GB2129472A - A method for providing a horizontal support area at a subsea production site - Google Patents
A method for providing a horizontal support area at a subsea production site Download PDFInfo
- Publication number
- GB2129472A GB2129472A GB08326488A GB8326488A GB2129472A GB 2129472 A GB2129472 A GB 2129472A GB 08326488 A GB08326488 A GB 08326488A GB 8326488 A GB8326488 A GB 8326488A GB 2129472 A GB2129472 A GB 2129472A
- Authority
- GB
- United Kingdom
- Prior art keywords
- template
- monopile
- wedge
- subsea production
- production site
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 18
- 238000000034 method Methods 0.000 title claims description 8
- 229930195733 hydrocarbon Natural products 0.000 description 4
- 150000002430 hydrocarbons Chemical class 0.000 description 4
- 229910000831 Steel Inorganic materials 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000010959 steel Substances 0.000 description 2
- 238000003860 storage Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000007670 refining Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000010561 standard procedure Methods 0.000 description 1
- 239000003351 stiffener Substances 0.000 description 1
- 238000011179 visual inspection Methods 0.000 description 1
- 238000003466 welding Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/017—Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/08—Underwater guide bases, e.g. drilling templates; Levelling thereof
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
- Biological Depolymerization Polymers (AREA)
Abstract
To provide a horizontal support area at a subsea production site, a single support pile is driven into the ocean floor and a support bracket is secured to the piling. The slope of the support bracket to the horizontal is determined and a wedge 20 is prefabricated so as to have the equal and opposite slope. The wedge 20 is then located on the bracket to define a horizontal seating for a subsea production template. <IMAGE>
Description
SPECIFICATION
A method for providing a horizontal support area at a subsea production site
The present invention pertains to a subsea production assembly wich connects a plurality of hydrocarbon producing wells with flowlines to transport hydrocarbons to storage facilities and more particularly to a method of providing a horizontal support area at a subsea production site.
Present oil production is being directed to offshore areas located in water of up to 2,500 feet (762 m) deep. Subsea production is more economical if a plurality of wells are drilled from the same area with different slopes to achieve more efficient well production. A manifold structure is then used to combine the output of the plurality of wells in one or two flowlines to transport either liquid or gaseous hydrocarbons to storage facilities or a transfer vessel for further transportation to refining facilities. Typically, the manifold structure is supported on a template which is placed on a plurality of pilings, leveled by adjusting the heights of the respective pilings and securely fastened to each of the pilings. The manifold structure also comprises several bays, the majority of which are used as connections to wellheads.One or two of the bays are used for connections to flowline bundles which carry the liquid or gaseous hydrocarbons to a remote destination.
The concrete pilings upon which the template is placed are usually prefabricated concrete and may be several hundred feet long. The pilings are driven into the ocean floor with an underwater hammer. Once the concrete pilings are in place, they must be adjusted so that the template, which is typically 25 feet (7.6 m) in diameter, is level within 3 inches (7.6 cm) across its diameter. To appreciate the magnitude of this problem, it is to be noted that, for a 25 foot (7.6 m) diameter template, a slope of 5 degrees from the horizontal will result in a discrepancy of over 2 feet (0.6 m) from one side of the template to the opposite side.
As the depth increases down to 2,500 feet (762 m), leveling of the template becomes more and more of a problem particularly with the multiple piling support cocept.
Accordingly the invention resides in a method for providing a horizontal support area at a subsea production site comprising the steps of determining the slope of the subsea production site prefabricating a wedge having a slope equal and opposite of the determined slope and placing the wedge on the subsea production site.
In the accompanying drawings,
Figure 1 is a diagrammatic side view of a monopile support.
Figure 2 is a plan view of a leveling wafer.
Figure 3 is a cut away side view of Figure 2.
Figure 4 is a plan view of a template and a gimbal mounted latch system.
Figure 5 is a side view along lines 4-4 of
Figure 4.
Figure 6 is a plan view of a slip segment
latching system.
Figure 7 is a partially cut away side view of
Figure 6.
Referring now to Figure 1, a monopile support assembly is illustrated having monopile 12 with ring girder 14 attached thereto. Superimposed in phantom are monopile 1 2A and ring girder 1 4A depicting distance variations existing whenever monopile 1 2 is not installed perfectly vertical.
Monopile 12 may be of any commonly used support material. However, the preferred embodiment uses steel pipe having an outer diameter of 6 feet (1.8 m) and a thickness of 2 inches (5.1 cm). This single support monopile 12 may be as long as 300 feet (91 m) of which only a few feet extend above the mudline of the ocean floor.
As illustrated in Figure 1, a five degree deviation from vertical at the top of monopile 12 results in a deviation in excess of 2 feet (0.6 m) between corner 1 6 and opposite corner 1 8 of the ring girder 14. Ring girder 14 may also be of any type currently used to initially support the weight of the template which will rest thereon. Ring girder 14 may be affixed to monopile 12 by standard methods such as welding.
Monopile 12 and its ring girder 14 are to be installed in 2,500 feet (762 m) of water, by driving with an underwater hammer. A tolerance on the verticality of the pile axis may be zero to five degrees omni-directionally. A ten bay template is preferably landed on the pile and made level to within one-half degree of horizontal to accommodate later operations. A more detailed description of a subsea template may be found in our published British Patent Application No.
2,114,188.
Normally, monopile 12 projects approximately 10 feet (3 m) above the ocean floor, and has a ring girder assembly 14 25 feet (7.6 m) in diameter fixed at the mudline. As previously stated, a five degree slope amounts to in excess of 2 feet (0.6 m) deviation across the 25 foot (7.6 m) base of the girder, whereas the template, when set down, must be leveled to + 2.62 inches (6.65 cm) across this same 25 foot (7.6 m) diameter. A significantly sloped surface presents drilling, pumping and connection problems which, due to the depth at which the platform is operated, require many man hours and great expense to correct.
A nearly level template surface is a prerequisite for reliable, efficient operation of a subsea production system which contains connections to oil wellheads and production flowlines.
Referring now to Figures 2 and 3, a template leveling wafer 20 is illustrated as having template orientation slot 22, handling eye 24, slope indicators 26 and lifting pins 38. The wafer 20 is a prefabricated structural component, which is constructed before the installation phase but is designed to be field adjustable. The wafer centers on the pile only loosely and provides a level top surface since its bottom surface is adjusted on site
to compensate for the angle of ring girder plate 14.
The wafer does not need to be precisely centered,
but it does require orientation with respect to
monopile 12. This can be accomplished with a
orientation pin 30 (Figure 3) on the wafer 20.
Precise orientation is not critical, as an orientation error of 1 80 degrees will produce an error of only
10 degrees from level. Therefore, an orientation
error of a few degrees will result in a small
leveling error.
A subsea platform is thus required to have no leveling machinery, as the foundation has already been made level. A large bearing area is also achieved. Separate orientation of a subsea platform is possible if done before the weight of the template is set on wafer 20. If compensating wafer 20 is set on ring girder 14 and found to be incorrect, it can be pulled back to the surface much easier and quicker than a large subsea platform base.
In operation, the deviation of monopile 12 (see
Figure 1) is measured and the slope of ring girder
14 is computed. Wafer 20 is prefabricated to compensate for the determined slope of ring girder 14. Wafer 20 may be lifted by lift pins 28 and lowered onto ring girder 14 on monopile 12 by methods currently used in subsea construction.
Wafer 20 has a center slot 32 which defines a funnel from bottom to top. The top of center slot 32 is approximately 6 feet (1.8 m) in diameter and the bottom is approximately 10 feet (3 m) in diameter. This permits wafer 20 to be lowered on
monopile 12 while misalignment of center slot 32 with respect to the center of monopile 12 may be as much as 4 feet (1.2 m). The funnel type arrangement of slot 32 ensures centering on monopile 12 and allows alignment with side walls of ring girder 14.
Wafer 20 is constructed to compensate for any deviation from vetical of monopile 12 which results in a slope from horizontal of the base of ring girder 14. As illustrated in Figure 3, wafer 20 may consist of two concentric superimposed, mutually rotatable segments 20A and 20B. Each segment is in the form of a circular wedge, conveniently defining a 2 1/2 degree angle between its upper and lower surfaces so that, by varying the angular orientation of the segments, the angle between the top and bottom surfaces of the overall wafer can be adjusted from 0--5 degrees. Each segment is a steel plate fabrication with circular and radial stiffeners 39 being provided to give the wafer sufficient strength to transfer the compressive loads experienced in use.
Before the wafer 20 is lowered into place on monopile 12 and ring girder 14, the angular orientation of the segments 20A, 20B is adjusted to compensate for slope existing in ring girder 14.
After the wafer has been installed, the accuracy of this adjustment can be confirmed by visual inspection of the slope indicators 26.
Using the monopile 1 2 as the sole support for the template presents an additional problem in latching the template to the monopile 12. Thus the template must be securely fastened to the
monopile 12 even when monopile 12 deviates
from vertical. However, the wafer 20 allows the
template to assume a level position, so that the
center axis of template 40 is always substantially
vertical, but will be at an angle with the center line
of monopile 1 2 when it deviates from vertical.
Referring now to Figures 4 to 7, template 40 is illustrated as being connected to gimbaled ring 42
through universal connection 44 and having
hydraulically operated slip latch 46 attached to
gimbaled ring 42 through universal connection
48. Hydraulically operated slip ring latch 46 fits
around monopile 12 and may rotate to
compensate for any deviation from vertical in
monopile 12. However, compensation for
deviation from the vertical by hydraulically
operated slip latch 46 can only compensate for
deviations within the 90 degree arc of universal
joint 48, that is t 45 degrees from center line axis
50 of universal joint 48.
Universal joint 44 connecting gimbaled ring 42
and template 40 is spaced 90 degrees from the
center line 50 of universal joint 48 having a center
line axis 52 perpendicular to axis 50. Universal
joint 44 will compensate for deviations from the
vertical in monopile 1 2 which are + 45 degrees
from centre line 52. Thus, template 40 may be
lowered upon wafer 20 and latched to monopile 1 2 despite its deviation from vertical.
Figure 5 illstrates universal connection 44 to
gimbaled ring 42 and universal connection 48 to
hydraulically operated slip ring latch 46. As
illustrated, template 40 may be set on wafer 20
while hydraulically operated latch 46 slides down
monopile 12. Template 40 will rest on wafer 20
while hydraulically operated latch 46 is configured
to extend to a level slightly above wafer 20.
As shown in Figures 6 and 7, hydraulically
operated slip latch 46 includes slip segments 50
50A having wedges 52, 52A located therein. Slip
latch 46 also includes hydraulic cylinders 56
connected to wedges 52 and 52A in juxtaposition
with slip segments 50 and 50A, respectively. Slip
segments 50 and wedge 52 depict the elements
in unlocked position and slip segment 50A and
wedge 52A depict the elements in locked position.
Hydraulically operated slip latch 46 must be
capable of being operated remotely and be
capable of latching positively to monopile 12
despite any forces exerted on template 40 or
monopile 12. This means that hydraulically
operated slip latch 46 must not be susceptible to
working itself loose when operational forces are
applied. The combination of wedges 52 and slip
segments provide a secure connection as required.
In operation, hydraulically operated slip latch
46 is lowered onto monopile 12, with the wedges
and slip segments in their unlocked position.
When the latch is in place, hydraulic cylinders 56
are actuated to force piston arm 58 against wedge
52A forcing it to slide slip segment against
monopile 12. Once in position, any radial or
transverse forces exerted on either template 20 or
monopile 1 2 will be transplated into radial forces.
By arranging that the angle of inclination of wedge 52 with respect to slip segment 50 is small, radial forces will be almost perpendicular to surfaces 60 and 60A of wedges 52 and 52A. As such, wedges 52 and 52A will maintain their position forcing slip segments 50 and 50A to remain tight against monopile 12.
Hydraulically operated slip latch 46 makes positive solid contact with monopile 12 and acts through universal connection 48, gimbaled ring 42 and universal connection 44 to provide secure mounting for template 40 to monopile 12.
Claims (3)
1. A method for providing a horizontal support
area at a subsea production site comprising the
steps of:
determining the slope of the subsea production
site;
prefabricating a wedge having a slope equal and opposite of the determined slope; and
placing the wedge on the subsea production site.
2. The method according to claim 1 wherein the prefabricating step includes providing first and second concentric, superimposed, generally circular wedge segments which are capable of relative angular movement, each wedge segment defining an angle between its upper and lower surfaces, and imparting relative angular movement to the segments so as to vary the angle between the upper surface of the first segment and the lower surface of the second segment.
3. The method of claim 1 or claim 2 and further comprising the steps of driving a single support pile into the ocean floor, securing a support bracket to the piling, and mounting a template on the support bracket with the prefabricated wedge being located between the bracket and the template.
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US43288082A | 1982-10-05 | 1982-10-05 |
Publications (3)
Publication Number | Publication Date |
---|---|
GB8326488D0 GB8326488D0 (en) | 1983-11-02 |
GB2129472A true GB2129472A (en) | 1984-05-16 |
GB2129472B GB2129472B (en) | 1986-03-12 |
Family
ID=23717954
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
GB08326488A Expired GB2129472B (en) | 1982-10-05 | 1983-10-04 | A method for providing a horizontal support area at a subsea production site |
Country Status (6)
Country | Link |
---|---|
JP (1) | JPS5988521A (en) |
AU (1) | AU559502B2 (en) |
CA (1) | CA1213741A (en) |
FR (1) | FR2533953B1 (en) |
GB (1) | GB2129472B (en) |
NO (1) | NO163495C (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP2749697A3 (en) * | 2012-12-13 | 2015-11-11 | Gravitas Offshore Limited | Levelling for offshore structures |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
JP2544991Y2 (en) * | 1993-02-25 | 1997-08-20 | 株式会社東芝 | Magnetron |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB819757A (en) * | 1956-08-06 | 1959-09-09 | Christiani And Nielsen | Foundation at great depths of water |
GB1176635A (en) * | 1967-03-17 | 1970-01-07 | Westinghouse Electric Corp | Building Structure Support Arrangement. |
Family Cites Families (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3316984A (en) * | 1964-11-20 | 1967-05-02 | Cameron Iron Works Inc | Well apparatus |
IE39145B1 (en) * | 1972-12-01 | 1978-08-16 | Redpath Dorman Long Ltd | Improvements in or relating to the founding of maritime structures |
GB2054710A (en) * | 1979-05-25 | 1981-02-18 | Cjb Bearl & Wright Ltd | Levelling seabed templates |
-
1983
- 1983-09-28 AU AU19697/83A patent/AU559502B2/en not_active Ceased
- 1983-10-04 CA CA000438304A patent/CA1213741A/en not_active Expired
- 1983-10-04 FR FR8315778A patent/FR2533953B1/en not_active Expired
- 1983-10-04 NO NO833606A patent/NO163495C/en unknown
- 1983-10-04 GB GB08326488A patent/GB2129472B/en not_active Expired
- 1983-10-05 JP JP58186655A patent/JPS5988521A/en active Granted
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB819757A (en) * | 1956-08-06 | 1959-09-09 | Christiani And Nielsen | Foundation at great depths of water |
GB1176635A (en) * | 1967-03-17 | 1970-01-07 | Westinghouse Electric Corp | Building Structure Support Arrangement. |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP2749697A3 (en) * | 2012-12-13 | 2015-11-11 | Gravitas Offshore Limited | Levelling for offshore structures |
Also Published As
Publication number | Publication date |
---|---|
FR2533953A1 (en) | 1984-04-06 |
JPS5988521A (en) | 1984-05-22 |
NO833606L (en) | 1984-04-06 |
GB8326488D0 (en) | 1983-11-02 |
GB2129472B (en) | 1986-03-12 |
CA1213741A (en) | 1986-11-12 |
AU1969783A (en) | 1984-04-12 |
FR2533953B1 (en) | 1988-06-17 |
JPH0350042B2 (en) | 1991-07-31 |
NO163495B (en) | 1990-02-26 |
NO163495C (en) | 1990-06-06 |
AU559502B2 (en) | 1987-03-12 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US4687062A (en) | Undersea template for the drilling of wells for the exploitation of hydrocarbon pools under the sea | |
US5244312A (en) | Pile supported drilling template | |
US3852970A (en) | Building raising and underpinning system | |
US3881549A (en) | Production and flare caisson system | |
US4740107A (en) | Method and apparatus for protecting a shallow-water well | |
FI92234C (en) | Production system for oil wells drilled in the bottom of the water area | |
US4435108A (en) | Method of installing sub-sea templates | |
US6299385B1 (en) | Mini-jacket and method for installation using caisson | |
GB2211526A (en) | Subsea template | |
US5379844A (en) | Offshore platform well system | |
US5988949A (en) | Offshore jacket installation | |
US3559410A (en) | System for relieving stress at the top and bottom of vertical tubular members in vertically moored platforms | |
US4907657A (en) | Method for protecting a shallow water well | |
US5012875A (en) | Method and apparatus for protecting a shallow-water well | |
US4260291A (en) | Installation of an offshore structure | |
US4711601A (en) | Method of installing offshore constructions | |
US4830542A (en) | Subsea template leveling wafer and leveling method | |
CA1201973A (en) | Apparatus and method for attaching a template at a subsea production site | |
CA1213741A (en) | Method for providing a horizontal support area at a subsea production site | |
EP0046044A1 (en) | Underwater anchor assembly and method of installing the same | |
US4966496A (en) | Method of erecting offshore platforms | |
US4580926A (en) | Foundation level and orientation tool | |
US5722494A (en) | Stacked template support structure | |
CA1194856A (en) | Method of installing subsea templates | |
JPH026151Y2 (en) |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
PCNP | Patent ceased through non-payment of renewal fee |
Effective date: 19951004 |