DIVERLESS SUBSEA HOT TAP SYSTEM WITH LATERAL PIPE TIE-IN

Abstract: A diverless process of tapping a pressurized subsea pipeline (12) without removing the pipeline from service. The process includes the steps of lowering and landing a measurement tool (30) onto the pipeline in order to check ovality and straightness of the pipeline. Pipe lift frames (36, 38) are lowered and landed onto the pipeline spaced from a chosen location. The pipeline is lifted by hydraulic actuators or mechanical screws on the lift frames. A hot tap machine and accompanying orientation frame are lowered from the surface and landed on the pipeline between the pipe lift frames. A fitting clamp is secured to the pipeline. A hot tap machine (60) is lowered onto the hot tap fitting and orientation frame(62). The pipeline is then tapped with the hot tap machine.

Description: DIVERLESS SUBSEA HOT TAP SYSTEM WITH LATERAL PIPE TIE-IN BACKGROUND OF THE INVENTION 1. Field of the Invention. The present invention relates to a diverless process for tapping a pressurized subsea pipeline without removing the pipeline from service. This diverless process utilizes specialty clamping equipment, tapping equipment and remote operating vehicles for operating at water depths beyond that accessible by divers. 2. Prior Art. Various kinds of underwater pipeline work have been carried out using divers equipped with various tools. Deep water conditions entail high subsea pressure and dangerous conditions. Manned or diver equipped operations are not suitable if the pipeline is at a depth which is inaccessible by divers. Remote operating vehicles perform visual and operational functions that are more limited than those functions performed by divers. To compensate for this limitation, processes must be developed to adapt the available technology to the work requirements. These processes are typically referred to as "diverless". Developed diverless processes are easily adapted for use using divers and/or control from the sea surface in diver accessible water depths. It has been proposed in the past to utilize a diverless underwater pipe tap system. De Sivry et al. (USPN 4,443,129) discloses an example of a diverless underwater pipe tap system including a lifting device to engage and displace the pipe, a working platform installed vertically above the tapping region and various tools used to carry out operations including concrete stripping, ovality or roundness measurement, and a tapping operation. De Sivry et al. contemplates cutting out a section of the pipeline. There is no disclosure or suggestion of a tap procedure while the pipeline is under pressure and de Sivry would not be suitable for such an operation. Likewise, various hot tap machines for tapping into a pipeline while the pipeline is pressurized have been disclosed. Reneau et al. (USPN 4,223,925) discloses one example of a hot tap machine for an underwater pipeline. It is advantageous to perform work on the pipeline without interrupting the flow of liquids or gases therethrough. It is also known to provide a remote operated subsea vehicle (ROV) controlled from the surface which includes thrusters or other mechanisms for propelling it through the water in response to a source of power at or controlled from the surface. Brooks et al. (Re27,745) illustrates an example of a submersible wireline robot unit that may be controlled remotely. None of the foregoing would be suitable for deep water conditions where the external subsea pressure is extreme. Given that the life spans of certain deep water oil and gas developments will be coming to an end in the near future, there will be an increasing number of existing pipelines which have excess transport capacity, thereby leaving excess pipeline infrastructure in deep water locations. If production from new fields can be tied into existing pipelines, then the investment in the pipeline can be spread out over more than one development. A diverless hot tap capability would allow the extension of pipelines from new fields to be connected to existing pipelines. This will reduce the overall length of the pipeline required to support a new field. It would also be possible to lay new trunk lines into areas in order to support multiple future field developments which would use lateral pipelines without having to pre-install connection facilities and valves at predetermined locations along the pipeline. Additionally, in deep water oil and gas developments, the cost of the pipeline infrastructure is estimated to be the majority of the cost of all of the installed subsea equipment. As an alternative to diverless hot tap systems, it would be possible to take an existing line out of service, cut a section of the pipeline and bring it to the surface, install a valve, lower the section back to the bottom and reconnect with a suitable jumper. Such an approach is not only time-consuming but requires the pipeline to be out of service. It would also be possible to pre-install blind branch connection facilities in the pipeline for future tie- ins. A disadvantage is that a great number of branch facilities would have to be installed to cover all possible future tie-in locations, a procedure that would be both time-consuming and expensive. Notwithstanding the foregoing, there remains a need for a diverless process of tapping a deep water subsea pipeline under high pressure without removing the pipeline from service. SUMMARY OF THE INVENTION The invention described herein is a diverless process for tapping into a deep water, pressurized subsea pipeline without removing the pipeline from service. This invention provides a method to hot tap into an existing subsea pipeline and connect a second, or multiple, pipelines by means of a horizontal pull-in and connection process. The initial phase will be locating a desired position of the hot tap along the pipeline and determining the in-situ conditions at that location. Various means such as subsea cameras, side-scan sonar, towed vehicles and remotely operated vehicles (ROV) may be used to locate and identify an area of interest. A preferred location on the pipeline will be indicated by the absence of any circumferential or longitudinal welds. After the desired area of interest and pipe section have been located, it may be necessary to excavate soil, sand or silt from underneath the pipeline to provide access for the hot tap equipment. A work-class ROV may be used to blow away the soil, sand or silt or a suction dredge may be used to remove it, thereby creating an excavated area for installing the hot tap equipment. It may then be necessary for the ROV to clean the pipeline using a hydraulically operated brush or low pressure water jet. In the next stage, two or more pipe lifting frames will be lowered from the surface and aligned by the ROV to straddle the pipeline during positioning. The lifting frames will be spaced at appropriate positions along the pipeline to effectively lift the pipeline without exceeding its plastic limit or otherwise damaging the pipeline. The distance between, and the number of lifting frames required, will be dependent upon the pipe size, wall thickness, internal pressure, soil conditions and other site-specific parameters. Each of the lifting frames incorporates a pipe grip mechanism that can move transverse or perpendicular to the axis of the pipeline and lowered onto the pipeline using hydraulic supply and controls provided by the ROV. The pipe lifting frames are also fitted with mud mats that may be extended or retracted by the ROV to provide sea bed stability. After the lifting frame is positioned over the pipeline at the desired location, the pipe grip mechanism is lowered onto the pipeline using the ROV hydraulic supply and controls. After the pipe grip is lowered and brought into contact with the pipeline, the grip mechanism is closed securely around it and hydraulically locked. The pipe grip mechanism, then supporting the pipeline, is raised to the desired height above the sea bed by the ROV using a mechanical jack screw device or hydraulic means. The second pipe lifting frame is landed and operated in a similar manner so that the pipeline is supported by at least two lifting frames. When the pipeline has been raised to the desired height by the pipe lifting frames, a measurement tool will be lowered from the surface on to the pipeline to check pipe roundness, ovality and axial alignment or straightness. The measurement tool will be guided into position and then powered and controlled by the ROV. After the pipeline has been checked for ovality and straightness, the measurement tool will inspect the pipeline condition at the desired hot tap area and note any anomalies or welds in the area. In the event that the pipeline contains a longitudinal weld that would affect the sealing area, a weld bead removal tool will be lowered from the surface and guided onto the pipeline by the ROV. The ROV will then operate the weld bead removal tool to machine the weld flush with the pipe surface. In the next stage, a pipe fitting frame assembly will then be lowered over the pipeline at the desired hot tap location. The pipe fitting frame assembly will include a hot tapping machine pre-installed at surface level on a hot tap fitting clamp by means of a releasable connector. The hot tapping machine and hot tap fitting clamp are integrated together into the pipe fitting frame. The hot tap cutter will be in retracted position during lowering to preclude initial contact with, and possible damage to, the pipeline. After the pipe fitting frame has landed out on the pipeline, it is secured to the pipe by means of two ROV-operated pipe clamps located at opposite ends of the frame. Next, the hot tap fitting clamp is extended to the pipe and closed around it by means of ROV- supplied hydraulics and controls. After the hot tap clamp has been closed around the pipe, the ROV will tighten each of the clamp bolts. After the hot tap clamp has been securely tightened, the ROV will confirm that the hot tap isolation valve is open. Next, the ROV will perform an external seal test on the hot tap clamp and hot tapping machine assembly prior to making the hot tap. Following a successful external seal test, the ROV will operate the hot tapping machine to perform the hot tap. The hot tapping machine will tap the pipeline using its cutter mechanism. When the hot tap operation has been completed and confirmed, the ROV will close the hot tap isolation valve and unlatch the hot tapping machine from the releasable connector hub which is located outboard of the hot tap isolation valve. The hot tapping machine and its support frame will then be retrieved to the surface. In the next stage, a lateral pipe connector guide is lowered from the surface and guided into alignment stabs fixed to the pipe fitting frame. After the lateral pipe connector guide has landed out and secured to the pipe fitting frame, the ROV will pay out two pull-in cables from hydraulic winches mounted on the frame and attach them to the lateral pipe connector pull-in skid. The ROV then operates hydraulic winches to pull in the lateral pipeline connector to a position near the mating face of the releasable connector hub. Next, the ROV will stroke the lateral pipe connector to seat against the mating hub and sequentially lock the connector to the hub. To ensure the connector is locked and to confirm the sealing integrity of the connection, the ROV will perform a final external seal test. Following a successful external seal test, the ROV then opens the hot tap isolation valve which permits product flow to the lateral pipeline system. Finally, after the pipeline has been connected and tested, the lateral pipe connector guide and associated equipment are retrieved to the surface. An alternate method of the embodiment is now described. During the initial stages of the process, a pipeline will be located and a preliminary visual condition inspection will be conducted through use of cameras. Cameras would be incorporated in a remote operating vehicle which is known in various configurations. The pipeline will be inspected in the area of interest and a pipe section will be identified. If the pipe contains a longitudinal weld or seam, the location of the seam will be identified. It is preferred, but not required, to select a location where a weld seam is not cut out with the hole being bored into the pipe during the tapping operation. For seamless pipe, this step is ignored. Additionally, a location will be identified away from any circumferential weld so that no section of the hot tap fitting will be over a circumferential field weld joint. Soil will be excavated from underneath the pipeline at the chosen location to allow unrestricted installation of the tools. The remote operating vehicle will be utilized to remove soil from underneath the pipeline and create a hole or an exposed area. The pipeline will be cleaned using a brush and/or a low pressure water jet powered by the remote operating vehicle. Once the foregoing preliminary procedures have been completed, a measurement tool will be lowered from the surface on to the pipeline in order to check circumferential roundness or ovality of the pipeline while simultaneously checking the straightness of the pipeline. The measurement tool will be powered by the remote operating vehicle. A pair or more of pipe lift frames will be lowered from the surface to straddle the pipeline, the lift frames spaced as appropriate, along the pipeline axis, and on opposing sides of the hot tap location. Each pipe lift frame will include a pair of platforms containing screw or hydraulic mechanisms, located on each side of the pipeline, which are used to position and raise or lower a pipeline lifting tong. Between the pair of platforms is a transverse beam from which extends the pipe tong. Each pipe tong may be positioned transversely to the axis of the pipeline and lowered onto the pipeline using the hydraulic system from the remote operating vehicle or a mechanical screw. Each lift platform may also include a mud mat which is adjustable with respect to the lift frame. The lift frames will position the pipeline to a desired height in an even and incremental sequence by the aforementioned mechanical or hydraulic mechanisms contained in each of the platforms thereby creating an upward net force. The mechanisms are powered by the remotely operated vehicle (ROV) in the same manner as the aforementioned tong and its associated manipulation mechanism. Subsequently, the pipe tongs are mechanically locked onto the pipeline in an elevated position. After lifting the pipeline in preparation for installation of the hot tap fitting clamp assembly around the pipeline, the measurement tool will again be utilized to check the circumferential roundness or ovality and straightness of the pipeline. In the event the pipeline contains a longitudinal weld and it is deemed necessary to remove the protruding surface of the weld, a weld bead removal tool will be lowered from the surface and landed onto the pipeline. The remote operating vehicle will be docked into the weld bead removal tool and hydraulic and control connections will be made. The weld bead removal tool will remove any protrusion of the longitudinal weld by machining a section of the weld along the pipeline. In the next step of the sequence of the invention, a hot tap fitting clamp assembly and its associated orientation frame will be lowered from the surface and landed on top of the pipeline at the designated location between the lift frames. The hot tap fitting clamp assembly comprises the piping components for the lateral branch connection: a clamp with a branch port and with associated fasteners or studs, a valve having opening and closing features for the branch connection, and a connector hub for connection of the hot tapping machine and subsequently the lateral pipeline. These piping components are preassembled prior to being placed in the fitting and orientation frame. The orientation frame includes a plurality of mud mats to support the hot tap fitting clamp assembly and hot tapping machine in soft soils. These mud mats can be extended and retracted by either hydraulic cylinders or mechanical screws so as to level the frame and support the weight of the equipment. The mud mats may be articulated to aid in the transportation and launching of the orientation frame. Using the remote operating vehicle and its hydraulic system, the diverless hot tap fitting clamp assembly and orientation frame will be leveled. In a preferred embodiment, the fitting and orientation frame includes four uprights, each of which is parallel to the other and each of the uprights are perpendicular to the axis of the pipeline. The orientation frame includes level indicators to measure the tilt, if any, and make leveling adjustments to the frame. The orientation frame houses the hot tap fitting clamp assembly on supports designed to not obstruct the operation of closing the clamp body around the pipeline or rotation of the assembly about the pipeline. The hot tap fitting clamp assembly is made to surround the pipeline, in the closed position, by operating its own hydraulic pistons, or mechanical screws. A plurality of guide posts are lowered from the surface onto the uprights of the orientation frame. The guide posts serve to guide and retain the hot tapping machine to be described herein. The guide posts are different lengths to facilitate the landing of the equipment. The hot tap fitting clamp will be closed to surround the pipeline using hydraulic pistons or mechanical screws attached to the body of the clamp powered and controlled by the remote operating vehicle. The remote operating vehicle will also position the fasteners or studs for securing the body seals of the clamp. A torque tool or stud tensioning assembly will be lowered onto the guide posts, if not preinstalled with the hot tap fitting clamp assembly. The remote operating vehicle will be docked into the torque tool or stud tensioning assembly. Studs on the fitting clamp will thereafter be tightened by said torque tool or stud tensioning assembly. Upon completion of this operation, the torque tool or stud tensioning assembly will be retrieved to the surface. Using a hydraulic piston and pinion arrangement, or other hydraulic mechanism for imparting a rotary motion, the hot tap fitting clamp assembly, which includes a valve and connector hub for the branch connection, is rotated from a side orientation to an upright position with respect to the pipeline. In the upright position, the valve will be vertical and parallel to the uprights and the guide posts. The remote operating vehicle will actuate a grip and seal mechanism in the hot tap fitting clamp to lock the hot tap fitting clamp and to make a seal with the pipeline. Finally, the pipeline will be lowered by the pipe lift frames until the pipeline is supported on the orientation frame. The next operation describes a diverless method to connect the hot tapping machine to the hot tap fitting clamp assembly. The hot tap machine and its accompanying frame will be lowered onto the orientation frame through the use of the guide posts. The hot tap machine will be brought into position above and in approximate alignment with the lateral connection hub that is part of the hot tap fitting clamp assembly. The next operation involves the precision alignment of the connecting hubs (one on the hot tap fitting clamp assembly and one on the hot tap machine) and the landing of sealing surfaces so as to avoid damage in consideration of the weight of the equipment. The connectors are designed with various tapered surfaces to align the sealing faces as they are positioned for contact by the force of the weight of the top connector. An integral part of the connectors are hydraulic cylinders that control the final make-up of the two hubs. Additional hydraulic cylinders are used to latch and unlatch the hubs. An alternate method for lowering the hot tap machine onto the connecting hub would involve a plurality of pistons, or other hydraulic mechanisms, attached to the hot tap orientation frame and the hot tapping machine which will control the height and rate of descent of the hot tap machine with respect to the hot tap frame. Once the hot tap assembly has been set in position using the guide posts, the hot tap machine will be carefully lowered through use of the pistons, or other hydraulic mechanisms, on the hot tap frame and a seal will be made with the hub of the connector on the hot tap fitting clamp assembly. This method would allow for other styles of connectors that do not have the integral controlled landing features to be employed. The hot tap machine will tap the pipeline using its cutter mechanism by passing through the valve, in its opened position, and engaging the pipeline. Thereafter, the cutter of the hot tap machine and pipe coupon will be retracted and the valve will be closed. The pipe lift frames will then lower the pipeline and the accompanying fitting clamp back to the sea floor. A series of steps will be taken to connect a production branch line or extension of another pipeline to the lateral hub of the hot tap fitting clamp assembly on the existing pipeline. With the production branch line terminating in a second production hub and valve assembly, the distance and relative orientation between the hot tap fitting clamp assembly as assembled on the pipeline and with the upright valve and connector hub on the production branch line will be measured. A pipeline jumper which contains mating connector hubs for connection at each end will be built to match the dimensions. The jumper is then lowered and guided by the remote operating vehicle onto the mating hubs at each respective end by the methods previously described in the setting of the hot tapping machine. The jumper will be lowered until the sealing faces meet. After the jumper is connected, the various guide posts and the pipe lift frames will be retrieved to the surface. BRIEF DESCRIPTION OF THE DRAWINGS Figure 1 illustrates an underwater deep sea pipeline residing on a sea floor or sea bed prior to the application of the present invention; Figure 2 illustrates an example of a remote operating vehicle; Figure 3 illustrates a measurement tool used in the process of the present invention; Figure 4 illustrates installation of a pair of pipe lift frames, part of the process of the diverless hot tap system of the present invention; Figure 5 illustrates the pipe lift frame being lowered with accompanying mud mats retracted; Figure 6 illustrates the pipe lift frame landed out on the sea floor and positioned over the pipeline; Figure 7 illustrates the pipe lift frame clamped onto the pipeline and with the pipeline lifted off the sea floor for subsequent access; Figure 8 illustrates the optional weld bead removal process; Figure 9 illustrates the hot tap fitting frame being lowered with the hot tapping machine pre-installed on the frame; Figure 10 illustrates the hot tap fitting frame landed out on the sea floor and positioned over the pipeline and between the pipe lift frames; Figure 11 illustrates the pipe support clamps on both ends of the hot tap fitting frame closed around the pipeline; Figure 12 illustrates the hot tap fitting clamps being aligned and closed onto the pipeline; Figure 13 illustrates the hot tap clamps being tightened on the pipeline by the remote operating vehicle; Figure 14 illustrates the ROV operating the hot tap machine to make the pipeline hot tap; Figure 15 illustrates the hot tap machine being retrieved to the surface; Figure 16 illustrates the hot tap machine support frame being retrieved to the surface; Figure 17 illustrates the lateral pipe connector guide being lowered into position over the hot tap fitting frame guideposts; Figure 18 illustrates the lateral pipe connector guide landed out onto the hot tap fitting frame; Figure 19 illustrates the lateral pipeline connector and skid assembly being pulled in to close proximity of an isolation valve; Figure 20 illustrates the lateral pipeline connector aligned with and locked on to the isolation valve flange; and Figure 21 illustrates the lateral pipe connector guide released from the hot tap fitting frame and being retrieved to the surface. Figure 22 illustrates installation of a pair of pipe lift frames, part of the process of the diverless hot tap system of the present invention; Figure 22A is an enlarged view of one of the pipe lift frames, which is part of the process of the present invention; Figure 23 illustrates a weld bead removal tool on the pipeline, which is a part of the process of the present invention; Figure 24 illustrates installation of an orientation frame containing the assembly of hot tap fitting clamp, valve and connecting hub installed on the pipeline between the pipe lift frames; Figure 25 illustrates installation of the guide posts on the orientation frame and the use of a torque tool assembly to affix the hot tap fitting clamp on the pipeline; Figure 26 illustrates the hot tap fitting clamp and its repositioning from a side orientation to an upright orientation; Figure 26A illustrates an enlarged view of the orientation frame to show movement of its pipe supports. Figure 27 illustrates the lowering of a hot tap machine and accompanying frame onto guide posts of the orientation frame; Figure 28 illustrates the initial alignment of the connector hub on the hot tap fitting machine and the hub on the lateral connection of the hot tap fitting clamp assembly; Figure 29 illustrates the final alignment utilizing hydraulic pistons or other hydraulic mechanism, on the hot tap frame to lower the hot tapping machine onto the hub of the hot tap fitting clamp assembly; Figure 30 illustrates a production line and terminating production hub which will be connected to the pipeline; Figure 31 illustrates the attachment of a pig catcher or pig launcher to the production hub prior to connection of the production line to the pipeline; Figure 32 illustrates lowering of a jumper which is made to span between the production hub and the fitting clamp; Figure 33 illustrates lowering of the jumper in alignment with the production hub and the pipeline fitting clamp valve for use of the guide posts on the orientation frame and on the production frame; Figure 34 illustrates the final lowering through use of valves on a jumper frame to bring the jumper into sealing alignment; and Figure 35 illustrates the final connection of the jumper following which removal of the guide posts and pipe lift frames will be accomplished. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS The embodiments discussed herein are merely illustrative of specific manners in which to make and use the invention and are not to be interpreted as limiting the scope of the instant invention. While the invention has been described with a certain degree of particularity, it is to be noted that many modifications may be made in the details of the invention's construction and the arrangement of its components without departing from the spirit and scope of this disclosure. It is understood that the invention is not limited to the embodiments set forth herein for purposes of exemplification. Referring to the drawings in detail, Figure 1 illustrates a section of an underwater deep sea pipeline 12 residing on and supported by a floor 14 of a sea bed. Figure 1, thus, illustrates the pipeline 12 prior to application of the present invention. The pipeline 12 will consist of a number of sections joined together with a plurality of circumferential welds 16. Depending on the size of the pipeline and other factors, longitudinal welds (not seen) may also be encountered. Deep water locations, such as at 6,000 feet and below are known to produce high pressure conditions external to the pipeline, relative to the internal pressure of the pipeline. The present invention is adaptable to various diameter pipelines but is particularly useful for 10" to 20" diameter pipelines. A remote operating vehicle (ROV) 18, shown in Figure 2, will assist in performing many of the steps or operations to be described in the present invention. The remote operating vehicle 18 will be controlled and may be powered from the surface. Various unmanned ROV's are well known in the field. During the initial stages of the invention, the pipeline 12 will be located and a series of comprehensive procedures will be performed. Subsea cameras, side-scan sonar, towed vehicles and remotely operated vehicles (ROV) may be used to locate and identify an area of interest. A preliminary visual condition inspection will be conducted through the use of underwater cameras. The bottom conditions will be reported, the water current will be reported, the visibility surrounding the pipeline will be reported, the type of soil on the sea bed will be reported and the depth of the pipeline will be reported. Other survey information may be necessary and would be obtained. Additionally, the location of circumferential pipe seams and welds, if any, will be reported. The nature and condition of any coating on the pipeline, such as concrete or other material, will also be reported. The pipeline 12 will be inspected in the area of interest and a pipe section will be identified between circumferential pipe welds 16. A preferred location on the pipeline will be the absence of any longitudinal welds that, if present, may be later removed by a grinding tool or similar mechanism operated by the ROV. A circumferential weld 16 will be located and then a location along the pipeline will be located a short distance from the circumferential weld so that there will be no section of the hot tap fitting installed over or immediately adjacent to the circumferential weld. At the outset, soil, sand or silt will be excavated from underneath the pipeline 12 to allow unrestricted installation of tools to be described herein. In one operation, the remote operating vehicle 18 will employ a pump to create a jet of sea water to blow away sand or silt from underneath the pipeline and create an excavated or exposed area beneath the pipeline. Alternatively, the ROV 18 may employ a suction device to create the desired excavation. Therefore, the pipeline 12 at the selected location will be cleaned using a brush or low pressure water jet powered and operated by the ROV. In some instances, external protective pipeline coating, such as fusion bonded epoxy, concrete or cement and the like, will be required to be removed prior to the next stage. A number of devices have been developed and are available to remove these coatings, and their use is possible within the scope of this invention. Once the foregoing preliminary procedures have been completed, a measurement or metrology tool 30 as seen in Figure 3 will be lowered onto the pipeline 12 from the surface at the selected location in order to check the circumferential roundness of the pipeline while simultaneously checking the axial alignment or straightness of the pipeline. The measurement tool 30 will be guided into position by the ROV and powered and controlled by the ROV's systems through the surface operator. The measurement tool moves a probe and camera back and forth axially as well as around circumferentially on the pipe surface to measure ovality and check for surface imperfections. If the pipeline is determined to be within the tolerances of roundness and straightness, the measurement tool may be removed and returned to the surface. Alternatively, the measurement tool 30 may be left on, or adjacent to, the pipeline 12 for use in a later sequence in the operation. If the pipeline fails the roundness and straightness test at that location, the measurement tool 30 will be moved axially to another location on the pipeline 12 and the measurement tests will be performed again until a satisfaction location is found. As illustrated in Figure 4, after a suitable location along the pipeline 12 has been determined, a pair of pipe lifting frames, 36 and 38, will be lowered from the surface to straddle the pipeline 12. Figure 5 shows an enlarged drawing of one of the lifting frames 36 or 38, as it is being lowered into position. At least one pair of the pipe lifting frames will be utilized. In some applications, four lifting frames (only two shown) will be required to achieve the desired results. Each lifting frame 36 and 38 will include a pair of opposed structural guides 40 and 42 and a cross-frame 44 upon which is installed a ROV control panel 46. Extendable mud mats 48 and 50 are installed on each side of the lifting frame which can be rotationally extended to provide seabed support. In the present embodiment, the mud mats are positioned by hydraulic cylinders. Figure 5 shows the mud mats in the retracted, travel position. Between the vertical structural guides, 40 and 42, a transverse beam 52 is installed from which extends a pipe grip device 54. The pipe grip device 54 may be moved transversely or perpendicularly to the axis of the pipeline 12 and lowered onto the pipeline 12 by means of a hydraulic system provided by the remote operating vehicle 18 and controlled through the ROV control panel 46. The pipe grip device 54 may be brought to a desired height in an even and incremental sequence by the ROV-controlled hydraulic system 46 acting upon hydraulic cylinders or other extension mechanism (not shown) within the vertical structural guides, 40 and 42. Before lifting the pipeline 12, the mud mats 48 and 50 are hydraulically lowered into position to rest securely on the seabed, as seen in Figure 6. In the present embodiment, the mud mats are positioned by hydraulic cylinders. The pipe grip device includes a pair of jaws which pivot to open or close. Next, the pipe grip device 54 is opened and lowered down to engage the pipeline 12. After initial contact, the pipe grip device 54 is closed around the pipeline 12 and mechanically locked. The pipeline 12 may then be raised to the desired elevated position, as best seen in Figure 7. This same sequence of operations is then repeated on each of the other pipe lifting frame or frames. After both of the pipe lifting frames 36 and 38 have been installed as described and the pipeline 12 raised to the desired elevation, the measurement tool 30 will again be utilized to check the circumferential roundness and straightness of the pipeline 12. If the measurement tool has not remained on the pipeline 12, it will be reinstalled between pipe lifting frames 36 and 38. The remote operating vehicle 18 will be used to power and operate the measurement tool 30. The roundness and straightness of the pipeline will again be checked in order to determine any effects of the aforementioned pipe lifting sequence. If the pipeline 12 is within the desired tolerances, the measurement tool 30 will be removed and retrieved to the surface. If the pipeline fails the measurement check, the pipe lifting frames may be repositioned and a new location selected for the forthcoming hot tap. The next step in the sequence of the process, shown in Figure 8, will only be performed if the pipeline 12 contains a longitudinal weld. A weld bead removal tool 58 will be lowered from the surface and landed onto the pipeline 12 in a manner similar to the measurement tool. The remote operating vehicle (not seen) will be docked into the weld bead removal tool 58 and will remove any longitudinal weld by grinding or machining from the pipeline. Confirmation of the weld bead removal tool 58 will be made through a subsea camera. After satisfactory weld bead removal, the removal tool 58 will be removed from the pipeline 12 and retrieved to the surface. Prior to performing a subsea hot tap of the pipeline 12, a hot tap fitting frame (to be described in detail) will be inspected on the surface and prepared for operation. The various seals and slips of the hot tap machine and fitting frame will be inspected. When the hot tap machine is used with a ball valve, it will be connected and checked. The hot tap machine and pre-installed ball valve are then rigged for deployment. Figure 9 illustrates the next sequence in the process. A hot tap machine 60 installed on a fitting frame 62 together with the pre-installed ball valve 64 and pipe clamp 66 is lowered from the surface onto the pipeline 12. A hot tap machine support frame and horizontal structural guide 80 has also been mounted on the fitting frame 62 on the surface. Hydraulically-operated pipe supports 68 and 70 are located at each end of the fitting frame 62 to capture the pipeline 12 after the frame has landed out on the pipeline. The combined hot tap machine/ball valve/pipe clamp assembly is supported in a structural guide system (not shown) within the lifting frame 62 that may be moved horizontally away from the pipeline during lowering and land out. The pipe clamp 66 is open at this stage in order to accept the pipeline 12 in a subsequent step. Figure 10 illustrates the hot tap fitting frame 62 landed out on to the pipeline 12. The pipe supports 68 and 70 and the pipe clamp 66 are open and the hot tap machine/ball valve/pipe clamp assembly is retracted away from the pipeline 12 to prevent premature contact and possible damage to the pipeline 12. Each pipe support 68 and 70 includes a pair of U-shaped pieces that rotate between open and closed position. In Figure 11, the ROV 18 has closed the pipe supports 68 and 70 at both ends of the fitting frame 62 and extended the hot tap machine/ball valve/pipe clamp assembly horizontally to contact the pipeline 12. After the hot tap machine/ball valve/pipe clamp assembly has been extended to contact the pipeline 12, the ROV 18 hydraulically closes the pipe clamp 66 around the pipeline. Closing the pipe clamp 66 is accomplished in three steps - 1) the initial closing of the clamp 66; 2) subsequent tightening of the structural bolts along the side of the clamp 66; and 3) setting of the seals and packers by means of bolts at the end of the clamp 66. Other pipe clamp designs may embody alternate means to obtain the same required results (a structurally secure and leak-tight clamp) within the scope of this invention. Figure 12 illustrates the ROV 18 tightening the structural bolts along the side of the pipe clamp 66 using a hydraulically-operated torque tool (not shown). To ensure a positive leak-tight seal, the ROV 18 will be capable of monitoring grip displacement indicators and the pressure seal between the pipeline 12 and pipe clamp 66. In the next sequence as seen in Figure 13 , the ROV 18 operates the hot tap machine 60 using a cutter mechanism (not shown) to machine out the hot tap coupon. Prior to making the hot tap, the ROV 18 confirms that the pre-installed ball valve is in the "open" position. After making the hot tap, the hot tap cutter will be retracted through the ball valve 64 and the ball valve will be "closed" by the ROV 18. After the hot tap has been completed, the ROV 18 disconnects the hot tap machine 60 from the ball valve 64 as shown in Figure 14. This is accomplished by means of a mechanical (bolted flange or hub) or hydraulic connection between the ball valve 64 and hot tap machine 60. The present embodiment illustrates the use of a hub-type mechanical connection 20 which requires only 1 or 2 actuation screws to install. Figure 15 illustrates the hot tap machine 60 being retrieved to the surface. The ball valve 64 has been "closed" and the ROV 18 has checked the pipe clamp 66 and ball valve 64 for any leakage. Figure 16 illustrates the hot tap machine support frame and horizontal structural guide 80 being retrieved to the surface. This subassembly was supported and oriented by a plurality of vertical guideposts 82. An alternate configuration (not shown) wherein the hot tap machine, support frame and horizontal structural guide are integrated into a single system is within the scope of this invention. In the next sequence seen in Figure 17, a lateral spool connector guide 84 is lowered from the surface and stabbed over the pair of vertical guideposts 82. After initial guidance by the ROV, the lateral connector guide 84 lands out on the hot tap fitting frame structure 62. Figure 18 shows the lateral spool connector guide 84 completely landed out on the fitting frame structure 62. The guide 84 includes a pair of opposed walls.. As seen in Figure 19, after the lateral spool connector guide 84 has landed out on the hot tap fitting frame 62, a lateral spool sled 88, having a production or other branch pipeline 94, is brought in proximity with the structure 62. The ROV 18 pulls, in sequence, wires from a pair of small hydraulic winches 86 installed on the connector guide 84 out to a lateral spool sled 88 which has been positioned near the pipeline 12. The ROV 18 then attaches the wires to structural points 90 on the sled 88. Next, the ROV 18 actuates the hydraulic winches 86 to pull the lateral spool sled 88 to a position within the connector guide 84. From that position, the sled 88 is guided to a final position wherein a flowline connector 92 contacts a mating flange on the ball valve 64. The connecting pipeline, or spool 94 is connected to the existing pipeline 12 by means of the flowline connector 92. A series of steps will next be taken to connect the existing pipeline 12 into a production branch or other unpressurized pipeline 94 by means of the lateral spool tie-in to be described herein. In a preferred example, the following steps occur. As seen in Figure 20, after the flowline connector 92 has seated against a corresponding flange on the ball valve 64, the ROV 18 hydraulically actuates the connector 92 to firmly connect it to the ball valve. In the embodiment illustrated, a collet connector hydraulically locks the lateral spool to the ball valve 64 then seals off the lateral spool/connector hub interfaces. After this connection has been made, the ROV 18 will perform a leak test of the interface and "open" the ball valve 64 to permit fluid flow from the existing pipeline 12 through the pipeline system. After all checks and tests have been satisfactorily performed, the connector guide 84 is retrieved to the surface and recovered as seen in Figure 21. The foregoing describes connection of a production branch or other pipeline to the existing pipeline. Other configurations are possible within the scope of the invention. Once a suitable location on the pipeline 12 has been determined, a plurality of pipe lift frames, 120 and 122, will be lowered from the surface to straddle the pipeline as best seen in Figure 22. Figure 22 A shows an enlarged drawing of one such pipe lift frame 120. In the present embodiment, at least a pair of pipe lift frames 120 and 122 will be utilized. In some applications, four pipe lift frames (not shown) will be utilized to achieve the desired result. Each pipe lift frame 120 and 122 will include a pair of opposed support platforms 124 and 126 which will be lowered on opposite sides of the pipeline 12. Each platform contains hydraulic or screw mechanisms. Between the platforms 124 andl26 is a transverse beam 128 from which extends a pipe tong 130. Each pipe lift platform 124 and 126 may include a mud mat, lift bags (not shown in Figures 22 and 22A) or other methods of support. The pipe tongs 130 may be moved transversely or perpendicular to the axis of the pipeline 12 and lowered around the pipeline 12 using the hydraulic system from the remote operating vehicle 18. The lift frames 120 and 122 will be brought to a desired height in an even and incremental sequence by the lifting device 132 and 134 contained in each of the platforms 124 and 126. In one preferred method, the hydraulic devices include bags which are actuated with hydraulic power supplied by the remote operating vehicle 18 (not shown in Figure 22). Subsequently, the pipe tongs 130 are mechanically locked onto the pipeline 12 in the elevated position. Once the pipe lift frames 120 and 122 have been installed as described, the measurement tool 30 will then again be utilized to check the circumferential roundness or ovality and straightness of the pipeline. If the measurement tool has not remained on the pipeline 12, it will be reinstalled on the pipeline 12 between the lift frames 120 and 122. The remote operating vehicle will be docked into the measurement tool and the hydraulic and electronic control connections will be made. The roundness or ovality and straightness of the pipeline will again be checked in order to determine any effects of the foregoing pipe lifting on the pipe. If the pipeline 12 is within the desired tolerances, the measurement tool 30 will be removed. If the pipeline fails the check, the pipe lifting frames may be readjusted and a new location chosen for the forthcoming hot tap. The next step in the sequence shown in Figure 23 will only be performed if the pipeline contains a longitudinal weld. If deemed necessary, a weld bead removal tool 140 will be lowered from the surface and landed onto the pipeline 12 as shown in Figure 23. The remote operating vehicle 18 (not shown in Figure 23) will be docked into the weld bead removal tool 140 and the hydraulic and control connections will be made. The weld bead removal tool 140 will remove any protruding longitudinal weld by machining the weld bead from the pipeline 12. Thereafter, visual inspection through a camera will be made. Finally, the weld bead removal tool 140 will be removed from the pipeline and returned to the surface. The weld bead removal tool will be used in those instances where a longitudinal weld has been found and the tool must be removed prior to the hot tap to be performed. In a step to be performed prior to the tapping of the pipeline, a hot tap fitting clamp will be inspected and prepared for operation. The various seals on the hot tap fitting clamp will be checked. The hot tap fitting clamp will also be rigged for vertical orientation. The next step in the sequence of the invention is illustrated in Figure 24. The pipe lift frames 120 and 122 are lowered so that the pipeline 12 will likewise be lowered. A hot tap fitting and its associated orientation frame 148 will be lowered from the surface and landed on top of the pipeline 12 between the pipe lift frames 120 and 122. The frame 148 may include a pair of opposed mud mats 150 (one visible in Figure 4). The mud mats 150 are movable by hydraulic cylinders between an extended and retracted position. The mud mats will be placed in the retracted position during lowering. The mud mats 150 will be extended and lowered before final touchdown on the sea floor 14. The mud mats 150 will be operated by the remote operating vehicle hydraulic system. Thereafter, the pipe lift frames 120 and 122 will be raised until the pipeline 12 is fully seated in the saddles of the orientation frame 148. Using the remote operating vehicle hydraulics system, the orientation frame 148 will be leveled. Thereafter, the pipe lift frames 120 and 122 will be locked in place. In the present embodiment, the orientation frame 148 includes four uprights 142, 144, 146 and 147, each of which is parallel to the other. It will be appreciated that while a plurality of uprights is advantageous, the number is a matter of choice. The frame 148 also includes an associated hot tap fitting clamp assembly 154. The hot tap fitting clamp assembly comprises the piping components for the lateral branch connection: a clamp with a branch port and with associated fasteners or studs, a valve having opening and closing features for the branch connection, and a connector hub for connection of the hot tapping machine. The hot tap fitting clamp assembly 154 is lowered over the pipeline at the selected location. The fitting clamp 154 is initially closed using its own hydraulic pistons and a plurality of fasteners or studs are pushed in. The remote operating vehicle (ROV) 18 will initially be used to hydraulically close the fitting clamp around the pipeline. With reference to Figure 25, either before or after closing the fitting clamp 154, a plurality of guide posts 160, 162, 164 and 166 are lowered from the surface onto the uprights 142, 144, 146 and 147, respectively, of the orientation frame 148 to guide and retain. While the guide posts may be of various configurations, in the present embodiment they have frusto-conical shaped, open bases. The guide posts 160, 162, 164, and 166 are of uneven length allowing for easy landing of equipment. By stabbing one guide post at a time, the remote operating vehicle can guide the equipment into position. A torque tool or stud tensioning assembly 170 is seen being lowered from the surface into position in Figure 25. The remote operating vehicle 18 will be docked into the torque tool or stud tensioning assembly 170 and the hydraulic and electronic control connections will be made. The fasteners or studs on the hot tap fitting clamp 154 will thereafter be tightened by the torque tool or stud tensioning assembly. Once this operation has been completed, the torque tool assembly or stud tensioning assembly 170 will be retracted from the guide posts and returned to the surface. To facilitate the positioning of the hot tap fitting clamp on the pipeline as just described, a lateral connection valve 172 on the fitting clamp assembly 154 will be oriented in a side position. Stated in other words, the connection valve 172 will not be vertical to the sea floor 14. As shown in Figure 26, using a hydraulic piston and pinion or rotary actuator arrangement, the fitting clamp 154 will include a connection valve 172 which is rotated approximately ninety degrees (90°) from a side to an upright position. In the upright position, the valve will be vertical to the sea floor and parallel to the uprights and the guide posts. The hot tap fitting clamp and valve assembly will contain level indicators to verify that the valve is vertically oriented. These level indicators may be electronic transponders and/or visual scale measurement devices. Thereafter, the remote operating vehicle 18 will actuate a grip and seal mechanism between the fitting clamp and the pipeline 12. The remote operating vehicle (ROV) will be capable of monitoring grip displacement indicators and the pressure. The remote operating vehicle 18 will hot stab into a test port and pressurize it to a predetermined pressure to verify a seal between the fitting clamp 154 and the pipeline 12. Accordingly, the seal integrity is tested. A relative vacuum/pressure test is performed using a remote operating vehicle tool. When the test is performed with the valve closed, it verifies the integrity of the seal between the pipeline 12 and the fitting clamp 154, the longitudinal seals along the clamp body, and the seal of the valve for pipeline pressure. In the case of a vacuum test, the external pressure of the water depth is verified. Finally, as illustrated in Figure 26 A, opposed pipe supports 171 rotate about axes 173 (shown by dashed lines) to close to form U-shaped piece 174, the pipeline 12 will then be lowered by the pipe lift frames 120 and 122 until the pipeline 12 is supported on the orientation and fitting frame 148. The U-shaped piece 174 receives and supports the pipeline 12. The next step in the sequence of the present invention is illustrated in Figure 27. With the pipeline 12 lowered and supported by the orientation frame 148, a hot tap machine 190 and accompanying frame 192 (forming a hot tap assembly) is lowered from the surface onto the orientation frame 148 through use of the guide posts 160, 162, 164 and 166. The hot tap machine 190 and its frame 192 have been previously rigged together. The same guide post arrangement is used as described previously. The hot tap frame 192 includes receptacles 180, 182, 184 and 186 which are received on the guide posts 160, 162, 164 and 166. While the receptacles 180, 182, 184 and 186 may take various forms, in the present preferred embodiment, they are frusto-conical with open bases. The hot tap frame 192 may include a plurality of pistons or mechanical screws 194 which control the level of the hot tap machine 190 with respect to the frame. As seen in Figure 28, the hot tapping assembly will land on the orientation frame 148. Initially, no seal is made so that the hot tap machine 190 is prevented from accidentally being rammed against the fitting clamp 154. In Figure 28, the hot tap machine 190 is aligned with the connection valve 172. Thereafter, as seen in Figure 29, the pistons 194 on the hot tap frame 192 will be activated so that the hot tap machine 190 will be carefully lowered and a seal will be made between the hot tap machine 190 and the fitting clamp 154. The integrity of the seal will then be tested. If the aforementioned pressure test is conducted with the valve open, it tests the integrity of the connection between the hot tap machine 190 and fitting clamp 154 as well. The test medium is not water and is selected to avoid hydrate formation which occurs by a meta-stable combination of natural gas liquids and water at the ambient pressures and temperatures. The test medium utilized could be any of several different methods, such as glycol or methanol. It is introduced to the cavitie(s) by means of a low pressure pump which circulates inhibitor/test medium into the cavitie(s) and takes seawater returns into a holding tank. Once the seawater has been displaced by the inhibitor/test medium, the pressure test is conducted. The test is conducted by connecting a high pressure/vacuum pump to a cavity in the hot tap machine body. The pump will pressurize the cavity between the top of the ball-valve ball and the tap machine. A successful test verifies integrity of the seal between the hot tap machine and the male hub on the hot tap fitting. The ball valve is then opened and the test is repeated. A successful test verifies the sealing integrity of the entire system. The entire process is repeated with the pump in the vacuum mode. This verifies integrity of the sealing system when the hydrostatic (ambient) pressure is greater than the pipeline pressure. After a good test is attained, the tapping will proceed. The remote operating vehicle 18 will be docked into the control panel of the hot tap machine 190 and hydraulic and electronic connections made. The hot tap machine 190 will tap the pipe 12 using its cutter mechanism (not visible). Thereafter, the cutter mechanism and pipe coupon will be retracted through the valve 172 and the valve will be closed. If deemed necessary, the integrity of the seal of the valve will be verified by testing on the external pressure side of the valve (hot tap fitting machine side) with the valve in the closed position. Finally, the hot tap machine 190 and its accompanying frame 192 will be raised and recovered to the surface in a reverse procedure. The entire procedure is performed while the pipeline is operational. The internal pressure of the pipeline may be significantly above or in deep sea conditions, below, ambient pressure. If external pressure exceeds the internal pipeline pressure, it will be necessary to break the seal by pressuring the connection with the valve closed. The internal pressure would be raised to at least the external pressure so that there would be no external forces acting on the seal to prevent disconnection of the hot tapping machine. The hot tap fitting clamp 154 is then released from the uprighting mechanism. Thereafter, the pipe lift frames 120 and 122 will lower the pipe 12 and the accompanying hot tap fitting clamp assembly back toward the sea floor 14. The weight of the pipeline 12 and the fitting clamp 154 are taken up by the orientation frame 148. Accordingly, the weight will not be distributed on the hot tap fitting or on the pipeline. The orientation frame 148 is designed with sufficient dimensional tolerances so as to provide the required flexibility for the connection of the lateral pipeline and also provide support for the weight of the connecting pipeline in soft soils. A series of steps will next be taken to connect a production branch or other pipeline to the existing pipeline 12. In a preferred example to be discussed herein, a new production line 200, as seen in Figure 30, is tied in to the pipeline 12. The production line 200 terminates in a valve or upright production hub 202. The distance or relative orientation between the hot tap fitting as assembled and the valve hub 202 on the production line is measured. The pipe lift frames 120 and 122 may be removed at this time or, alternatively, may be removed at the end of the procedure. In Figure 31, a pig catcher 220 is guided onto the production hub so that the production line 200 may be pigged prior to completion, all as known in the art. A pair of guide posts 214 and 216 are lowered on the uprights. With reference to Figure 32, ajumper 230 is built to match the measured dimensions. The jumper 230 will be filled with methanol or glycol or a hydrate-inhibition fluid prior to being deployed subsea. The jumper 230 is then lowered and guided by the remote operating vehicle 18 using techniques for setting jumpers previously described. As seen in Figure 32, the jumper assembly 230 is held by jumper frame 232 and is lowered on to male end connectors (one at the connection for the hot tap and one on the lateral pipeline sled structure). The connecting devices on the jumper contain hydraulic pistons to land the female collet connector on the sealing faces in a method to prevent damage to the sealing faces. Finally, as seen in Figure 23 , hydraulic cylinders 236 gradually lower the jumper 230 until the sealing faces meet. Collet connectors then seal off the jumper valve/hub interfaces. Figure 34 shows the jumper 230 after it has been connected. In a final step, as seen in Figure 35 the guide posts 160, 162, 164, and 166, and the pipe lift frames 120 and 122 are retrieved to the surface. Whereas the present invention has been described in relation to the drawings attached hereto, it should be understood that other and further modifications, apart from those shown or suggested herein, may be made within the spirt and scope of this invention.

Claims: WHAT IS CLAIMED IS: 1. A diverless process of tapping a pressurized subsea pipeline without removing said pipeline from service, which process comprises: (a) lowering and landing a measurement tool onto said pipeline and checking roundness and straightness of said pipeline with said measurement tool; (b) lowering and landing at least a pair of pipe lift frames onto said pipeline; (c) lifting said pipeline by said pipe lift frames; (d) lowering and landing a combined hot tap fitting frame and hot tap machine onto said pipeline between said pipe fitting frames; (e) tapping said pipeline with said hot tap machine; and (f) lowering said pipeline with said pipe lifting frames. 2. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 1 including the steps of pre-installing said hot tap machine, a ball valve, and pipe clamp on said fitting frame prior to lowering and landing said frame. 3. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 1 including the additional preliminary steps of: (a) excavating from underneath said pipeline by using a remotely operated vehicle (ROV) to allow unrestricted installation of required tools; (b) cleaning off said pipeline using brushes or low pressure water jets; and (c) removing protective or external coatings from said pipeline. 4. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 1 including the additional steps prior to said lowering and landing of said hot tap fitting frame and hot tap machine of: (a) lowering and landing a weld bead removal tool onto said pipeline; and (b) grinding, milling or machining any weld beads from said pipeline. 5. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 1 wherein said step of lowering and landing a pair of pipe lifting frames onto said pipeline includes the additional steps of: (a) lowering and landing each pipe lifting frame at a prescribed spacing from a selected hot tap location; (b) rotating a plurality of mud mats on said pipe lifting frames from a travel position to a down and locked position before final touchdown; and (c) closing pipe support locking devices of each pipe lifting frame on said pipeline. 6. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 1 including the additional step of again lowering and landing said measurement tool onto said pipeline after said pipeline has been elevated from the sea floor by said pair of pipe lifting frames and retaking said checks and measurements. 7. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 1 including the additional preliminary steps of a visual condition inspection of the seabed and vicinity including the use of a camera to report bottom conditions, visibility, type of soil, water current, location of circumferential and longitudinal weld seams. 8. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 1 including the additional step of disconnecting and retrieving said hot tap machine after tapping. 9. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 1 including the additional step of lowering and landing a lateral or spool pipe connector guide after tapping. 10. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 9 including an additional step of pulling in a lateral or spool pipe section. 11. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 10 including an additional step of connecting said lateral or spool pipe section to said pipeline by means of a mechanical or hydraulic connector. 12. A diverless process of tapping a pressurized subsea pipeline without removing said pipeline from service, which process comprises: (a) lowering and landing a measurement tool onto said pipeline and checking ovality and checking straightness of said pipeline with said measurement tool; (b) lowering and landing at least a pair of pipe lift frames onto said pipeline; (c) lifting said pipeline on said pipe lift frames; (d) lowering and landing a hot tap fitting clamp assembly contained in an orientation frame on said pipeline between said pipe lift frames; (e) incrementally raising said pipe lift frames until said pipeline is fully seated in the hot tap fitting and orientation frame; (f) lowering a hot tap machine onto said hot tap fitting and orientation frame; (g) tapping said pipeline with said hot tap machine; and (h) lowering said pipeline. 13. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 wherein the step of lifting said pipeline is accomplished by hydraulic actuators or mechanical screws on said lift frames. 14. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 including the additional steps prior to said lowering and landing of said hot tap fitting contained in said orientation frame of: (a) lowering and landing a weld bead removal tool onto said pipeline; and (b) grinding any longitudinal weld beads from said pipeline. 15. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 14 wherein power and control for said measurement tool, said hot tap fitting and orientation frame said hot tap machine and said torque tool or stud tensioner are all powered by a remote operating vehicle. 16. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 14 wherein said lowering of said measurement tool includes the steps of: clamping said measurement tool onto said pipeline; and welding, grinding or milling a longitudinal or circumferential weld bead. 17. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 including the preliminary steps of: excavating from underneath said pipeline by using a remote operated vehicle to allow unrestricted installation of said pipe measurement tool; cleaning off said pipeline using brushes or low pressure water jets; and removing protective or external coatings from said pipeline. 18. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 17 including the step of dispersing soil entrained water by hydraulically powered fans or chemical flocculation to maintain visibility. 19. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 wherein said step of lowering and landing a pair of pipe lift frames onto said pipeline includes the additional steps of: lowering and landing each said pipe lift frame at a prescribed spacing from a chosen hot tap location; positioning a plurality of mud mats on said lift frames from a travel position to a down and locked position; and locking tongs on each lift frame mechanically to said pipe. 20. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 including the additional step of again lowering and landing said measurement tool onto said pipeline after installation of said pair of pipe lift frames and checking ovality and checking straightness. 21. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 including the step of lowering a plurality of guide posts on said pipe lift frames substantially vertical to said pipeline. 22. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 wherein a valve and connector hub assembly are lowered with said orientation frame. 23. A diverless process of tapping a subsea pipeline as set forth in Claim 12 including the additional preliminary steps of a preliminary visual condition inspection including use of a camera to report bottom conditions, visibility, type of soil, water current, location of circumferential and longitudinal weld seams and surface pipeline defects. 24. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 including the additional steps of rotating the hot tap fitting clamp about the pipeline to orient the fitting clamp to the pipeline and measuring the orientation of said valve. 25. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 wherein the step of lowering said pipeline is accomplished by hydraulic actuators or mechanical screw on said lift frames. 26. A diverless process of tapping a pressurized subsea pipeline as set forth in Claim 12 including the additional steps of: installing a receptacle in a hub on the hot tap fitting and on a production valve hub; measuring distance between hub receptacle and production valve hub receptacle; lowering a jumping spool between hub and production receptacle; and seal off jumper- valve hub interfaces.

Inventors: CROSS DONALD W, DECKER LARRY, EXLEY GERN D, HICKS DAVID J, MCCOY RICHARD W, TARLTON ORAN, CROSS, DONALD, W., DECKER, LARRY, EXLEY, GERN, D., HICKS, DAVID, J., MCCOY, RICHARD, W., TARLTON, ORAN
Applicants: WILLIAMS FIELD SERVICES GULF C, WILLIAMS FIELD SERVICES GULF COAST COMPANY, L.P.
Application year: 2000
Main classification: F16L1
IPC codes: F16L1