Catwalk System

Info

Publication number: 20200332609
Type: Application
Filed: Apr 22, 2019
Publication Date: Oct 22, 2020
Inventor: Aaron Bryant (Houston, TX)
Application Number: 16/390,363

Abstract

A catwalk system comprising a catwalk suitcase and a tubular handling catwalk. The catwalk suitcase may have a base configured to receive the tubular handling catwalk, and a ramp connected with the base and configured to extend diagonally to a drill rig floor located at an oil and gas wellsite. The ramp may be configured to facilitate movement of tubulars from the tubular handling catwalk to the drill rig floor.

Description

Description

BACKGROUND OF THE DISCLOSURE

Wells are generally drilled into the ground or ocean bed to recover natural deposits of oil, gas, and other materials that are trapped in subterranean formations. Well construction operations (e.g., drilling operations) may be performed at a wellsite by a drilling system (e.g., a drilling rig) having various automated surface and subterranean equipment operating in a coordinated manner. For example, a drive mechanism, such as a top drive or rotary table located at a wellsite surface can be utilized to rotate and advance a drill string into a subterranean formation to drill a wellbore. The drill string may include a plurality of drill pipes coupled together and terminating with a drill bit. Length of the drill string may be increased by adding additional drill pipes while depth of the wellbore increases. Drilling fluid may be pumped from the wellsite surface down through the drill string to the drill bit. The drilling fluid lubricates and cools the drill bit, and carries drill cuttings from the wellbore back to the wellsite surface. The drilling fluid returning to the surface may then be cleaned and again pumped through the drill string. The equipment of the drilling system may be grouped into various subsystems, wherein each subsystem performs a different operation controlled by a corresponding local and/or a remotely located controller.

A tubular handling machine, such as a catwalk, may convey tubulars between a rig floor of the drilling system and a tubular storage area, which may be located at a ground level of the wellsite below the rig floor. When a catwalk has to be replaced with another catwalk, such as to accommodate different tubulars to be transferred to the rig floor, the catwalk has to be replaced expeditiously to resume the drilling and/or other wellsite operations. Also, when a catwalk breaks down, tubulars cannot be transferred to the rig floor, thereby bringing drilling and/or other wellsite operations to a standstill. If the catwalk cannot be repaired expeditiously onsite, the catwalk will also have to be replaced. However, disassembly, removal, and installation of a replacement catwalk can take an extended period of time (e.g., several hours, a full day, or longer).

SUMMARY OF THE DISCLOSURE

This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify indispensable features of the claimed subject matter, nor is it intended for use as an aid in limiting the scope of the claimed subject matter.

The present disclosure introduces an apparatus including a base and a ramp. The base receives a tubular handling catwalk. The ramp is connected with the base and extends diagonally to a drill rig floor located at an oil and gas wellsite. The ramp facilitates movement of tubulars from the tubular handling catwalk to the drill rig floor.

The present disclosure also introduces an apparatus including a catwalk suitcase that includes a base, a ramp, and fluid conduits. The base detachably connects with a tubular handling catwalk. The ramp is connected with the base and extends to a drill rig floor located at an oil and gas wellsite. The ramp facilitates movement of tubulars from the tubular handling catwalk to the drill rig floor. The fluid conduits are connected with and extend along the base and/or ramp.

The present disclosure also introduces a method that includes installing a catwalk suitcase at an oil and gas wellsite such that a base of the catwalk suitcase is disposed at a ground level of the oil and gas wellsite and a ramp of the catwalk suitcase extends to a rig floor of a drill rig. The method also includes detachably connecting a tubular handling catwalk with the base and moving tubulars from the tubular handling catwalk to the rig floor via the ramp.

These and additional aspects of the present disclosure are set forth in the description that follows, and/or may be learned by a person having ordinary skill in the art by reading the material herein and/or practicing the principles described herein. At least some aspects of the present disclosure may be achieved via means recited in the attached claims.

BRIEF DESCRIPTION OF THE DRAWINGS

The present disclosure is understood from the following detailed description when read with the accompanying figures. It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale. In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.

FIG. 1 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 2 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 3 is a schematic side view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 4 is a side view of the apparatus shown in FIG. 3 in a different stage of operations according to one or more aspects of the present disclosure.

FIG. 5 is a side view of at least a portion of the apparatus shown in FIG. 4 in a different stage of operations according to one or more aspects of the present disclosure.

FIG. 6 is a top view of the apparatus shown in FIG. 4 according to one or more aspects of the present disclosure.

FIG. 7 is a bottom view of the apparatus shown in FIG. 4 according to one or more aspects of the present disclosure.

FIG. 8 is a front view of the apparatus shown in FIG. 4 according to one or more aspects of the present disclosure.

FIG. 9 is a back view of the apparatus shown in FIG. 4 according to one or more aspects of the present disclosure.

DETAILED DESCRIPTION

It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the present disclosure. These are, of course, merely examples and are not intended to be limiting. In addition, the present disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for simplicity and clarity, and does not in itself dictate a relationship between the various embodiments and/or configurations discussed.

Systems and methods (e.g., processes, operations) according to one or more aspects of the present disclosure may be utilized or otherwise implemented in association with an automated well construction system (e.g., a drilling rig) at an oil and gas wellsite, such as for constructing a wellbore to obtain hydrocarbons (e.g., oil and/or gas) from a subterranean formation. However, one or more aspects of the present disclosure may be utilized or otherwise implemented in association with other automated systems in the oil and gas industry and other industries. For example, one or more aspects of the present disclosure may be implemented in association with wellsite systems for performing fracturing, cementing, acidizing, chemical injecting, and/or water jet cutting operations, among other examples. One or more aspects of the present disclosure may also be implemented in association with mining sites, building construction sites, and/or other work sites where automated machines or equipment are utilized.

FIG. 1 is a schematic view of at least a portion of an example implementation of a well construction system 100 according to one or more aspects of the present disclosure. The well construction system 100 represents an example environment in which one or more aspects of the present disclosure described below may be implemented.

The well construction system 100, which may be or comprise a drilling rig, is depicted in relation to a wellbore 102 formed by rotary and/or directional drilling from a wellsite surface 104 and extending into a subterranean formation 106. The well construction system 100 includes surface equipment 110 located at the wellsite surface 104 and a drill string 120 suspended within the wellbore 102. The surface equipment 110 may include a mast, a derrick, and/or another support structure 112 disposed over a rig floor 114. The drill string 120 may be suspended within the wellbore 102 from the support structure 112. The support structure 112 and the rig floor 114 may be collectively supported over the wellbore 102 above the ground level of the wellsite surface 104 by legs and/or other support structures (not shown).

The drill string 120 may comprise a bottom-hole assembly (BHA) 124 and means 122 for conveying the BHA 124 within the wellbore 102. The conveyance means 122 may comprise drill pipe, heavy-weight drill pipe (HWDP), wired drill pipe (WDP), tough logging condition (TLC) pipe, coiled tubing, and/or other means for conveying the BHA 124 within the wellbore 102. A downhole end of the BHA 124 may include or be coupled to a drill bit 126. Rotation of the drill bit 126 and the weight of the drill string 120 collectively operate to form the wellbore 102. The drill bit 126 may be rotated from the wellsite surface 104 and/or via a downhole mud motor (not shown) connected with the drill bit 126.

The support structure 112 may support a driver, such as a top drive 116, operable to connect (perhaps indirectly) with an uphole end of the conveyance means 122, and to impart rotary motion 117 and vertical motion 135 to the drill string 120 and the drill bit 126. However, another driver, such as a kelly and rotary table (neither shown), may be utilized instead of or in addition to the top drive 116 to impart the rotary motion 117. The top drive 116 and the connected drill string 120 may be suspended from the support structure 112 via hoisting equipment, which may include a traveling block 118, a crown block (not shown), and a draw works 119 storing a support cable or line 123. The crown block may be connected to or otherwise supported by the support structure 112, and the traveling block 118 may be coupled with the top drive 116, such as via a hook. The draw works 119 may be mounted on or otherwise supported by the rig floor 114. The crown block and traveling block 118 comprise pulleys or sheaves around which the support line 123 is reeved to operatively connect the crown block, the traveling block 118, and the draw works 119 (and perhaps an anchor). The draw works 119 may thus selectively impart tension to the support line 123 to lift and lower the top drive 116, resulting in the vertical motion 135. The draw works 119 may comprise a drum, a frame, and a prime mover (e.g., an engine or motor) (not shown) operable to drive the drum to rotate and reel in the support line 123, causing the traveling block 118 and the top drive 116 to move upward. The draw works 119 may be operable to release the support line 123 via a controlled rotation of the drum, causing the traveling block 118 and the top drive 116 to move downward.

The top drive 116 may comprise a grabber, a swivel (neither shown), a tubular handling assembly links 127 terminating with an elevator 129, and a drive shaft 125 operatively connected with a prime mover (not shown), such as via a gear box or transmission (not shown). The drill string 120 may be mechanically coupled to the drive shaft 125 with or without a sub saver between the drill string 120 and the drive shaft 125. The prime mover may be selectively operated to rotate the drive shaft 125 and the drill string 120 coupled with the drive shaft 125. Hence, during drilling operations, the top drive 116 in conjunction with operation of the draw works 119 may advance the drill string 120 into the formation 106 to form the wellbore 102. The tubular handling assembly links 127 and the elevator 129 of the top drive 116 may handle tubulars (e.g., drill pipes, drill collars, downhole tools, casing joints, etc.) that are not mechanically coupled to the drive shaft 125. For example, when the drill string 120 is being tripped into or out of the wellbore 102, the elevator 129 may grasp individual tubulars and tubulars forming the drill string 120 such that the individual tubulars and the drill string can be raised and/or lowered via the hoisting equipment mechanically coupled to the top drive 116. The grabber may include a clamp that clamps onto a tubular when making up and/or breaking out a connection of a tubular with the drive shaft 125.

The well construction system 100 may further include a well control system for maintaining well pressure control. For example, the drill string 120 may be conveyed within the wellbore 102 through various blowout preventer (BOP) equipment disposed at the wellsite surface 104 on top of the wellbore 102 and perhaps below the rig floor 114. The BOP equipment may be operable to control pressure within the wellbore 102 via a series of pressure barriers (e.g., rams) between the wellbore 102 and the wellsite surface 104. The BOP equipment may include a BOP stack 130, an annular preventer 132, and/or a rotating control device (RCD) 138 mounted above the annular preventer 132. The BOP equipment 130, 132, 138 may be mounted on top of a wellhead 134.

The well construction system 100 may further include a drilling fluid circulation system operable to circulate fluids between the surface equipment 110 and the drill bit 126 during drilling and other operations. For example, the drilling fluid circulation system may be operable to inject a drilling fluid from the wellsite surface 104 into the wellbore 102 via an internal fluid passage 121 extending longitudinally through the drill string 120. The drilling fluid circulation system may comprise a pit, a tank, and/or another fluid container 142 (e.g., a mud pit, a suction tank) holding the drilling fluid (i.e., mud) 140, and a pump 144 operable to move the drilling fluid 140 from the container 142 into the fluid passage 121 of the drill string 120 via a fluid conduit 146 extending from the pump 144 to the top drive 116 and an internal passage extending through the top drive 116. The fluid conduit 146 may comprise one or more of a pump discharge line, a stand pipe, a rotary hose, and a gooseneck (not shown) connected with a fluid inlet of the top drive 116. The pump 144 and the container 142 may be fluidly connected by a fluid conduit 148, such as a suction line.

During drilling operations, the drilling fluid may continue to flow downhole through the internal passage 121 of the drill string 120, as indicated by directional arrow 158. The drilling fluid may exit the BHA 124 via ports 128 in the drill bit 126 and then circulate uphole through an annular space 108 (“annulus”) of the wellbore 102 defined between an exterior of the drill string 120 and the wall of the wellbore 102, such flow being indicated by directional arrows 159. In this manner, the drilling fluid lubricates the drill bit 126 and carries formation cuttings uphole to the wellsite surface 104. The returning drilling fluid may exit the annulus 108 via a bell nipple 139, an RCD 138, and/or a ported adapter 136 (e.g., a spool, a wing valve, etc.) located below one or more portions of the BOP stack 130.

The drilling fluid exiting the annulus 108 via the bell nipple 139 may be directed toward drilling fluid reconditioning equipment 170 via a fluid conduit 145 (e.g., a gravity return line) to be cleaned and/or reconditioned, as described below, prior to being returned to the container 142 for recirculation. The drilling fluid exiting the annulus 108 via the RCD 138 may be directed into a fluid conduit 160 (e.g., a drilling pressure control line), and may pass through various wellsite equipment fluidly connected along the conduit 160 prior to being returned to the container 142 for recirculation. For example, the drilling fluid may pass through a choke manifold 162 (e.g., a drilling pressure control choke manifold) and then through the drilling fluid reconditioning equipment 170. The choke manifold 162 may include at least one choke and a plurality of fluid valves (neither shown) collectively operable to control the flow through and out of the choke manifold 162. Backpressure may be applied to the annulus 108 by variably restricting flow of the drilling fluid or other fluids flowing through the choke manifold 162. The greater the restriction to flow through the choke manifold 162, the greater the backpressure applied to the annulus 108. The drilling fluid exiting the annulus 108 via the ported adapter 136 may be directed into a fluid conduit 164 (e.g., a rig choke line), and may pass through various equipment fluidly connected along the conduit 164 prior to being returned to the container 142 for recirculation. For example, the drilling fluid may pass through a choke manifold 168 (e.g., a rig choke manifold, well control choke manifold) and then through the drilling fluid reconditioning equipment 170. The choke manifold 168 may include at least one choke and a plurality of fluid valves (neither shown) collectively operable to control the flow through the choke manifold 168. Backpressure may be applied to the annulus 108 by variably restricting flow of the drilling fluid or other fluids flowing through the choke manifold 168.

Before being returned to the container 142, the drilling fluid returning to the wellsite surface 104 may be cleaned and/or reconditioned via drilling fluid reconditioning equipment 170, which may include one or more of liquid gas separators (e.g., a poor boy separator 171), shale shakers 172, centrifuges, and other drilling fluid cleaning, reconditioning, and/or other processing equipment 173. The liquid gas separators may remove mud gasses entrained in the drilling fluid discharged from the wellbore 102 and the shale shakers 172 may separate and remove solid particles 141 (e.g., drill cuttings) from the drilling fluid into a solids container 143 (e.g., a reserve pit). The drilling fluid reconditioning equipment 170 may further comprise equipment 173 operable to remove additional gas and finer formation cuttings from the drilling fluid and/or modify physical properties or characteristics (e.g., rheology) of the drilling fluid. For example, the drilling fluid reconditioning equipment 170 may include a degasser, a desander, a desilter, a mud cleaner, and/or a decanter, among other examples. Intermediate tanks/containers (not shown) may be utilized to hold the drilling fluid while the drilling fluid progresses through the various stages or portions of the drilling fluid reconditioning equipment 170. The cleaned/reconditioned drilling fluid may be transferred to the fluid container 142, the solid particles 141 removed from the drilling fluid may be transferred to the solids container 143, and/or the gas removed from the drilling fluid may be transferred to a flare stack 174 via a conduit 175 (e.g., a flare line) to be burned or to a container (not shown) for storage and removal from the wellsite.

Throughout different regions (e.g., the Middle East) cement pumps, tanks, and related equipment are commonly located about thirty meters or more away from well center. During a cement job, wellsite operators may install high-pressure jumper hoses between cement piping connections at an outer end of a catwalk and cement pumps. The wellsite operators may also install a hose, manifolds, and other equipment between the well center and the end of the cement piping along a catwalk ramp. Cement may then be pumped from the cement tanks, along the temporary hose on the ground, to the installed cement piping in the catwalk, through high-pressure swivel joints to the ramp (V-Door) section of the piping, then through the temporary hose and other equipment on the drill floor to the well center.

In a well control situation, normal pressure may be supplied from the rig mud pumps via permanently installed kill lines. Rig mud pumps are capable of generating between about 5,000 PSI and about 7,500 PSI, depending on the rig. However, well control pressure can reach pressures of up to about 15,000 PSI. In a well control event, where trapped pressure is greater than the pressure the rig mud pumps can generate, a cement pump may be used to kill the well. Such method may be known as an “emergency kill.” Cement pumps may normally generate pressures ranging between about 10,000 PSI and about 15,000 PSI. Because the cement pumps are located at such distances from the well center, a high-pressure kill hose may be temporarily installed between the cement pumps and the kill piping installed in the catwalk. A permanently installed high-pressure kill hose may extend from the rig end of the catwalk frame to a well BOP. The high-pressure kill hoses and the kill piping in the catwalk operate as the kill path for mud that is pumped by the cement pumps.

High-pressure hoses and piping, such as the high-pressure kill hoses and piping, are expensive and require re-certification and maintenance regardless of whether such hoses and piping are used. Furthermore, safety regulations mandate that high-pressure hoses and piping, and their connections, undergo pressure testing each time such high-pressure hoses and piping are disconnected. Furthermore, catwalks may be “shared” or swapped between different rigs. Some rigs may normally utilize manual or conventional catwalk and ramp systems. A hydraulic catwalk may be installed for special or otherwise selected operations. Also, a hydraulic catwalk may be uninstalled for maintenance and replaced with a manual catwalk. Because of regulations that mandate that piping is installed in the catwalk and ramp, wellsite operators maintain at least two sets of piping at the wellsite. The wellsite operators also take several hours to disconnect the original piping, reconnect the next set, and then pressure test the entire system.

The present disclosure is directed to an example implementation of a catwalk system comprising a ramp and base system that comprises high-pressure piping and is detachably connectable with a catwalk, which can be swapped out without having to disconnect the high-pressure piping. The catwalk system may, thus, permit having one set of piping at the wellsite, reduce installation time, and facilitate installation of another catwalk without having to reconnect and pressure test the piping.

FIG. 2 is a schematic view of an example implementation of a well construction system 200 (e.g., a drilling rig) comprising a tubular handling catwalk system 202 according to one or more aspects of the present disclosure. The well construction system 200 may comprise one or more features of the well construction system 100 shown in FIG. 1, including where indicated by the same numerals. The well construction system 200 may also be operable to perform processes of the well construction system 100. Accordingly, the following description refers to FIGS. 1 and 2, collectively.

The catwalk system 202 may be or comprise tubular handling equipment collectively operable to convey tubulars 201 (e.g., drill pipes, drill collars, casing joints, downhole tools, etc.) from the ground or ground level of the wellsite surface 104, to the rig floor 114, permitting the tubular handling assembly links 127 to grab and lift the tubulars 201 above the wellbore 102 for connection with previously deployed tubulars. The catwalk system 202 may have a horizontal portion and an inclined portion that extends between the horizontal portion and the rig floor 114. The catwalk system 202 may comprise a tubular handling catwalk 206 having a skate 221 movable along a channel or groove (not shown) extending longitudinally along the catwalk 206. The skate 221 may be operable to convey (e.g., push) the tubulars 201 to the rig floor 114. The skate 221 may be driven along the groove by a drive system (not shown), such as a pulley system or a hydraulic system. The catwalk system 202 may comprise one or more racks (not shown) configured to store and/or transfer the tubulars 201 to the catwalk 206.

The catwalk system 202 may comprise a catwalk suitcase 204 configured to support, connect with, or otherwise receive the tubular handling catwalk 206. The catwalk suitcase 204 may comprise a base 208 configured to be mounded or otherwise disposed at the ground level (e.g., on the ground) of the oil and gas wellsite 104 and to receive the catwalk 206. The base 208 may be configured to detachably connect with the tubular handling catwalk 206 received by the base 208. The base 208 may also or instead be configured to support the catwalk 206 thereon above the ground level of the oil and gas wellsite 104. The base 208 may be configured to receive one at a time a different tubular handling catwalk 206 (e.g., a manual catwalk, a hydraulically powered catwalk, an electrically powered catwalk, etc.) and to permit the received catwalk 206 to be swapped or replaced by another tubular handling catwalk 206. The received catwalk 206 may be replaced by a different catwalk 206 based on, for example, wellsite operations or type of tubulars 201 that are intended to be moved to or from the rig floor 114. The received catwalk 206 may also or instead be replaced by a different tubular handling catwalk 206 when the received catwalk 206 breaks down. Accordingly, the tubular handling catwalk 206 is a selected one of a plurality of tubular handling catwalks 206. The catwalk suitcase 204 may further comprise a ramp 210 (also known as a V-Door) connected with the base 208 and positioned in an inclined fashion (e.g., extending diagonally) between the base 208 and the rig floor 114 at the oil and gas wellsite 104. When the catwalk 206 is received by the base 208, the ramp 210 may facilitate movement of the tubulars 201 from the catwalk 206 to the rig floor 114.

The base 208 may comprise a horizontal portion 214 configured to be disposed on and extending substantially parallel to the ground level (e.g., the ground) of the oil and gas wellsite 104, and a vertical portion 216 connected with the horizontal portion 214 and extending substantially perpendicularly with respect to the ground level of the oil and gas wellsite 104. The ramp 210 may be pivotably connected with base 208 via a pivot joint 220 at an upper end of the vertical portion 216. The horizontal and vertical portions 214, 216 may define a space 218 configured to receive the catwalk 206 therein. When the catwalk 206 is received by the base 208 within the space 218, a powered skate 221 of the catwalk 206 can push the tubular 201 longitudinally along the catwalk 206 toward the ramp 210. After the tubular 201 contacts a lower portion of the ramp 210, the skate 221 may push the tubular 201 along the ramp 210 toward the rig floor 114 until an upper end (e.g., box end) of the tubular 201 extends above the rig floor 114.

The catwalk suitcase 204 may further comprise a plurality of fluid conduits 222, 224 extending longitudinally along at least a portion of the catwalk suitcase 204. The fluid conduits 222, 224 may extend longitudinally along the base 208 and/or ramp 210 between opposing ends of the base 208 and/or ramp 210. The fluid conduits 222, 224 may transfer or deliver to the wellbore 102 and/or the rig floor 114 one or more utilities that are utilized during operations of the well construction system 200.

One or more of the fluid conduits 222 may form at least a portion of the base 208, extending between a distal end of the base 208 away from the rig floor 114 and/or the wellbore 102 and a proximal end of the base 208 closest to the rig floor 114 and/or the wellbore 102. One or more of the fluid conduits 222 may terminate with a distal fluid coupler 226 and an opposing proximal fluid coupler 228. The fluid conduits 222 and couplers 226, 228 may be or comprise medium pressure (e.g., rated for 7,500 PSI or more) fluid conduits and couplers configured to convey kill weight fluid or other high density fluid to the annulus 108 of the wellbore 102 during well kill operations at the oil and gas wellsite 104. Thus, one or more of the fluid couplers 226 may be fluidly connected with one or more mud pumps 144 or other sources of the kill fluid via an intermediate fluid conduit 230 (e.g., pipe, hose, etc.) extending to such source of the kill fluid. One or more of the fluid couplers 228 may be fluidly connected with a kill port of the ported adapter 136 or another port connected with the annulus 108 via an intermediate fluid conduit 232 (e.g., pipe, hose, etc.) extending to such port. Accordingly, the fluid conduits 222 may be or comprise at least portions of emergency kill lines.

Furthermore, one or more of the fluid conduits 224 may form at least a portion of the base 208 and the ramp 210, extending between the distal end of the base 208 away from the rig floor 114 and/or the wellbore 102 and a proximal end of the ramp 210 closest to the rig floor 114 and/or the wellbore 102. One or more of the fluid conduits 224 may terminate with a distal fluid coupler 234 and an opposing proximal fluid coupler 236. The fluid conduits 224 and corresponding couplers 234, 236 may be or comprise high-pressure (e.g., rated for 15,000 PSI or more) fluid conduits and couplers configured to convey cement slurry from the ground level to the rig floor 114 during cementing operations at the oil and gas wellsite 104. Thus, one or more of the fluid couplers 234 may be fluidly connected with one or more cement pumps (not shown) via an intermediate fluid conduit 238 (e.g., pipe, hose, etc.) extending to such cement pumps, which may be located at the wellsite 104 at a distance from the rig floor 114. One or more of the fluid couplers 236 may be fluidly connected with a cement head 240 during cementing operations via an intermediate fluid conduit 242 (e.g., pipe, hose, etc.) extending to such cement head 240 located above or otherwise at the rig floor 114. Accordingly, the fluid conduits 224 may be or comprise at least portions of cement lines. The cement head 240 may be connected to a casing extending from the wellbore 102 and operated by a human operator 203 (e.g., a roughneck, a derrickman, etc.) during the cementing operations. The base 208 and the ramp 210, including the fluid conduits 222, 224, may be separate and distinct from the catwalk 206, permitting a mechanical interface with the rig floor 114 by the ramp 210 and a fluid connection between mud pumps 144 and the ported adapter 136 and between the cement pumps and the cement head 240 to be maintained while swapping out a catwalk 206.

FIGS. 3-9 are schematic views of an example implementation of a tubular handling catwalk system 300 according to one or more aspects of the present disclosure, which may be installed and utilized at or form a portion of a well construction system, such as the well construction systems 100, 200 shown in FIGS. 1 and 2, respectively. FIG. 3 shows a side view of the catwalk system 300 in a folded and disassembled operational stage, FIG. 4 shows a side view of the catwalk system 300 in an unfolded and assembled operational stage, and FIG. 5 shows a side view of the catwalk system 300 without a tubular handling catwalk. FIGS. 6 and 7 show an upper and bottom views, respectively, of the catwalk system 300 shown in FIG. 4. FIGS. 8 and 9 show proximal and distal end views, respectively, of the catwalk system 300 shown in FIG. 4. The catwalk system 300 may comprise one or more features and/or perform one or more operations of the catwalk system 202 shown in FIG. 2. Unless referring to a specific one or more of the FIGS. 1-9, the following description refers to FIGS. 1-9, collectively.

The catwalk system 300 may comprise a catwalk suitcase 304 and a tubular handling catwalk 306. The catwalk suitcase 304 may be configured to support, detachably connect with, and/or otherwise receive the tubular handling catwalk 306. The catwalk suitcase 304 may comprise a base 308 configured to be mounded or otherwise disposed on the ground level (e.g., the ground) of the oil and gas wellsite 104 and to receive the tubular handling catwalk 306. The base 308 may be configured to detachably connect with the catwalk 306 received by the base 308. The base 308 may also or instead be configured to support the catwalk 306 thereon above the ground level of the oil and gas wellsite 104. The catwalk suitcase 304 may further comprise a ramp 310 (also known as a V-Door) connected with the base 308 and operable to be positioned in an inclined fashion (e.g., extending diagonally) between the base 308 and the rig floor 114 at the oil and gas wellsite 104, as shown in FIG. 4. When the catwalk 306 is received by the base 308, the ramp 310 may facilitate movement of tubulars 301 (e.g., drill pipes, drill collars, casing joints, downhole tools, etc.) from the catwalk 306 to the rig floor 114.

The base 308 may comprise a horizontal portion 314 configured to be disposed on and extending substantially parallel to the ground level of the oil and gas wellsite 104, and a vertical 316 portion fixedly connected with the horizontal portion 314 and extending substantially perpendicularly with respect to the ground level of the oil and gas wellsite 104. The ramp 310 may be pivotably connected with base 308 via a pivot joint 320 at an upper end of the vertical portion 316. The horizontal and vertical portions 314, 316 of the base 308 may define a space 318 configured to receive the catwalk 306 therein. When the catwalk 306 is received by the base 308 within the space 318, as shown in FIG. 4, an upper surface 309 of the catwalk 306 is aligned with or adjacent to a lower end of the ramp 310. Accordingly, during operations, the catwalk 306 may receive a tubular 301 into a channel or groove 382 extending longitudinally along the upper surface 309 of the catwalk 306 and a powered skate 321 of the catwalk 306 may be operable to push the tubular 301 along the groove 382 toward the ramp 310. After the tubular 301 contacts the lower portion of the ramp 310, the skate 321 may push the tubular 301 upwardly along the ramp 310 toward the rig floor 114 until an upper end (e.g., box end) of the tubular 301 extends above the rig floor 114, as shown in FIG. 2. The tubulars 301 may be stored on and/or transferred onto the catwalk 306 via one or more tubular racks 307, which may be installed on one or both sides of the catwalk 306. For clarity and ease of understanding the tubular racks 307 are shown just on FIGS. 8 and 9.

The skate 321 may be operatively connected with or form a portion of a mechanical power system 360 operable to move the tubulars 301 along the catwalk 306 and the ramp 310. The mechanical power system 360 may be or comprise a winch system comprising a plurality of gears or pulleys 362 operable to transfer torque generated by a motor 364 to tension one or more belts, chains, or other lines 366. The line 366 may be connected with the skate 321 to transfer power from the motor 364 to the skate 321, thereby facilitating movement of the tubular 301. The mechanical power system 360 may be, for example, a fluid powered system comprising a hydraulic motor 364 or an electrically powered system comprising an electric motor 364.

The catwalk suitcase 304 may comprise a plurality of fluid conduits 322, 324 extending longitudinally along the base 308 and/or ramp 310 between opposing ends of the base 308 and/or ramp 310. For example, one or more fluid conduits 322 may form at least a portion of the base 308, extending between a distal end of the base 308 away from the rig floor 114 and/or wellbore 102, and a proximal end of the base 308 closest to the rig floor 114 and/or the wellbore 102. One or more of the fluid conduits 322 may terminate with a distal fluid coupler 326 and an opposing proximal fluid coupler 328. The fluid conduits 322 may be or comprise medium pressure (e.g., rated for 7,500 PSI or more) fluid conduits configured to convey a kill weight fluid during well kill operations at the oil and gas wellsite 104. Thus, one or more of the fluid couplers 326 may be fluidly connected with one or more mud pumps 144 via an intermediate fluid conduit 230 extending to the mud pumps 144. One or more of the fluid couplers 328 may be fluidly connected with a kill port of a ported adapter 136 or another port fluidly connected with an annulus 108 of the wellbore 102 via an intermediate fluid conduit 232 extending to such port.

Furthermore, one or more fluid conduits 324 may form at least a portion of the base 308 and the ramp 310, extending between the distal end of the base 308 (and the catwalk suitcase 304) away from the rig floor 114 and/or wellbore 102 and a proximal end of the ramp 310 (and the catwalk suitcase 304) closest to the rig floor 114 and/or wellbore 102. One or more of the fluid conduits 324 may terminate with a distal fluid coupler 334 and an opposing proximal fluid coupler 336. The fluid conduits 324 may be or comprise high-pressure (e.g., rated for 15,000 PSI or more) fluid conduits configured to convey cement slurry to the rig floor 114 during cementing operations at the oil and gas wellsite 104. Thus, one or more of the fluid couplers 334 may be fluidly connected with one or more cement pumps (not shown) via an intermediate fluid conduit 238 extending to such cement pumps, which may be located at the ground level of the wellsite 104 at a distance from the rig floor 114. One or more of the fluid couplers 336 may be fluidly connected with a cement head 240 during cementing operations via an intermediate fluid conduit 242 extending to the cement head 240 located above or otherwise at the rig floor 114. The fluid conduits 324 may also or instead be utilized to convey a kill weight fluid during well kill operations at the oil and gas wellsite 104. For example, if the kill weight fluid is intended to be conveyed to the wellbore 102 at high pressures (e.g., at 15,000 PSI or more), the cement pumps may be utilized to convey the kill weight fluid to the wellbore 102 via at least a portion of the fluid conduits 324.

The fluid conduits 324 may each comprise a plurality of distinct portions (e.g., pipes, hoses, etc.) that may be disconnected for transport, as shown in FIG. 3, and reconnected when the catwalk system 300 is being installed at the wellsite 104. A portion of the fluid conduits 324 may be connected with or form a portion of the ramp 310 and another (opposing) portion of the fluid conduits 324 may be connected with or form a portion of the base 308. During installation of the catwalk system 300, the ramp 310 may be unfolded or pivoted such that the ramp 310 is positioned in an inclined fashion extending diagonally between the base 308 and the drill rig floor 114, as shown in FIG. 4. The opposing portions of the fluid conduits 324 may be fluidly coupled via corresponding intermediate fluid conduit portions 325. The opposing portions of the fluid conduits 324 and the intermediate fluid conduit portions 325 may be fluidly connected via corresponding fluid couplers. The intermediate fluid conduit portions 325 may be or comprise high-pressure swivel joints (e.g., chicksan joints) or other fluid conduits (e.g., pipes, hoses, etc.). Thus, the opposing portions of the fluid conduits 324 and the intermediate fluid conduit portions 325 may collectively form the fluid conduits 324 extending along the base 308 and the ramp 310 from the ground level of the wellsite 104 to the rig floor 114.

The catwalk suitcase 302 may further comprise additional fluid conduits 327 (e.g., pipes, hoses, etc.) connected with or forming a portion of the ramp 310. The fluid conduits 327 may extend longitudinally between opposing ends of the ramp 310. The fluid conduits 327 may be connected with the fluid conduits 322, such as may permit fluids (e.g., cement slurry, hydraulic fluid, drilling mud, etc.) to be transferred along the fluid conduits 322, 327 between the ground level of the wellsite 104 and the rig floor 114 instead of such fluids being transferred to the ported adapter 136 via the fluid conduits 322. The fluid conduits 327 may be connected with the fluid conduits 322 via intermediate fluid conduits, such as the intermediate fluid conduit portions 325.

Although the catwalk suitcase 302 is shown comprising two of each of the fluid conduits 322, 324, 327, it is to be understood that the catwalk suitcase 302 may comprise other quantities of such fluid conduits 322, 324, 327. For example, the catwalk suitcase 302 within the scope of the present disclosure may comprise one, three, four, or more of each of the fluid conduits 322, 324, 327. The quantities of each of the fluid conduits 322, 324, 327 may be determined based on, for example, configuration of the well construction system 100, 200 (e.g., quantity of kill ports, quantity of casing heads, quantity of ports in the casing head, etc.) and/or operational parameters of the well construction system 100, 200 (e.g., intended flows of the kill fluid, the cement flurry, or another fluid, etc.).

The base 308 of the catwalk suitcase 304 may be skidded or otherwise comprise a skid 340 configured to facilitate transportation of the catwalk suitcase 304 and/or the catwalk system 300. The skid 340 may be fixedly connected with the horizontal portion 314 of the base 308 or otherwise integrated as part of the base 308. The catwalk 306 may be skidded or otherwise comprise a skid 342 configured to facilitate transportation of the catwalk 306. The skid 342 may be fixedly connected with the catwalk 306 or otherwise integrated as part of the catwalk 306. The skid 340 or another portion of the base 308 may be configured to be mounded or otherwise disposed on the ground level (e.g., the ground) of the oil and gas wellsite 104 and to receive the skid 342 or another portion of the catwalk 306. The skids 340, 342 may permit the catwalk suitcase 304 and the catwalk 306, respectively, to be mounted on a trailer, such as may permit transportation to the wellsite 104 and/or to be moved and installed at the wellsite 104. The skids 340, 342 may be constructed pursuant to International Organization for Standardization (ISO) specifications, permitting the catwalk suitcase 304 and/or the catwalk 306 to be transported like an intermodal ISO container.

The base 308 may be configured to support the catwalk 306 thereon above the ground level of the oil and gas wellsite 104. The base 308 may also or instead be configured to detachably connect with the skid 342 or another portion of the catwalk 306 received by the base 308. For example, the base 308 and the catwalk 306 may be detachably connected together via a plurality of pins or bolts 344 extending between and at least partially through the base 308 and the catwalk 306, thereby preventing relative movement therebetween.

The base 308 of the catwalk suitcase 304 may comprise a frame assembly 370 supporting or otherwise connected with the fluid conduits 322, 324 extending along the frame assembly 370. The fluid conduits 322, 324 may be connected with the frame assembly 370 via a plurality of brackets 372 connected with the frame assembly 370. The skid 340 may be connected with or form at least a portion of the frame assembly 370. Similarly, the ramp 310 of the catwalk suitcase 304 may comprise a frame assembly 374 supporting or otherwise connected with the fluid conduits 324 extending along the frame assembly 374. The fluid conduits 324 may be connected with the frame assembly 374 via a plurality of brackets 376 connected with the frame assembly 374. The catwalk 306 may also comprise a frame assembly 390 supporting or otherwise connected with the upper surface 309 and the mechanical power system 360. The skid 342 may be connected with or form at least a portion of the frame assembly 390. The frame assemblies 370, 374, 390 may be or comprise a plurality of interconnected structural steel members or beams (just a few shown in FIGS. 7 and 8 for clarity) connected with the fluid conduits 322, 324, 327 and the mechanical power system 360, respectively. One or more of the frame assemblies 370, 374, 390 may at least partially extend about the fluid conduits 322, 324, 327 and the mechanical power system 360, such as to protect the fluid conduits 322, 324, 327 and the mechanical power system 360 from physical damage during transport, assembly, and operations, and to help facilitate transportation of the catwalk suitcase 304 and the catwalk 306. The frame assembly 370 may be a load-bearing frame assembly operable to support the weight of the catwalk 306 received by the base 308. The frame assembly 374 may be a load-bearing frame assembly operable to support the weight of the tubulars 301 being moved along the ramp 310 toward the rig floor 114.

The ramp 310 may further comprise a slide 380 configured to facilitate sliding of tubulars 301 being moved from the catwalk 306 to the rig floor 114. The slide 380 may be or comprise a low friction surface configured to facilitate movement of the tubulars 301 being pushed by the skate 321 along the ramp 310 to the rig floor 114. For example, after a tubular 301 is received within the groove 382 of the catwalk 306, the lower (i.e., pin) end of the tubular 301 may be pushed by the skate 321 causing the upper (i.e., box) end of the tubular 301 to slide upwardly along the slide 380 toward the rig floor 114. After the skate 321 reaches the end of travel and the upper end of the tubular 301 is at the rig floor 114, as shown in FIG. 2, lifting equipment, such as an elevator 129 of a top drive 116 or a pipe delivery arm (not shown), may lift the tubular 301, thereby causing the lower end of the tubular 301 to slide upwardly along the slide 380. The slide 380 may further comprise a longitudinal groove 384 configured to center or otherwise guide the tubular 301 while the tubular 301 slides along the slide 380. The ramp 310 may also comprise guide railings or other members 386 configured to maintain the tubulars 301 along or within the slide 380 of the ramp 308 while the tubulars 301 are transferred along the ramp 310 from the catwalk 306 to the rig floor 114.

As further shown in FIGS. 3-9, the catwalk suitcase 304 and/or the catwalk 306 may comprise a plurality of detachably connectable portions that may be transported individually and connected (i.e., assembled) together at the wellsite 104 to install the catwalk system 300 at the wellsite 104 as part of the well construction system 100, 200. For example, the base 308 may comprise first and second base portions 346, 348 that may be disconnected for transportation and connected together at the wellsite 104. Each base portion 346, 348 may comprise corresponding portions of the frame assembly 370, the fluid conduits 322, 324, and the skid 340. The first and second base portions 346, 348 may be connected via fasteners, such as pins or bolts 350, and the corresponding portions of the conduits 322, 324 may be connected together via corresponding fluid couplers 351. The catwalk 306 may comprise first and second portions 352, 354 that may be disconnected for transportation and connected together at the wellsite 104. Each portion 352, 354 of the catwalk 306 may comprise corresponding portions of the frame assembly 390, the skid 342, the upper surface 309, and the mechanical power system 360. The first and second portions 352, 354 of the catwalk 306 may be connected via fasteners, such as pins or bolts 356. The first and second portions 352, 354 of the catwalk 306 may also or instead be connected with the base 308 via the pins or bolts 344 to maintain relative position between the first and second portions 352, 354.

The catwalk suitcase 304 and the catwalk 306 may be transported while being detachably connected together, as shown in FIG. 3, or catwalk suitcase 304 and the catwalk 306 may be transported separately while disconnected from each other. The catwalk suitcase 304 may be transported while the ramp 310 is folded or pivoted against the base 308 and/or the catwalk 306, as shown in FIG. 3. During installation of the catwalk system 300, the ramp 310 of the catwalk suitcase 304 may be unfolded or pivoted such that the ramp 310 is positioned in an inclined fashion (e.g., extending diagonally) between the base 308 and the rig floor 114 at the oil and gas wellsite 104, as shown in FIG. 4. Furthermore, the separated portions of the catwalk suitcase 304 and/or the catwalk 306 may be connected together, as shown in FIGS. 4-9. Although the catwalk suitcase 304 and the catwalk 306 are shown each comprising two portions 346, 348 and 352, 354, respectively, that are connectable together, it is to be understood that catwalk suitcase 304 and/or the catwalk 306 may each be provided as single discrete units, wherein the portions 346, 348 of the catwalk suitcase 304 and portions 352, 354 of the catwalk 306 are each integrally formed or connected and, thereby, configured to be transported to and installed at the wellsite 104 as single discrete units without mandating an addition connection.

As described above, the base 308 may be configured to receive one at a time a tubular handling catwalk 306 and/or to detachably connect with the catwalk 306 received by the base 308. Accordingly, the base 308 may be configured to be disconnected from the received catwalk 306, permitting the catwalk 306 to be removed from the space 318, as shown in FIG. 5, and swapped or replaced by another tubular handling catwalk 306. The received catwalk 306 may be replaced by another and/or different catwalk 306 based on, for example, wellsite operational parameters or type of tubulars that are intended to be moved to or from the rig floor 114. The received catwalk 206 may also or instead be replaced by another catwalk 306 when the received catwalk 306 breaks down. Accordingly, the catwalk 306 received by the base 308 may be a selected one of a plurality of tubular handling catwalks 306. The base 308 and the ramp 310, including the fluid conduits 322, 324, may be separate and distinct from the catwalks 306, permitting a mechanical interface with the rig floor 114 by the ramp 310 and a fluid connection between mud pumps 144 and the ported adapter 136 and between the cement pumps and the cement head 240 to be maintained while swapping out a catwalk 306.

The present disclosure is further directed to an example implementation of a method or operation according to one or more aspects of the present disclosure. The method described below and/or other operations described herein may be performed utilizing or otherwise in conjunction with at least a portion of one or more implementations of one or more instances of the apparatus shown in one or more of FIGS. 1-9 and/or otherwise within the scope of the present disclosure. However, the method and operations described herein may be performed in conjunction with implementations of apparatus other than those depicted in FIGS. 1-9 that are also within the scope of the present disclosure. Accordingly, the following description refers to FIGS. 1-9, collectively.

The method may comprise installing a catwalk suitcase 304 at an oil and gas wellsite 104 such that a base 308 of the catwalk suitcase 304 is disposed at a ground level of the oil and gas wellsite 104 and a ramp 310 of the catwalk suitcase 304 extends to a drill rig floor 114 of a drill rig, detachably connecting a tubular handling catwalk 306 with the base 308, and moving tubulars 301 from the tubular handling catwalk 306 to the drill rig floor 114 via the ramp 310, as shown in FIGS. 2 and 4.

The method may further comprise disconnecting the tubular handling catwalk 306 from the base 308 and removing the tubular handling catwalk 306 from the space 318, as shown in FIG. 5, detachably connecting another tubular handling catwalk 306 with the base 308, and moving tubulars 301 from the another tubular handling catwalk 306 to the drill rig floor 114 via the ramp 310.

The catwalk suitcase 304 may comprise a fluid conduit 322 connected with and extending along the base 308, a fluid conduit 327 connected with and extending along the ramp 310, and/or a fluid conduit 324 connected with and extending along the base 308 and ramp 310. The method may thus further comprise conveying a kill weight fluid via the fluid conduit 322 to a wellbore 102 at the oil and gas wellsite 104 during well kill operations, as shown in FIG. 2. The method may also or instead comprise conveying a cement slurry via the fluid conduit 327 to a cement head 240 at the drill rig floor 114 during cementing operations. The method may also or instead comprise conveying a cement slurry via the fluid conduit 324 to a cement head 240 at the drill rig floor 114 during cementing operations, as shown in FIG. 2.

In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces an apparatus comprising: a base configured to receive a tubular handling catwalk; and a ramp connected with the base and configured to extend diagonally to a drill rig floor located at an oil and gas wellsite, wherein the ramp is configured to facilitate movement of tubulars from the tubular handling catwalk to the drill rig floor.

The apparatus may comprise the tubular handling catwalk configured to be received by the base.

The tubular handling catwalk may be one of a plurality of tubular handling catwalks, and the base may be configured to receive each tubular handling catwalk one at a time.

The base may be configured to be disposed at ground level of the oil and gas wellsite.

The base may be configured to detachably connect with the tubular handling catwalk.

The base may be configured to detachably connect with a skid of the tubular handling catwalk.

The base may be configured to support the tubular handling catwalk thereon.

The base may comprise: a horizontal portion configured to be disposed at ground level of the oil and gas wellsite; and a vertical portion fixedly connected with the horizontal portion, wherein the ramp is connected with an upper end of the vertical portion, and wherein the horizontal and vertical portions define a space configured to receive the tubular handling catwalk.

The base may comprise a skid configured to facilitate transportation of the apparatus.

The ramp may be pivotably connected with the base.

The ramp may comprise a slide configured to facilitate sliding of the tubulars from the tubular handling catwalk to the drill rig floor.

The base may comprise a frame and a fluid conduit extending along the frame. The fluid conduit may be configured to convey a kill weight fluid during well kill operations at the oil and gas wellsite.

The ramp may comprise a frame and a fluid conduit extending along the frame of the ramp. The fluid conduit may be configured to convey a cement slurry from a ground level of the oil and gas wellsite to the drill rig floor during cementing operations at the oil and gas wellsite.

The apparatus may comprise a fluid conduit connected with and extending longitudinally along the base and ramp. The fluid conduit may be configured to convey a cement slurry from a ground level of the oil and gas wellsite to the drill rig floor during cementing operations at the oil and gas wellsite. The fluid conduit may be configured to convey a kill weight fluid during well kill operations at the oil and gas wellsite.

The present disclosure also introduces an apparatus comprising a catwalk suitcase comprising: a base configured to detachably connect with a tubular handling catwalk; a ramp connected with the base and configured to extend to a drill rig floor located at an oil and gas wellsite, wherein the ramp is configured to facilitate movement of tubulars from the tubular handling catwalk to the drill rig floor; and a plurality of fluid conduits connected with and extending along the base and/or ramp.

The apparatus may comprise the tubular handling catwalk configured to detachably connect with the base.

The tubular handling catwalk may be one of a plurality of tubular handling catwalks, and the base may be configured to detachably connect with each tubular handling catwalk one at a time.

The base may be configured to be disposed at ground level of the oil and gas wellsite.

The base may be configured to detachably connect with a skid of the tubular handling catwalk.

The base may be configured to support the tubular handling catwalk thereon.

The base may comprise: a horizontal portion configured to be disposed at ground level of the oil and gas wellsite; and a vertical portion fixedly connected with the horizontal portion, wherein the ramp is connected with an upper end of the vertical portion, and wherein the horizontal and vertical portions define a space configured to receive the tubular handling catwalk.

The base may comprise a skid configured to facilitate transportation of the catwalk suitcase.

The ramp may be pivotably connected with the base.

The ramp may comprise a slide configured to facilitate sliding of the tubulars from the tubular handling catwalk to the drill rig floor.

The base may comprise a base frame, and at least one of the fluid conduits may be connected with and extend along the base frame. The ramp may comprise a ramp frame, at least one of the fluid conduits may be connected with and extend along the ramp frame, and at least one of the fluid conduits of the base and at least one of the fluid conduits of the ramp may be connected. The at least one of the fluid conduits of the base and the at least one of the fluid conduits of the ramp may be configured to convey a cement slurry during cementing operations at the oil and gas wellsite.

At least one of the fluid conduits may be configured to convey a cement slurry from ground level of the oil and gas wellsite to the drill rig floor during cementing operations.

At least one of the fluid conduits may be configured to convey a kill weight fluid during well kill operations at the oil and gas wellsite.

The present disclosure also introduces a method comprising: installing a catwalk suitcase at an oil and gas wellsite such that a base of the catwalk suitcase is disposed at a ground level of the oil and gas wellsite and a ramp of the catwalk suitcase extends to a rig floor of a drill rig; detachably connecting a tubular handling catwalk with the base; and moving tubulars from the tubular handling catwalk to the rig floor via the ramp.

The method may further comprise: disconnecting the tubular handling catwalk from the base; detachably connecting another tubular handling catwalk with the base; and moving tubulars from the another catwalk to the rig floor via the ramp.

The catwalk suitcase may comprise a fluid conduit connected with and extending along the base, and the method may further comprise conveying a kill weight fluid via the fluid conduit during well kill operations.

The catwalk suitcase may comprise a fluid conduit connected with and extending along the ramp, and the method may further comprise conveying a cement slurry via the fluid conduit during cementing operations.

The catwalk suitcase may comprise a fluid conduit connected with and extending along the base and the ramp, and the method may further comprise conveying a cement slurry via the fluid conduit during cementing operations.

The foregoing outlines features of several implementations so that a person having ordinary skill in the art may better understand the aspects of the present disclosure. A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same functions and/or achieving the same benefits of the implementations introduced herein. A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions, and alterations herein without departing from the spirit and scope of the present disclosure.

The Abstract at the end of this disclosure is provided to comply with 37 C.F.R. § 1.72(b) to permit the reader to quickly ascertain the nature of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

Claims

1. An apparatus comprising:

a base configured to receive a tubular handling catwalk; and

a ramp connected with the base and configured to extend diagonally to a drill rig floor located at an oil and gas wellsite, wherein the ramp is configured to facilitate movement of tubulars from the tubular handling catwalk to the drill rig floor.

2. The apparatus of claim 1 wherein the tubular handling catwalk is one of a plurality of tubular handling catwalks, and wherein the base is configured to receive each tubular handling catwalk one at a time.

3. The apparatus of claim 1 wherein the base is configured to detachably connect with the tubular handling catwalk.

4. The apparatus of claim 1 wherein the base is configured to support the tubular handling catwalk thereon.

5. The apparatus of claim 1 wherein the base comprises:

a horizontal portion configured to be disposed at ground level of the oil and gas wellsite; and

a vertical portion fixedly connected with the horizontal portion, wherein the ramp is connected with an upper end of the vertical portion, and wherein the horizontal and vertical portions define a space configured to receive the tubular handling catwalk.

6. The apparatus of claim 1 wherein the base comprises:

a frame; and

a fluid conduit extending along the frame.

7. The apparatus of claim 6 wherein the fluid conduit is configured to convey a kill weight fluid during well kill operations at the oil and gas wellsite.

8. The apparatus of claim 1 wherein the ramp comprises:

a frame; and

a fluid conduit extending along the frame of the ramp.

9. The apparatus of claim 8 wherein the fluid conduit is configured to convey a cement slurry from a ground level of the oil and gas wellsite to the drill rig floor during cementing operations at the oil and gas wellsite.

10. The apparatus of claim 1 further comprising a fluid conduit connected with and extending longitudinally along the base and ramp.

11. The apparatus of claim 10 wherein the fluid conduit is configured to convey a cement slurry from a ground level of the oil and gas wellsite to the drill rig floor during cementing operations at the oil and gas wellsite.

12. An apparatus comprising:

a catwalk suitcase comprising: a base configured to detachably connect with a tubular handling catwalk; a ramp connected with the base and configured to extend to a drill rig floor located at an oil and gas wellsite, wherein the ramp is configured to facilitate movement of tubulars from the tubular handling catwalk to the drill rig floor; and a plurality of fluid conduits connected with and extending along the base and/or ramp.

13. The apparatus of claim 12 wherein the base comprises:

a horizontal portion configured to be disposed at ground level of the oil and gas wellsite; and

a vertical portion fixedly connected with the horizontal portion, wherein the ramp is connected with an upper end of the vertical portion, and wherein the horizontal and vertical portions define a space configured to receive the tubular handling catwalk.

14. The apparatus of claim 12 wherein at least one of the fluid conduits is configured to convey a kill weight fluid during well kill operations at the oil and gas wellsite.

15. The apparatus of claim 12 wherein at least one of the fluid conduits is configured to convey a cement slurry from ground level of the oil and gas wellsite to the drill rig floor during cementing operations.

16. A method comprising:

installing a catwalk suitcase at an oil and gas wellsite such that a base of the catwalk suitcase is disposed at a ground level of the oil and gas wellsite and a ramp of the catwalk suitcase extends to a rig floor of a drill rig;

detachably connecting a tubular handling catwalk with the base; and

moving tubulars from the tubular handling catwalk to the rig floor via the ramp.

17. The method of claim 16 further comprising:

disconnecting the tubular handling catwalk from the base;

detachably connecting another tubular handling catwalk with the base; and

moving tubulars from the another catwalk to the rig floor via the ramp.

18. The method of claim 16 wherein the catwalk suitcase comprises a fluid conduit connected with and extending along the base, and wherein the method further comprises conveying a kill weight fluid via the fluid conduit during well kill operations.

19. The method of claim 16 wherein the catwalk suitcase comprises a fluid conduit connected with and extending along the ramp, and wherein the method further comprises conveying a cement slurry via the fluid conduit during cementing operations.

20. The method of claim 16 wherein the catwalk suitcase comprises a fluid conduit connected with and extending along the base and the ramp, and wherein the method further comprises conveying a cement slurry via the fluid conduit during cementing operations.