Note : Les descriptions sont présentées dans la langue officielle dans laquelle elles ont été soumises.
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PATENT APPLICATION
TITLE OF THE INVENTION
"ARTICULATED MULTIPLE BUOY MARINE PLATFORM APPARATUS
AND METHOD OF INSTALLING SAME"
INVENTOR: KHACHATURIAN, Jon, E., a US citizen, residing at 5427 Sutton Place,
New Orleans, Louisiana 70131.
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BACKGROUND
The present invention relates to floating marine platforms in deep water
environments (e.g., over 1500 feet or 450 meters) and methods of installing
same. More
particularly, the present invention relates to a novel multiple buoy platform
that supports
a platform with a plurality of buoys and method of installing same.
In an alternate embodiment the present invention relates to a method wherein
multiple buoys can be used as part of an installation method to place a marine
platform
upon a single spar support.
In an alternate embodiment the present invention relates to a novel specially
configured multiple device support enabling replacement of one device while
the other
supports the platform.
Many types of marine platforms have been designed, patented and used
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commercially. Marine platforms typically take the form of either fixed
platforms that
include a large underwater support structure or "jacket" or a floating
platform having a
submersible support. Sometimes these platforms are called semi-submersible
rigs.
Jack-up barges are another type of platform that can be used in an offshore
marine
environment for drilling/production. Jack-up barges have a barge with long
legs that can
be powered up for travel and powered down to elevate the barge above the
water.
Other types of platforms for deep water (1500 feet or 450 meters or deeper)
have
been patented. The September 2000 issue volume 60, issue 9 of Offshore
Magazine,
PennWell Corporation, Oklahoma, USA, shows many floating offshore platforms
for
use in deep water drilling and/or production. Some of the following patents
relate to
offshore platforms, some of which are buoy type offshore platforms. Other
patents have
issued that relate in general to floating structures, and include some patents
disclosing
structures that would not be suitable for use in oil and gas well drilling
and/or production.
PATENT # ISSUE TITLE
DATE
US 2,952,234 13 September 1960 Sectional Floating Marine Platform
US 3,540,396 17 November 1970 Offshore Well Apparatus and System
US 3,982,492 28 September 1976 Floating Structure
US 4,286,538 01 September 1981 Multipurpose Floating Structure
2 0 US 4,297,965 03 November 1981 Tension leg Structure for Tension Leg
Platform
US 4,620,820 04 November 1986 Tension Leg Platform Anchoring Method
and Apparatus
US 5,197,825 30 March 1993 Tendon for Anchoring a Semisubmersible
2 5 US 5,423,632 13 June 1995 Compliant Platform With Slide
Connection Docking to Auxiliary Vessel
Platform
US 5,439,060 08 August 1995 Tensioned Riser Deepwater Tower
US 5,558,467 24 September 1996 Deep Water offshore Apparatus
3o US 5,706,897 13 January 1998 Drilling, Production, Test, and Oil
Storage Caisson
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US 5,722,797 03 March 1998 Floating Caisson for Offshore
Production and Drilling
US 5,799,603 01 September 1998 Shock-Absorbing System for Floating
Platform
US 5,873,416 23 February 1999 Drilling, Production, Test, and Oil
Storage Caisson
US 5,931,602 03 August 1999 Device for Oil Production at Great
Depths at Sea
Storage Caisson
US 5,924,822 20 July 1999 Method for Deck Installation on an
Offshore Substructure
US 6,012,873 11 January 2000 Buoyant Leg Platform With Retractable
Gravity Base and Method of Anchoring
and Relocating the Same
US 6,027,286 22 February 2000 Offshore Spar Production System and
Method for Creating a Controlled Tilt
of the Caisson Axis
GB 2 092 664 Ball-and-Socket Coupling for Use in
Anchorage of Floating Bodies
One of the problems with single floater type marine platform constructions is
that
the single floater must be enormous, and thus very expensive to manufacture,
transport,
and install. In a marine environment, such a structure must support an oil and
gas well
drilling rig or production platform weighing between 5,000 and 40,000 tons
(5,080,250kg
and 40,642,000 kg), for example (or even a package of between 500-100,000
tons)
(508,025 kg - 101,605,000 kg).
BRIEF SUMMARY OF THE INVENTION
In one particular embodiment there is provided a marine platform, comprising:
a) a plurality of buoys; b) a platform having an oil and gas well producing
facility and
a peripheral portion that includes a plurality of connecting positions, one
connecting
position for each buoy; and c) an articulating connection that connects each
buoy to
the platform at a respective connecting position, the plurality of
articulating
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connections allowing for buoy motions induced by sea movement while reducing
sea
movement effect on the platform.
In another particular embodiment there is provided a marine platform,
comprising: a) a plurality of buoys; b) a platform having an oil and gas well
producing facility weighing between 500,000 kilograms and 105,000,000
kilograms
and a peripheral portion that includes a plurality of connecting positions,
one
connecting position for each buoy; and c) an articulating connection that
connects
each buoy to the platform at a respective connecting position, the plurality
of
articulating connections allowing for buoy motions induced by sea movement
while
reducing sea movement effect on the platform.
In yet another particular embodiment there is provided a marine platform,
comprising: a) a plurality of buoys; b) a platform having an oil and gas well
producing
facility and a peripheral portion that includes a plurality of connecting
positions, one
connecting position for each buoy; and c) a connection that connects each buoy
to the
platform at a respective connecting positions, the plurality of connections
allowing for
buoy motions induced by sea movement while reducing sea movement effect on the
platform; and d) the connection including first and second connection devices
that
enable removal of one of the connection devices for servicing, the other
device
connecting the buoy to the platform during such servicing.
In still yet another particular embodiment there is provided a marine
platform,
comprising: a) a plurality of buoys; b) a platform having an oil and gas well
producing
facility weighing between 500,000 kilograms and 105,000,000 kilograms and a
peripheral portion that includes a plurality of connecting positions, one
connecting
position for each buoy; and c) a connection that connects each buoy to the
platform at a
respective connecting position, the plurality of connections allowing for buoy
motions
induced by sea movement while reducing sea movement effect on the platform; d)
the
connection between each buoy and the platform including first and second
articulating
devices and a load transfer mechanism that enables at least some of the
platform load
to be transferred from one device to the other device.
In still yet another particular embodiment there is provided a marine
platform,
comprising: a) a plurality of buoys; b) a platform having an oil and gas well
producing
facility and a peripheral portion that includes a plurality of connecting
positions, one
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connecting position for each buoy; and c) a connection that connects each buoy
to the
platform at a respective connecting positions, the plurality of connections
allowing for
buoy motions induced by sea movement while reducing sea movement effect on the
platform; and d) the connection having means for enabling a transfer of at
least a
portion of the platform load from a first portion of the connection to a
second portion
of the connection.
In still yet another particular embodiment there is provided a method of
installing an oil and gas well drilling or production platform in an offshore
deep water
marine environment, comprising the steps of. a) placing a plurality of buoys;
b) floating a platform in the marine environment having an oil and gas well
drilling or
production facility to the location of the buoys, the platform including a
peripheral
portion that includes a plurality of connecting positions, one connecting
position for
each buoy; and c) ballasting the platform and buoys relative to one another
until each
buoy connects with the platform and substantially all of the weight of the
platform is
supported by the buoys.
In still yet another particular embodiment there is provided a method of
installing an oil and gas well production platform in an offshore deep water
marine
environment, comprising the steps of. a) floating a multi-ton package to a
selected
offshore location, the package having a plurality of connectors and wherein
the
connectors are preliminarily positioned at a higher elevational position; b)
positioning
a plurality of floating buoys at a selected offshore location, each buoy
having a buoy
connector portion at its upper end; c) preliminarily positioning the buoy
connectors at a
selected elevational position; d) ballasting the floating package and buoys
relative to
one another so that the package connectors and the buoy connectors engage to
define a
plurality of articulating connections and where substantially all of the
weight of the
platform is supported by the buoys.
In still yet another particular embodiment there is provided a method of
installing an oil and gas well production platform in an offshore deep water
marine
environment, comprising the steps of. a) floating a multi-ton package to a
selected
offshore location, the package having a plurality of connectors and wherein
the
connectors are preliminarily positioned at a higher elevational position; b)
positioning
a plurality of floating buoys at a selected offshore location, each buoy
having a buoy
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connector portion at its upper end; c) preliminarily positioning the buoy
connectors at a
selected elevational position; d) ballasting the floating package and buoys
relative to
one another so that the package connectors and the buoy connectors engage to
define a
plurality of articulating connectors, including at least one articulating
connector for
each floating buoy.
In still yet another particular embodiment there is provided a method of
installing an oil and gas well production platform in an offshore deep water
marine
environment, comprising the steps of: a) floating a multi-ton package to a
selected
offshore location, the package having a plurality of connectors and wherein
the
connectors are preliminarily positioned at a higher elevational position; b)
positioning
a plurality of floating buoys at a selected offshore location, each buoy
having a buoy
connector portion at its upper end; c) preliminarily positioning the buoy
connectors at a
selected elevational position; d) positioning a floating spar next to the
combination of
buoys and multi-ton package; and e) transferring the package from the buoys to
the
spar by laterally moving the spar relative to the combination of buoys and
package
until they are generally vertically aligned and then lowering the package to
the spar.
The present invention provides an improved offshore marine platform (and
method of installation) that can be used for drilling for oil and/or gas or in
the
production of oil and gas from an offshore environment. Such drilling and/or
production facilities typically weigh between 500 - 100,000 tons (508,025 kg -
101,605,000 kg), more commonly between 3,000 - 50,000 tons (3,048,150 kg -
50,802,500 kg).
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The apparatus of the present invention thus provides a marine platform that is
comprised of a plurality of spaced apart buoys and a superstructure having a
periphery
that includes a plurality of attachment positions, one attachment position for
each buoy.
An articulating connection joins each buoy to the platform superstructure.
The apparatus of the present invention uses articulating connections between
the
submerged portion of each buoy and the superstructure to minimize or reduce
topside,
wave induced motions during the structural life of the apparatus.
Each of the buoys will move due to current and/or wind and/or wave action or
due
to other dynamic marine environmental factors. "Articulating connection" as
used herein
should be understood to mean any connection or joint that connects a buoy to
the
superstructure, transmits axial and shear forces, and allows the support
buoy(s) to move
relative to the superstructure without separation, and wherein the bending
moment
transferred to the superstructure from one of the so connected buoys or from
multiple of
the so connected buoys is reduced, minimized or substantially eliminated.
"Articulating
connection" can also be a joint movably connecting a buoy to a superstructure
wherein
axial and tangential forces are substantially transmitted, however, transfer
of bending
moment is substantially reduced or minimized through the joint allowing
relative
movement between the buoy and the superstructure.
A connection (which can be an articulating connection) connects each buoy to
the
platform at a respective attachment position, the connection allowing for sea
state
induced buoy motions while minimizing effects on the platform.
The apparatus of the present invention provides a marine platform that can
further
comprise a mooring extending from a plurality of the buoys for holding the
platform and
buoys to a desired location.
In one embodiment, the present invention provides a marine platform wherein
each ofthe articulating connections includes corresponding concave and convex
engaging
portions. In an alternative embodiment, a universal type joint is disclosed.
In another embodiment a marine platform has buoys with convex articulating
portions and the platform has correspondingly shaped concave articulating
portions.
In another embodiment, each buoy can be provided with a concave articulating
portion and the platform with a convex articulating portion.
In another embodiment, each buoy has a height and a diameter. In another
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embodiment, the height is much greater than the diameter for each of the
buoys.
In another embodiment, each buoy is preferably between about 25 and 100 feet
in diameter (7.62m and 30.48m).
The apparatus of the present invention preferably provides a plurality of
buoys,
wherein each buoy is between about 100 and 500 feet in height (30.48m and
152.4m).
The buoys can be of a generally uniform diameter along a majority of the buoy.
However, in an alternative embodiment each buoy can have a variable diameter.
In a preferred embodiment, each buoy is generally cylindrically shaped.
However,
in an alternative embodiment each buoy can be provided with simply an upper
end
portion that is generally cylindrically shaped.
In a preferred embodiment, there are at least three buoys and at least three
attachment positions, preferably four buoys and four attachment positions.
In a preferred embodiment, each articulated connection is preferably
hemispherically shaped for the upper end portion of each buoy and there is a
correspondingly concavely shaped receptacle on the platform that fits the
surface of each
hemispherically shaped upper end portion.
In an alternative embodiment the connection can also be in the form of a
universal
joint. In an additional embodiment, the connection can be in the form of first
and second
devices that provide "backup" or redundancy enabling one device to be serviced
while
the other supports the platform. In this additional embodiment, a first
universal joint
preferably carries load between the platform and each buoy over the long
period of time.
In the event that the first device must be replaced or serviced, a j acking
arrangement loads
the other device so that the first device does not carry load and can be
removed. The
devices can include an inner device and an outer device. The "devices" can be
articulating
devices such as universal joints.
In a preferred embodiment, the platform is comprised of a trussed deck. The
trussed deck preferably has lower horizontal members, upper horizontal members
and a
plurality of inclined members spanning between the upper and lower horizontal
members,
and wherein the attachment positions are next to the lower horizontal member.
In a preferred embodiment, the apparatus supports an oil and gas well drilling
and/or production platform weighing between 500 and 100,000 tons (508,025 kg
and
101,605,000 kg), more particularly, weighing between 3,000 tons and
50,000(3,048,150
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kg and 50,802,500 kg).
An advantage of the present invention is that it enables smaller, multiple
hull
components to be used to support the superstructure when compared to a single
column
or single buoy floater.
An advantage of the present invention is that topside angular motion can be
reduced when compared to the topside angular motion of a single column floater
of
comparable weight.
With the present invention, there is substantially no bending moment or
minimum
bending moment transferred between each buoy and the structure being
supported. The
present invention thus minimizes or substantially eliminates moment transfer
at the
articulating connection that is formed between each buoy and the structure
being
supported. The buoys are thus substantially free to move in any direction
relative to the
supported structure or load excepting motion that would separate a buoy from
the
supported structure.
The present invention has particular utility in the supporting of oil and gas
well
drilling facilities and oil and gas well drilling production facilities. The
apparatus of the
present invention has particular utility in very deep water, for example, in
excess of 1500
feet (4572m).
The present invention also has particular utility in tropical environments
(for
example West Africa and Brazil) wherein the environment produces long period
swell
action.
In an alternative embodiment of the present invention includes a method of
installing an oil and gas well facility such as a drilling facility or a
production facility on
a platform in an offshore deepwater marine environment is provided. The term
"deepwater" as used herein means water depths of in excess of 1500 feet
(4572m).
The method of the present invention contemplates the placement of a plurality
of
buoys at a selected offshore location, a portion of each of the buoys being
underwater. A
superstructure extends above water and includes a platform having an oil and
gas well
facility. Such a facility can include oil well drilling, oil well production,
or a combination
of oil well drilling and production. The platform and its facility can be
floated to a
selected location. The platform includes a peripheral portion having a
plurality of
attachment positions, one attachment position for each buoy.
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When the buoys and platform are located at a desired position, the platform is
ballasted relative to the buoys until the buoys connect with the platform.
This connection
can be achieved by either ballasting the platform downwardly (such as for
example, using
a ballasted transport barge), or by ballasting the buoys to a higher position
so that they
engage the supported platform.
In a preferred embodiment, the buoys can be elongated, cylindrically shaped
buoys, each having a diameter of for example, 25 - 100 feet (7.62m - 30.48m)
and a
height of preferably between about 100 and 500 feet (30.48m and 152.4m). Each
of the
buoys can have an upper, smaller diameter portion that includes a connector.
In one
embodiment, the connector can be convex in shape and articulate with a
correspondingly
shaped concave connector on the platform.
The platform can include a trussed deck that carries at or near its periphery
or
corners, connectors that enable a connection to be formed with the upper end
portion of
each buoy. As an example, there can be provided four buoys and four connectors
on the
trussed deck or platform.
If a trussed deck is employed, an oil well production facility (drilling or
production or a combination) can be supported upon the trussed deck. The
connector at
the top of each buoy can be any type of an articulating connection that forms
an
articulation with the trussed deck or a connector on the trussed deck.
Examples include
the ball and socket or concave/convex arrangement shown in the drawings
(Figures 1-12).
Another example includes the universal joint shown in the drawings (see
Figures 13-14).
In an alternate method, the multiple buoys can be used as part of an
installation
method to place the marine platform upon a single spar support.
BRIEF DESCRIPTION OF THE DRAWINGS
For a further understanding of the nature, objects, and advantages of the
present
invention, reference should be had to the following detailed description, read
in
conjunction with the following drawings, wherein like reference numerals
denote like
elements and wherein:
Figure 1 is an elevation view of a preferred embodiment of the apparatus of
the
present invention;
Figure 2 is a plan view of a preferred embodiment of the apparatus of the
present
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invention;
Figure 3 is an elevation view of a preferred embodiment of the apparatus of
the
present invention;
Figure 4 is another elevation view of a preferred embodiment of the apparatus
of
the present invention;
Figures 5-6 are fragmentary perspective views of a preferred embodiment of the
apparatus of the present invention illustrating the articulating connection
between a buoy
and the platform; and
Figures 7-8 show alternate mooring arrangements for the apparatus of the
present
invention;
Figure 9 is a partial elevation view of an alternate embodiment of the
apparatus
of the present, invention that features buoys of variable diameter;
Figure 10 is a sectional view taken along lines 10-10 of Figure 9;
Figure 1 OA is a sectional view taken along lines 10-10 of Figure 9 and
showing
a buoy lower end portion that is square;
Figure 11 is a partial elevation view of a third embodiment of the apparatus
of the
present invention showing an alternate buoy construction;
Figure 12 is a perspective elevation view of a third embodiment of the
apparatus
of the present invention showing an alternate buoy construction;
Figures 13-14 are elevation views of a fourth embodiment of the apparatus of
the
present invention showing an alternate articulating connection between each
buoy and the
platform. Figure 14 is rotated 90 degrees from Figure 13 around the
longitudinal axis of
the buoy;
Figure 15 is a schematic elevation view of a fifth embodiment of the apparatus
of the present invention;
Figure 16 is a partial elevation view of the fifth embodiment of the apparatus
of
the present invention;
Figure 17 is a side elevation view taken along lines 17-17 of Figure 16;
Figure 18 is a partially cut away elevation view of the fifth embodiment of
the
apparatus of the present invention;
Figure 19 is a partially cut away elevation view of the fifth embodiment of
the
apparatus of the present invention;
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Figure 20 is an elevation view of the fifth embodiment of the apparatus of the
present invention showing an angled position of the platform relative to the
buoys;
Figure 21 is an elevation view of the fifth embodiment of the apparatus of the
present invention showing an angled position of the platform relative to the
buoys;
Figure 22 is a partial elevation view of the fifth embodiment of the apparatus
of
the present invention illustrating removal of the pin for servicing the
internal universal
joints;
Figure 23 is another partial elevation view of the fifth embodiment of the
apparatus of the present invention showing removal of the internal universal
joint.
Figure 24 is a partial perspective, exploded view of the fifth embodiment of
the
apparatus of the present invention illustrating the internal universal joint;
and
Figure 25 is a partial perspective, exploded view of the fifth embodiment of
the
apparatus of the present invention showing the external universal joint.
Figure 26 is an elevation view illustrating the method of the present
invention,
specifically the first step of floating the marine platform to a desired
location next to a
plurality of buoys that will support the platform;
Figure 27 is an elevation view illustrating the method of the present
invention,
specifically the step of ballasting the buoys relative to the barge during a
connection of
the buoys to the oil and gas well drilling and/or production facility to be
supported;
Figure 28 is an elevation view illustrating the method of the present
invention
including the final step of ballasting the combination of structure and
plurality of buoys
until a desired elevational position is achieved;
Figure 29 is a perspective view illustrating the first step of the method of
the
present invention;
Figure 30 is a perspective view illustrating the second step of the method of
the
present invention;
Figure 31 is a perspective view illustrating an alternate method of the
present
invention wherein the apparatus of the present invention is used to place a
marine
platform upon a single spar support;
Figure 32 is a perspective view illustrating an alternate method of the
present
invention wherein the apparatus of the present invention is used to place a
marine
platform upon a single spar support;
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Figure 33 is an elevation view illustrating an alternate method of the present
invention wherein the apparatus of the present invention is used to place a
marine
platform upon a single spar support;
Figure 34 is an elevation view illustrating an alternate method of the present
invention wherein the apparatus of the present invention is used to place a
marine
platform upon a single spar support;
Figure 35 is an elevation view illustrating an alternate method of the present
invention, showing the platform after placement upon a single spar and removal
of all
supporting buoys.
DETAILED DESCRIPTION OF THE INVENTION
Figures 1-6 show a preferred embodiment of the apparatus of the present
invention designated generally by the numeral 10 in Figures 1-4. In Figures 1-
4, floating
marine platform apparatus 10 is shown in a marine environment or ocean 12
having a
water surface 11. The apparatus 10 includes a plurality of buoys 13-16,
preferably four
(optionally between three (3) and eight (8)), that support a superstructure
defined by the
combination of platform 17 and drilling and/or producing facilities 53. Oil
and gas well
producing facility as used herein shall include a facility used for oil and
gas well drilling
or production, or a combination of drilling and production.
Buoys 13-16 can be any desired shape, including the alternate buoys shown in
the
drawings or buoys with configurations like those in the September 2000 issue
volume 60,
issue 9 of Offshore Magazine, PennWell Corporation, Oklahoma, USA. Platform 17
can be
any desired platform or rig, such as a trussed deck constructed of a plurality
of upper
horizontal members 18, a plurality of lower horizontal members 19, a plurality
of vertical
members 20 and a plurality of diagonal members 21 to define a trussed deck or
platform 17.
As shown in Figure 1, platform 17 can include any desired oil and gas drilling
and/or
production facility 53, such facilities (in combination with platform 17)
defining a
superstructure weighing between about 500 - 100,000 tons(508,025 kg -
101,605,000 kg), or
between about 3,000 - 50,000 tons (3,048,150 kg - 50,802,500 kg). (See Figures
3 and 8).
Each buoy 13-16 has an upper end portion 22 that can be conically shaped at 23
(see Figures 5-6). An attachment portion 24 provides a convex upper surface 25
that
receives a correspondingly shaped concave surface 26 of connecting portion 27
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platform 17. The concave surface 26 can be generally hemispherically shaped.
However,
the concave surface 26 is curved to articulate upon the surface 25. Surface 26
is
preferably smaller than a full hemispherical surface, sized to articulate upon
surface 25
even wherein there is an angular variation that can be as much as 30 degrees
(or more)
between the central longitudinal axis 28 of buoy 13 and a pure horizontal
plane 29. To
address wear, conventionally available bearing materials may be used in the
articulating
connections. A preferred bearing material would be a graphite impregnated
brass or
bronze bushing.
The following equations can be used in sizing the buoys:
Heave Period T(heave) = 2T[i/(M/K)
Where M = total heave mass;
K = heave stiffness;
Heave Stiffness K = 1/4T[DZG
Where D = the diameter of the section of the buoy passing
through the water plane;
G = the unit weight of water (approximately 65 pounds
per cubic foot)(1,041.2 kilograms per cubic meter);
Heave Mass M = (Dry buoy mass) + (entrapped fluid mass) + (permanent
solid ballast mass) + (added virtual fluid mass)
The buoys may be constructed of stiffened steel plate, or continuously cast
(slip formed)
concrete or through other conventional construction techniques. Typically, a
number of
internal stiffeners are included to provide the required overall structural
strength.
The attachment portion 24 at the upper end of each buoy 13-16 can be
reinforced
with a plurality of vertical plates 30 as shown in Figure 6. Likewise, the
connection
portion 27 of platform 17 can be provided with a plurality of internal
reinforcing plates
35. The plates 35 extend between upper curved plate 36 and lower curved plate
37. A
conical plate 38 can be attached to (or can be integral with) upper curved
plate 36 as
shown in Figure 6. A square harness articulating connection (not shown) going
around
the primary articulating connection may also be used.
Platform apparatus 10 can be secured to the sea bed 51 using piling or anchors
52
and mooring lines 32, 41 (Figures 1-4, 8). In a preferred embodiment (Figures
1-4), one
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or more mooring lines 32 extend from each buoy 13-16 at an upper padeye 31 to
the sea
bed 51. The mooring lines in Figures 1, 2, 3 and 4 extend between padeyes 31
and
anchors 52 at sea bed 51.
In a preferred embodiment, a plurality of horizontal mooring lines 34 extend
between lower padeyes 33 on two buoys 13, 14 as shown in Figure 1. While the
lower
horizontal mooring lines 34 are shown connecting to buoys 13, 14, it should be
understood that each pair of buoys (14-15, 15-16, 16-13) has a horizontal line
34
extending there between in the same configuration shown in Figure 1.
Figure 7 shows a first alternate embodiment of the present invention,
utilizing
tensioned mooring lines 39 that extend between connection points (for example,
padeyes) 40 on each of the buoys 13-16 and anchors (such as 52) embedded in
the sea
bed 51. In the embodiment of Figure 7, horizontal mooring lines 34 could
optionally be
provided between each pair of buoys such as 13 and 14, or 14 and 15, or 15 and
16, or
16 and 13.
Figure 8 shows an alternate arrangement wherein caternary mooring lines 41
extend between padeyes 31 and the anchors 52 that are anchored to the sea bed
51. In
this embodiment, there are no horizontal lines connecting the buoys.
The plan view of Figure 2 shows various orientations that could be used for
either
mooring lines 32 or mooring lines 41. One arrangement provides a plurality of
three
mooring lines 32 or 41 attached to each buoy 13-16, the mooring lines 32 or 41
being
spaced about 120 degrees apart as shown in hard lines. In phantom lines in
Figure 2,
another geometry for the mooring lines 32, 41 is shown, wherein there are two
mooring
lines for each buoy that are about 90 degrees apart.
The platform 17 is constructed of upper and lower sets of horizontal members
18,
19; vertical members 20; and diagonal members 21.
Figures 9, 10 and 1 OA show an alternate construction for each of the buoys.
It
should be understood that a buoy such as one of those shown in Figures 9, 10
or 1 OA
could be used to replace any one or all of the buoys 13-16 shown in Figures 1-
4 and 5-6.
Buoy 42 can be provided with a variable diameter having a smaller diameter
cylindrical middle section 43, and a larger diameter lower section 44 which
can be for
example, either cylindrical (see Figure 10) or squared (see Figure 1 OA). The
cylindrical
lower section 44 is shown in Figures 9 and 10, and the squared lower section
45 shown
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in Figure 1 OA.
Another buoy construction is shown in Figures 11 and 12. It should be
understood
that the buoy shown in Figures 11 and 12 could be used to replace any one or
all of the
plurality of buoys 13-16 of Figures 1-6. In Figures 11 and 12, the buoy 46 has
a
cylindrical middle section 47, a conical upper section 48, and a trussed lower
section 49.
Padeyes 50 on the upper end portion of trussed lower section 49 can be used to
support
any of the earlier described mooring lines such as 32, 39, or 41. In the
embodiment of
Figures 11 and 12, each of the buoys 46 can have a similar construction and
configuration
at the upper end portion to that of a preferred embodiment shown in Figures 1-
6,
providing a conical upper section 48 and an attachment portion 24.
In Figures 13 and 14, there can be seen an alternate articulating connection
between platform 17 and a selected buoy 13 (or 14-16 or 42, or.46). A gimble
or
universal joint 62 arrangement is shown in Figures 13 and 14, providing a
first pinned
connection at 54 and a second pinned connection at 55. The first pin 56 can be
of a larger
diameter, having a central opening 58 through which the second, smaller
diameter pin 57
passes as shown. The central longitudinal axes of the pins 54, 55 preferably
intersect.
Arrow 59 in Figures 13-14 shows that a buoy can optionally be made to rotate
relative
to the gimbal connection shown. Bearing plates 60, 61 can rotate relative to
one another.
To minimize frictional force transference and wear, both pins 56,57 can be
mounted in
bearings.
Figures 15-25 show a fifth embodiment of the apparatus of the present
invention,
designated generally by the numeral 63 in Figure 15. Floating marine platform
apparatus
63 is shown in Figure 15 as including a platform 17 that can include a
structural deck,
package, platform, trussed deck or the like which has been shown in phantom
lines. It
should be understood that platform 17 shown in Figure 15 can include a
structural deck
64 or any other structural frame that is known in the art for supporting an
offshore oil and
gas well drilling platform, and oil and gas well production facility, or an
oil and gas well
drilling and production facility 67.
Platform 17 can include a structural deck which is schematically illustrated
using
the numeral 64 in Figures 15-25 including a superstructure (e.g. with an oil
drilling
platform, oil production platform, crew quarters, heliport, vessels, and the
like). A
plurality of connections are shown, a connection interfacing between each buoy
13, 14,
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15, 16 and the platform 17 to be supported.
In the embodiment of Figures 15-25, the connection that is positioned in
between
each buoy such as buoy 13 and platform 17 is preferably a connection that
includes first
and second connection devices and a load transfer mechanism that can transfer
at least
some of the platform load from one of the devices to the other device.
In the fifth embodiment, these devices preferably include an internal device
65
(see Figure 24) and an external device 66 (see Figure 25). In the embodiment
of Figures
15-25, the internal 65 and external 66 devices are preferably articulating
connections. In
the embodiment of Figures 15-25, the devices 65, 66 are preferably each
universal joint
connections.
In the embodiment of Figures 15-25, a load transfer mechanism enables load to
be transferred from one of the devices 65 or 66 to the other device 65 or 66.
This load
transfer mechanism is preferably a j acking system such as the plurality of
hydraulic j acks
119 that are shown in the drawings.
In Figure 25, a deck opening 68 is shown through which the internal device 65
can be removed for servicing. The internal device 65 can be the device that
typically
carries a portion of the platform load for a majority of the time and
transfers that load to
its buoy such as buoy 13. At deck opening 68, padeyes 69 are provided each
having an
opening 70 as shown in Figure 25.
The details of construction of the internal device 65 are shown in Figure 24.
The
internal device 65 includes a lower section 71, and upper section 82, and pins
77, 90. The
lower section 71 has a bottom 72 that transfers load to the upper surface 124
of buoy 13.
When load is to be transferred to the second device 66 of Figure 25, a j
acking mechanism
such as the plurality of hydraulic jacks 119 lift the lower section 71 from
upper surface
124 of buoy 13, as shown in figure 22. A gap 123 is then present in between
the upper
surface 124 of buoy 13 and the bottom 72 of lower section 71. In such a
position (shown
in Figure 22), pin 120 can be removed and the internal device 65 can be lifted
upwardly
and withdrawn through opening 68 in structural deck 64.
Lower section 71 has sides 73, a top 74 and a pair of padeyes 75 that are
spaced
apart and which extend from the top 74. Each padeye 75 has pin opening 76. A
smaller
pin 77 has enlarged head 78 and externally threaded section 79. Nut 80
provides an
internally threaded section 81 that enables the nut 80 to be threadably
engaged to the pin
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77 at threads 79. Upper section 82 of internal device 65 provides sides 83 and
payeyes
84 that extend downwardly as shown in Figure 24, each padeye 84 providing a
pin
opening 85.
Upper section 82 provides a pair of spaced apart beams 86, each having end
portions 87, 88. Each end portion 87, 88 provides a pin opening 97. A larger
pin 90 fits
through openings 85 as indicated schematically by arrow 126 in Figure 24. Pin
90 has
enlarged head 91, and externally threaded section 92. Larger pin 90 also
provides an
opening 93 that is positioned in between externally threaded section 92 and
head 91 as
shown in Figure 24.
Nut 94 has internally threaded section 95 that enables the nut to be
threadably
engaged with the larger pin 90. A gap 96 is provided in between the beams 86
so that
padeyes 69 on structural deck 64 fit in between the spaced apart beams 86 in
gap 96 as
shown in the drawings (see Figures 16 and 18). In this position, the openings
70 of
padeyes 69 align with the openings 97 of beams 86. Pins 120 can then be placed
through
the aligned openings 70, 97. Upon assembly of the device 65, larger pin 90 is
first passed
through openings 85 of padeyes 84. Nut 94 is then threadably engaged with pin
90 at
correspondingly engaging threaded portions 92, 95. The pin 77 is then placed
through one
of the openings 76 of padeye 75, and then through opening 93 of larger pin 90
and then
through the opposite opening 76 of padeye 75. Nut 80 then retains smaller pin
77 by
engaging the threaded portions 79, 81. In this position, the internal device
65 defines a
first universal joint (see Figure 23) that can be removed as shown by arrow
128 in figure
23 for servicing.
The devices 65, 66 can be universal joints as shown. Each of the universal
joints
each have multiple pins 77,90 (for device 65) and 110 (for device 66) with
central
longitudinal axes, the central axes of the pins 77, 90 and 110 of both
universal joints
occupying a common plane during use.
When the internal device 65 is removed for servicing, the external device 66
carries a portion of the platform load between structural deck 64 and buoy 13.
The
external device 66 is shown more particularly in Figure 25. External device 66
includes
a pair of spaced apart lower supports 98, each having a pair of spaced apart
padeyes 99,
each of the padeyes 99 providing a pin opening 100.
A pair of lower beams 101 are provided, a beam 101 being pivotally attached to
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each lower support 98 as shown in Figure 25. Each lower beam 101 provides end
portions
102, 103, each of the end portions 102, 103 providing an upper surface 104
that carries
a hydraulic jack 119. Each of the lower beams 101 provides a beam opening 105
that
receives a pin 110 when the opening 105 aligns with openings 100 of padeyes
99.
The external device 66 includes a pair of spaced apart supports 115 that are
connected (eg. welded or bolted) to the underside of structural deck 64 for
transferring
load from the external device 66 to structural deck 64. Upper beams 106 are
pivotally
attached to upper supports 115 using pins 110. Each of the upper supports 115
has a pair
of spaced apart padeyes 116, each padeye 116 having an opening 117 for
receiving a pin
110. Each upper beam 106 provides end portions 107, 108 having a lower surface
109
that is engaged by an elevating portion 129 of hydraulic jack 119 when load is
to be
carried by the external device 66. It should be understood that the hydraulic
j acks 119 are
commercially available such as from Enerpac.
Each pin 110 has an enlarged head 111 and an externally threaded section 112.
Pins 110 are retained in position using nuts 113. Each nut 113 has an
internally threaded
section 114 that engages the externally threaded section 112 of pin 110. Each
of the upper
beams 106 has a beam opening 118 that receives pin 110. In order to effect the
pivotal
connection between upper supports 115 and upper beams 106, pins 110 are passed
through the openings 117 of padeyes 116 and the beam openings 118. The pins
110 are
then secured by fastening a nut 113 to threaded section 112.
In the embodiment of Figures 15-25, it is preferable that the internal device
65
carry load between a buoy (for example 13), and structural deck 64 a majority
of the time.
Therefore, there is typically a small gap between the elevating portion 129 of
each jack
119 and the undersurface 109 of beam ends 107, 108. In such a situation, the
bottom 72
of lower section 71 of internal device 65 bears against the upper surface 124
of buoy 13.
In order to service the internal device 65 (or to replace it), the hydraulic
jacks 119 are
actuated so that elevating portion 129 elevates until the elevating portion
129 engages
lower surface 109 of each beam end 107, 108. Continued elevation of the jack
119
elevating portions 129 causes upper beams 106 to move away from lower beams
101.
Such elevating of the jacks 119 increases the distance between structural deck
64 and the
upper surface 124 of each buoy 13, 14, 15, 16. Eventually, the lower surface
72 of the
lower section 71 rises above upper surface 124 of buoy 113 (see Figure 22)
thus
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removing platform load from the internal device 65. Pin 120 is then removed by
disassembly of retainer nut 122 from pin 120 as schematically indicated by
arrow 89 in
Figure 22. A gap 123 between lower section 71 and buoy 13 is shown in Figure
22.
Arrow 128 in Figure 23 schematically illustrates the lifting of internal
device 65 upwardly
for removal and servicing. The external device 66 in Figure 23 now carries
load between
structural deck 64 and buoy 13.
In Figures 26-28 and 29-30, a method of the present invention is disclosed. In
Figure 29, arrow 153 designates travel of a transport barge 163 toward a
plurality of
buoys 13, 14, 15, 16 that have been positioned at a desired location. Buoys
13, 14, 15, 16
are held in that position using for example, a plurality of anchor lines 32 as
shown in
Figures 26-30.
Transport barge 163 provides an upper deck 164, a bottom 165, a port side 166
and a starboard side 167. The barge 163 also has end portions 154, 155.
Transport barge
163 can be any suitable barge having a length, width, and depth that are
suitable for
transporting a multi-ton superstructure to a job site. Typically, such a
superstructure 53
mounted upon platform 17 will be a multi-ton structure that is capable of
performing oil
and gas well drilling activities and/or oil and gas well production
activities.
In Figure 30, barge 163 has been positioned next to the plurality of buoys 13,
14,
15, 16. As an example, Figures 29-30, the transport barge 163 has been
positioned so that
the buoys 13, 16 are on the starboard side 167 of transport barge 163. The
buoys 14, 15
are positioned on the port side 166 of transport barge 163 as shown in Figures
26-28 and
30.
Once in the position shown in Figures 26 and 30, a ballasting operation moves
the
buoys 13, 14, 15, 16 into contact with the platform 17 so that a connection is
perfected.
More specifically, the attachment portions 24 of the respective buoys 13, 14,
15, 16
engage and form an articulating connection with the corresponding connecting
portions
27 of platform 17 as shown in Figures 26-28 and in Figures 1-8 and 13-14.
Ballasting can be achieved by initially adding water to the buoys 13, 14, 15,
16
so that they are at a lower position in the water as shown in Figures 26 and
29-30. The
water can then be pumped from the interior of each of the buoys 13, 14, 15, 16
as
indicated schematically by the numeral 60 in Figure 27. As water is removed
from the
interior of each of the buoys 13-16, the water level 151 in each of the buoys
13-16 will
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drop and each of the buoys 13-16 will rise as indicated schematically by
arrows 170 in
Figure 27.
Each of the buoys 13, 14, 15, 16 will be ballasted upwardly in the direction
of
arrows 170 until its attachment portion 24 forms a connection with the
connecting portion
27 of platform 17. Alternatively, the barge 163 can be positioned as shown in
Figures 26
and 30. The barge 163 can then be lowered so that the barge 163, platform 17
and
drilling/production facility 53 lower with it until the connection portions 27
of platform
17 rest upon the attachment portions 24 of the buoys 13-16.
As still a further alternative, a combination of ballasting of barge 163 and
buoys
13, 14, 15, 16 can be used to connect each of the attachment portions 24 of
buoy 13, 14,
15, 16 to platform 17 so that the attachments shown in Figures 1, 2, 3, 4, 7,
8 are
achieved. For example, barge 163 can be lowered using ballasting while buoys
13, 14,
15, 16 are simultaneously elevated using ballasting.
For the embodiment of Figures 13 and 14, a similar ballasting arrangement can
be provided wherein the pinned connections 54, 55 are added after the platform
17 and
buoys 13, 14, 15, 16 are at the proper elevational positions relative to one
another.
Once the superstructure that includes platform 17 and facility 53 is supported
as
shown in Figure 28, the superstructure (platform 17 and facility 53) can be
placed upon
a single spar support 156 if desired using the apparatus 10 of the present
invention as a
transfer apparatus.
After removal of barge 163 (see Figures 26-30), tow boats 159 can be used to
tow
each buoy 13, 14, 15, 16 to spar 156. For example, each boat 159 can provide a
tow line
160 attached to a buoy 13, 14, 15 or 16, or to deck 17 at a provided
attachment 161.
In Figures 31, 32, and 33, the boats 159 pull buoys 13, 14, 15, 16 to a
position as
shown that overlays platform 17 with upper end portion 157 of spar 156.
Ballasting can
then be used to either elevate spar 156 or lower buoys 13, 14, 15, 16 (or a
combination
of such ballasting can be used) to engage spar 156 upper end portion 157 with
platform
17 as indicated by arrow 162 in Figure 34.
Additional ballasting separates each buoy 13, 14, 15, 16 from platform 17 so
that
spar 156 alone supports platform 17 and its facility 53 (see Figure 35).
PARTS LIST
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PART NUMBER DESCRIPTION
floating marine platform apparatus
11 water surface
12 ocean
5 13 buoy
14 buoy
buoy
16 buoy
17 platform
10 18 upper horizontal member
19 lower horizontal member
vertical member
21 diagonal member
22 upper end portion
15 23 conical shape
24 attachment portion
convex surface
26 concave surface
27 connecting portion
20 28 central longitudinal axis
29 plane
internal reinforcing plate
31 upper padeye
32 mooring line
25 33 lower padeye
34 horizontal mooring line
internal reinforcing plate
36 upper curved plate
37 lower curved plate
30 38 conical plate
39 tensioned mooring line
padeye
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41 caternary mooring line
42 buoy
43 cylindrical middle section
44 cylindrical lower section
45 square lower section
46 buoy
47 cylindrical middle section
48 conical upper section
49 trussed lower section
50 padeye
51 sea bed
52 anchor
53 drilling/production facility
54 first pinned connection
55 second pinned connection
56 pin
57 pin
58 opening
59 arrow
60 bearing plate
61 bearing plate
62 universal joint
63 floating marine platform apparatus
64 structural deck
65 internal device
66 external device
67 facility
68 deck opening
69 padeye
70 opening
71 lower section
72 bottom
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73 side
74 top
75 padeye
76 pin opening
77 smaller pin
78 enlarged head
79 externally threaded section
80 nut
81 internally threaded section
82 upper section
83 side
84 padeye
85 pin opening
86 beam
87 end portion
88 end portion
89 arrow
90 larger pin
91 enlarged head
92 externally threaded section
93 opening
94 nut
95 internally threaded section
96 gap
97 pin opening
98 lower support
99 padeye
100 pin opening
101 lower beam
102 end
103 end
104 upper surface
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105 beam opening
106 upper beam
107 end
108 end
109 lower surface
110 pin
111 enlarged head
112 externally threaded section
113 nut
114 internally threaded section
115 upper support
116 padeye
117 pin opening
118 beam opening
119 jack
120 pin
121 enlarged head
122 retainer nut
123 gap
124 top of buoy
125 arrow
126 arrow
127 arrow
128 arrow
129 elevating portion
150 water discharge
151 water level
152 buoy interior
153 arrow
154 end portion
155 end portion
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156 spar
157 upper end portion
158 arrow
159 tow boat
160 tow line
161 attachment
162 arrow
163 barge
164 barge deck
165 bottom
166 port side
167 starboard side
168 bearing plate
169 bearing plate
170 directional arrows
The foregoing embodiments are presented by way of example only; the scope of
the present invention is to be limited only by the following claims.
23
