API RP 2T-2010 Planning, Designing, and Constructing Tension Leg Platforms

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LANNING

ESIGNING

AND

ONSTRUCTING

ENSION

LATFORMS

241

D.4.2.2.5 Section D.4.2.2.1 c) relates to the development of progressive pile failure due to the axial

flexibility of the pile-soil system under cyclic loading conditions. Two-way (i.e. tension-compression) load tests

conducted in the above mentioned studies show an immediate degradation in pile capacity. Results from the

full-scale Beta pile test (Doyle and Pelletier, 1985

[125]

) showed temporary reductions of 61 % to 85 % of the

precyclic pile capacity within 16 fully reversed load cycles. In addition, the weight of the soil plug was not

evident during cyclic testing. However, other testing at Haga by NGI (Karlsrud, K., and Haugen, T., 1981

[165]

)

suggests that one-way cyclic loading of the pile relative to the soil causes significantly less degradation than

two-way loading at discrete pile elevations. For long flexible piles, fully reversed cycling may occur even

though the pile top is under a sustained bias loading. Thus, pile load capacity may be reduced due to cyclic

loading for flexible piles.

D.4.2.2.6 Section D.4.2.2.1 d) considers the effect of sustained tension loading on soil behavior. Soils

under sustained shear stress may deform in time. This effect should be considered in determining the long-

term capacity of piles under sustained loading.

D.4.2.2.7 Section D.4.2.2.1 e) represents a consideration, which can be expected to aid the foundation’s

load carrying capacity. Since here again it is not possible to reliably quantify the effects of suction, it was

decided to ignore this consideration.

D.4.2.3 Lack of Residual Strength of the Soil-pile System

A consideration included under this factor is the relative lack of residual strength for a pile loaded in tension

compared to one loaded in compression. Schematically, the relative residual strength after pile overload in

tension (T), and compression (C) may be viewed as shown in Figure D.1.

The potential for dramatic decreases in strength in the event of pile overload warrants an increased safety

factor when compared to a compression pile. The assignment of specific numerical values to account for a

tension pile’s relative lack of residual strength is uncertain.

Figure D.1—Relative Residual Strength After Pile Overload

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242 API RECOMMENDED PRACTICE 2T

D.4.2.4 Load Redistribution Capacities of the Foundation

Redundancy in the form of clustered or grouped piles can mitigate concern over the lack of residual strength,

since all piles would not reach their maximum capacity simultaneously. The bias factor should reward

redundancy.

D.4.2.5 Relative Difficulty of Foundation Installation

The relative ability to install satisfactory driven piles is deemed comparable to the skirt piles of a jacket-type

structure. For drilled and grouted piles and for connections between a pile and a foundation template, it is

believed that these should be attainable in a manner comparable to a jacket platform. However, it is believed

necessary to explicitly mention that special means should be provided to verify that grouted piles and pile to

template connections are installed in a manner conforming to the design.

NOTE Provided explicit mention was made of the need to provide means to verify the adequacy of grout and pile to

template connection installation.

D.4.2.6 Relative Integrity of Soil Samples Obtained from Deepwater

In this regard it is believed that adequate precautions are already mentioned in 10.2.2. It is also felt that the

geotechnical consultant in conjunction with the operator’s staff, could properly interpret engineering soil

properties resulting from deepwater soil samples.

D.4.2.7 Relative Character and Reliability of Load Determination

The determination of loading is assumed to be comparable to that obtained for a jacket structure.

D.4.2.8 Relative Lack of Ability to Inspect and Repair TLP Foundation Piles

The ability to inspect and repair TLP piles was deemed to be very similar to that of jacket-type structure.

D.4.3 Consequences of a Foundation Failure to the Integrity of the Overall Structural System

The consequence of a foundation failure for a TLP was deemed to be comparable to that of a jacket-type

structure if a multi-pile bottom template is used to house the tendon receptacles. For the direct-connection

method, pile failure is not comparable to that of a jacket-type structure. The number of piles per corner and

the ultimate capacity of all the piles at the corner should be considered in evaluating the possible failure of a

single pile when the

B-factor is selected.

D.5 Discussion on Large Lateral Pile Deflections

Because it is a free-head pile, the direct-connect method may result in lateral deflections that exceed the

criterion on which API 2A-WSD is based (see Matlock and Tucker, 1961

[186]

and Matlock, 1970

[187]

). The

lateral deflections for the tests at Sabine, for example, did not exceed about 25 % of the pile diameter.

Therefore, in lieu of other data, it may be assumed in clay soils that when lateral deflections (for the pile in the

soil) exceed about 25 % of the pile diameter, the

(i.e. ultimate lateral resistance) given in API 2A-WSD

should be reduced by the ratio of remolded to undisturbed strength and that the cyclic soft clay criteria

governs the shape of the curve. This is based on published model test data and centrifuge tests by Doyle et

al. (2005)

[129]

that indicate a reduced Pu is appropriate when lateral deflections exceed about 25 % of the pile

diameter. In applying this recommendation, the criteria given in API 2A-WSD is followed until the pile

deflection exceeds 25 % of the diameter. At that time the

p-y curves are generated as normal until the value of

p/p

reaches the ratio of the remolded to undisturbed shear strength. At that time, all further values given in

API 2A-WSD for

p/p

shall not exceed the ratio of remolded to undisturbed shear strength. The associated

values of

x/x

shall remain the same.

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243

Annex E

(informative)

Drilling and Production Interacting Checklists

A good working design is often seriously weakened by a lack of definition between the various design

disciplines on how the drilling rigs interface with the TLP. Drilling rig interface points with TLPs are provided in

Tables E.1 through E.3.

Table E.1—Structure Layout Interface Checklist

Item Structure Layout Interface Point

1 Position and strength of beams and trusses on platform deck(s)

2 Allowable loadings for deck areas between major support members

3 Deck layout plans for open areas

4 Design loads due to wind on drilling packages

5 Dynamic loads from drilling packages resulting from horizontal accelerations of platform

6 Loading conditions from drilling packages due to construction, tow out and temporary

mooring phases

7 CG and weight impact due to rig layouts, drilling live loads, and rig packaging/module

design

8 Rig skid beam spacing, position, and strength

9 Jacking systems that can be accommodated

10 Elevation of well heads

11 Strength and layout of local beams around wellhead area

12 Strength points available for pulling heavy loads; eg, hanging BOP units

13 Position of “rat” and “mouse holes”

14 Access into/out of the hull for equipment when the drill rig is in place

15 Increased accommodation needs

16 Use of brine tanks in the hull

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244 API RECOMMENDED PRACTICE 2T

Table E.2—Utilities Interface Checklist

Item Utilities Interface Systems and Equipment

1 Sharing with production systems

2 Lightweight machinery valving and piping

3 Area classification requirements resulting from drilling rig modules

4 Liquid storage in hull vs decks—consideration should be give between weight and CG

positive impacts and negative fire and gas and hazardous area effects

5 Piping for fuel, water, etc., and transfer to and along the platform

a) location distribution, size and number

b) access points

6 Electrical power and communication/instrumentation

a) quantity, distribution and location of cables

b) remote bop control points (including prerun hydraulic lines)

c) drilling instrumentation

Table E.3—Rig Services Interface Checklist

Item Utilities Interface Systems and Equipment

1 Drilling drains, sumps, and solids handling to avoid coating or plugging lines, sumps, or

other discharge points

a) down comers for overboard disposal of cuttings from shale shakers, desilters,

desanders, and sand traps

b) drilling mud from active and reserve mud pits

c) cement and cooling water

2 Impact of solid discharges on underwater equipment structures or intakes

3 Supply barge handling and consumable loading/unloading

4 Handling and operations of drilling risers, blowout preventers and deep well tools

5 Penetrations through the hull to be used for acoustical positioning equipment (serious

consideration should be given to locating this type of system outside the hull)

6 ROV interfaces ROVs shall be able to plug all penetrations ROVs are limited in the

amount of direct overhead work they can do and penetration design shall keep this in

mind

7 Maintenance and operations of equipment used by the drilling team but located in the

hull in areas that affect watertight integrity shall be agreed by both teams

8 If used, the weight of brine and the possibility and impacts of tank overflowing shall be

considered both by the structural group and the marine systems group

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245

Annex F

(informative)

Regulations Governing TLPs

F.1 USCG Regulations for TLPs Located in U.S. Waters

Applicable regulations for TLPs in U.S. waters include the following.

a) 33 CFR Parts 140 to 147 (Subchapter N), Outer Continental Shelf Activities. These regulations stipulate

requirements for identification marks for platforms, means of escape, guard rails, fire extinguishers, life

preservers, ring buoys, first aid kits, etc.

b) 46 CFR Parts 107 to 109 (Subchapter IA), Mobile Offshore Drilling Units. These regulations govern the

inspection and certification design and equipment and operation.

c) 46 CFR Parts 50 to 64 (Subchapter F), Marine Engineering. These regulations prescribe the

requirements for materials construction, installation, inspection and maintenance of boilers, unfired

pressure vessels, piping and welding.

d) 46 CFR Parts 110 to 113 (Subchapter J), Electrical Engineering. These regulations prescribe in detail the

electrical engineering requirements for vessels.

e) 33 CFR Part 67, Aids to Navigation on Artificial Islands and Fixed Structures. These regulations prescribe

in detail the requirements for installation of lights and foghorns on offshore structures in various zones.

f) Oil and Pollution Act (OPA 90); governs storage of hydrocarbons at the waterline.

g) Minerals Management jurisdiction for TLPs located in U.S. waters

⎯30 CFR Part 250⎯oil and gas and

sulfur operations in the outer continental shelf and outer continental shelf orders for U.S. waters. These

orders govern the marking, installation, operation, and removal of offshore structures and facilities.

F.2 International Regulations

Applicable international regulations include the following:

a) International Maritime Organization (IMO), Code for the Construction and Equipment of Mobile Offshore

Drilling Units [Resolution A.414 (XI)].

b) International Regulations for Preventing Collisions at Sea, Rule 24a, Towing and Pushing.

c) International Electrical Code (IEC).

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246

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PLANNING, DESIGNING, AND CONSTRUCTING TENSION LEG PLATFORMS 247

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248 API RECOMMENDED PRACTICE 2T

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PLANNING, DESIGNING, AND CONSTRUCTING TENSION LEG PLATFORMS 249

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⎯

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⎯

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⎯

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⎯

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