxonmobil Upstream Research Company | Method for installation of evacuated tubular conduits |
AU2002237401A1 (en) * | 2002-03-01 | 2003-09-16 | Head Philip | Conductor system |
GB0206227D0 (en) | 2002-03-16 | 2002-05-01 | Weatherford Lamb | Bore-lining and drilling |
US6749026B2 (en) | 2002-03-21 | 2004-06-15 | Halliburton Energy Services, Inc. | Method of forming downhole tubular string connections |
US7234546B2 (en) | 2002-04-08 | 2007-06-26 | Baker Hughes Incorporated | Drilling and cementing casing system |
US6666274B2 (en) | 2002-05-15 | 2003-12-23 | Sunstone Corporation | Tubing containing electrical wiring insert |
US6688392B2 (en) * | 2002-05-23 | 2004-02-10 | Baker Hughes Incorporated | System and method for flow/pressure boosting in a subsea environment |
FR2841293B1 (en) | 2002-06-19 | 2006-03-03 | Bouygues Offshore | TELESCOPIC GUIDE FOR DRILLING AT SEA |
US6832656B2 (en) | 2002-06-26 | 2004-12-21 | Weartherford/Lamb, Inc. | Valve for an internal fill up tool and associated method |
US7178592B2 (en) | 2002-07-10 | 2007-02-20 | Weatherford/Lamb, Inc. | Closed loop multiphase underbalanced drilling process |
US6715430B2 (en) | 2002-07-19 | 2004-04-06 | Jae Chul Choi | Sectional table with gusset |
US6892835B2 (en) | 2002-07-29 | 2005-05-17 | Weatherford/Lamb, Inc. | Flush mounted spider |
US6994176B2 (en) | 2002-07-29 | 2006-02-07 | Weatherford/Lamb, Inc. | Adjustable rotating guides for spider or elevator |
GB2382361B (en) | 2002-08-30 | 2004-02-25 | Technology Ventures Internat L | A method of forming a bore |
US6899186B2 (en) | 2002-12-13 | 2005-05-31 | Weatherford/Lamb, Inc. | Apparatus and method of drilling with casing |
US7219730B2 (en) | 2002-09-27 | 2007-05-22 | Weatherford/Lamb, Inc. | Smart cementing systems |
US6832658B2 (en) | 2002-10-11 | 2004-12-21 | Larry G. Keast | Top drive system |
US7303022B2 (en) | 2002-10-11 | 2007-12-04 | Weatherford/Lamb, Inc. | Wired casing |
US6889772B2 (en) | 2002-10-23 | 2005-05-10 | Frank's International, Inc. | Method and apparatus for installing control lines in a well |
US6953096B2 (en) | 2002-12-31 | 2005-10-11 | Weatherford/Lamb, Inc. | Expandable bit with secondary release device |
US7128154B2 (en) | 2003-01-30 | 2006-10-31 | Weatherford/Lamb, Inc. | Single-direction cementing plug |
GB2414502B (en) | 2003-02-27 | 2007-10-17 | Weatherford Lamb | Drill shoe |
CA2677247C (en) | 2003-03-05 | 2012-09-25 | Weatherford/Lamb, Inc. | Casing running and drilling system |
CA2517978C (en) | 2003-03-05 | 2009-07-14 | Weatherford/Lamb, Inc. | Drilling with casing latch |
WO2004079150A2 (en) | 2003-03-05 | 2004-09-16 | Weatherford/Lamb, Inc. | Full bore lined wellbores |
US7311114B2 (en) * | 2005-05-20 | 2007-12-25 | Tdw Delaware, Inc. | Cross-line plugging system |
-
2003
- 2003-07-11 US US10/618,093 patent/US7650944B1/en not_active Expired - Fee Related
-
2004
- 2004-07-07 AU AU2004203054A patent/AU2004203054B2/en not_active Ceased
- 2004-07-07 CA CA2473073A patent/CA2473073C/en not_active Expired - Fee Related
- 2004-07-09 BR BRPI0402753-1A patent/BRPI0402753B1/en not_active IP Right Cessation
- 2004-07-09 NO NO20042922A patent/NO335948B1/en not_active IP Right Cessation
- 2004-07-09 EP EP20040254129 patent/EP1496297B1/en not_active Expired - Fee Related
Also Published As
Publication number | Publication date |
---|---|
NO20042922L (en) | 2005-01-12 |
NO335948B1 (en) | 2015-03-30 |
EP1496297A2 (en) | 2005-01-12 |
BRPI0402753B1 (en) | 2015-06-23 |
CA2473073A1 (en) | 2005-01-11 |
US7650944B1 (en) | 2010-01-26 |
AU2004203054A1 (en) | 2005-01-27 |
BRPI0402753A (en) | 2005-02-22 |
EP1496297B1 (en) | 2007-11-14 |
AU2004203054B2 (en) | 2007-09-13 |
EP1496297A3 (en) | 2005-05-11 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CA2473073C (en) | Vessel for well intervention | |
US10329860B2 (en) | Managed pressure drilling system having well control mode | |
US7913764B2 (en) | Return line mounted pump for riserless mud return system | |
US6840322B2 (en) | Subsea well intervention vessel | |
US7134498B2 (en) | Well drilling and completions system | |
US10012044B2 (en) | Annular isolation device for managed pressure drilling | |
US20040104052A1 (en) | Reverse circulation directional and horizontal drilling using concentric coil tubing | |
EP2013446B1 (en) | Wellbore system | |
EP2236739B1 (en) | Well unloading package | |
US5842528A (en) | Method of drilling and completing wells | |
US20120080186A1 (en) | Apparatus and system for processing solids in subsea drilling or excavation | |
US20220268127A1 (en) | Downhole apparatus and methods for casing | |
WO2005012685A1 (en) | Drilling method | |
WO2017201154A1 (en) | Mat for wellhead cellar | |
WO2016106267A1 (en) | Riserless subsea well abandonment system | |
Walker | Extended-Reach Drilling Offshore California: An Operator's Experience with Drilling a Record Extended Reach Well | |
Crook | Stopping the spill |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
EEER | Examination request | ||
MKLA | Lapsed |
Effective date: 20180709 |