recommended guidelines for remote pipe handling operations.pdf

081 – NORWEGIAN OIL AND GAS

RECOMMENDED GUIDELINES

FOR

REMOTE PIPE HANDLING

OPERATIONS

Translated version

Norwegian Oil and Gas Association recommended guidelines for remote pipe handling

operations

No. 081 Established: 30.04.03 Revision no. 5 Date revised: 03.06.2015 Page: 2

Preface

This guideline is supported by the Norwegian Oil and Gas Drilling Managers Forum,

the Norwegian Shipowners’ Association (NSA) and the Petroleum Safety Authorities (PSA).

Furthermore the Norwegian Oil and Gas Operations Committee has recommended this

guideline, and it has been approved by Norwegian Oil and Gas general director.

This Norwegian Oil and Gas guideline has been prepared with the broad-based participation

of interested parties in the Norwegian petroleum industry, and they are owned by the

Norwegian petroleum industry, represented by Norwegian Oil and Gas. Norwegian Oil and

Gas is responsible for administration of these guidelines.

Norwegian Oil and Gas Association

Vassbotnen 1, Sandnes

P.O. Box 8065

4068 Stavanger, Norway

Tel.: + 47 51 84 65 00

Fax: + 47 51 84 65 01

Web site: www.norskoljeoggass.no

E-mail: [email protected]

http://www.norskoljeoggass.no/


operations


Table of contents

1 OBJECTIVES.................................................................................................................................. 4

2 ABBREVIATIONS ........................................................................................................................ 5

3 HIGHLIGHTING CHANGES TO A GUIDELINE .................................................................. 6

4 DISTRIBUTION LIST ................................................................................................................... 7

5 VALIDITY ...................................................................................................................................... 7

6 TASK DEFINITIONS ................................................................................................................... 7

7 GENERAL REQUIREMENTS ..................................................................................................... 8

8 PROCEDURE FOR APPLICATION FOR EXEMPTION ........................................................ 9

9 MARKING OF EQUIPMENT ................................................................................................... 10

9.1 PURPOSE ............................................................................................................................. 10

9.2 EXAMPLES OF EQUIPMENT TO BE MARKED .......................................................... 10

9.3 RENTED EQUIPMENT ..................................................................................................... 10

10 GUIDELINES FOR FILLING IN THE MATRIX ................................................................ 11

10.1 HEADING .............................................................................................................................. 11

10.2 TABLE ..................................................................................................................................... 11

10.3 FOOTER .................................................................................................................................. 12

11 ATTACHMENTS .................................................................................................................... 13

11.1 ATTACHMENT 1: DEVIATION MATRIX ........................................................................ 13

11.2 ATTACHMENT 2: REMOTE OPERATED EQUIPMENT FAILURES .......................... 24

11.3 ATTACHMENT 3: PULLING DEFORMED OR IMPAIRED PIPES .............................. 25

11.4 ATTACHMENT 4: FAILURE IN ANTI-COLLISION SYSTEM ....................................... 25


operations


1 OBJECTIVES

This document describes the guidelines and routines for Norwegian Oil and Gas/NSA

members in order to establish a practical implementation of PSAs requirements set forth in

the Facilities regulations and the Activities Regulations, with regards to remote pipe

handling operations.

The intention of this document is to establish a common understanding of what is realistic

to achieve for existing drilling and well intervention units with respect to safe remote pipe

handling operations, in order to meet the intentions set forth in PSAs regulations, with

available proven equipment.

The guideline must be considered together with the entire regulations. This shall apply

for, however not limited to, the framework regulations regarding principles for risk

reduction. The framework regulations regarding general requirements for material and

information, the framework regulations regarding exemptions and the Management

Regulations regarding handling of non-conformances.

New drilling unit projects, upgrades and replacement projects should have the objective to

reduce the extent of manual pipe handling operations even further than described in this

document.


operations


2 ABBREVIATIONS

DMF - Drilling Managers Forum

HTV - Horizontal to vertical

PSA - Petroleum Safety Authority

NSA - Norwegian Shipowners Association

OC -Operations Committee

M -Manual operation

R - Remote operation

NA - Not Applicable


operations


3 HIGHLIGHTING CHANGES TO A GUIDELINE

All references in the guideline 081 concerning specific paragraphs to Petroleum Safety

Authority are removed.

Preface is made general and do not include working group with names who has prepared

the revision work.

Section 4 – The guideline is made public on the Norwegian oil and gas web-site and will not

be distributed.

Section 5 – The document is valid from 01.07.2015

Section 7 - Manual operations as a result of equipment failure can be regarded as training.

Section 9 is changed from “Colour coding of equipment” to “ Marking of equipment”. All

colour coding is removed from this document. The equipment shall be marked properly and

be easy to identify and correspond with the documentation. Equipment that is not marked

shall not be used.

Section 10 – Heading – Performed date is included.

Attachment 11.1 Deviation matrix – No 9 Non Magnetic DC, reference R2 is included (same

comment as for no. 2 DC). Refer to attachment 3 for deformed or impaired pipes regarding

no. 11 Casing and nr. 12 Non magnetic Casing


operations


4 DISTRIBUTION LIST

This document will be available on Norwegian Oil and Gas web site

www.norskoljeoggass.no. The Document is named “Norwegian Oil and Gas/NR-081

Recommended guidelines for remote pipe handling operations”.

5 VALIDITY

This document is valid from 1st July 2015.

6 TASK DEFINITIONS

The intention of this document is to give the Norwegian Oil and Gas/NSA member

companies a practical description of guidelines and routines on how to implement PSAs

requirement set forward in the facility regulation and the activity regulation. This document

is based on the following documentation:

Identification of all relevant remote operated sub operations and associated handling

routes from original position on deck until it has been secured at the rotary table, ref.

definition in facilities regulations.

Analysis of each sub operation, with indication that operation can be conducted safely

with the available remote operated field proven equipment.

Identified realistic operational status (R=Remote operated, M=Manual operated or

NA=Not applicable) for each sub-operation and handling sequence.

Pipe handling related to hydraulic well operations (CT or Snubbing) is not considered in

this document.

http://www.olf.no/


operations


7 GENERAL REQUIREMENTS

The following procedure:

All pipe handling that can be remotely operated shall be handled in this manner as long

as this improves the overall safety level. IF manual handling is chosen, regardless of

possible remote handling solutions, a documented risk assessment SHALL be

established. Remote operations shall be performed from a safe position away from

exposed area. Each installation shall, on an individual basis, define the safe area (Red

Zone).

Handling procedures shall be established for all planned manual pipe handling

operations marked ”M” in the matrix. These procedures must be based on risk analysis

(HAZID). HAZID shall be repeated at least every 3 years and in relation to changes that

will affect the pipe handling. HAZID shall be stored in a way that makes it available on

the Rig. HAZID shall be conducted in accordance to ISO 17776.

For planned manual operations, the rig specific handling procedures must be examined

before the manual operation starts.

For none planned manual operation, ref. Equipment failure or other (Attachment 2 and

4), a Safe Job Analyzes must be carried out before the operation starts. The

manufacturer's user manual shall be available and examined before the equipment is

used.

This guideline together with rig specific matrix and manual procedures shall be readily

available for the users at all times.

Any pipe handling operation not covered in this document is not considered relevant

with regards to the PSA requirements in facility regulation and activity regulation. Such

operations must carried out in accordance with relevant lifting and material handling

requirements as described in NORSOK R-002/R-003 and other relevant parts of PSA

regulation.

Existing internal procedures for manual pipe handling operations must be updated in the

rig specific matrix on a continuous basis.

Personnel directly involved in pipe handling operations shall have competency as

outlined by activity regulation (lifting operations) and attachment B in NORSOK R-003.

Simulator training is recommended where relevant and possible.

Training should include emergency operation of handling equipment.

In order to maintain experience with manual operations, traceable and documented

training of personnel shall be performed on a regular basis; ref. activity regulation

regarding organisation and competence. Documentation e.g., can be documented directly

in daily drilling report. Each organization defines the need for training. The training shall

be based on possible failures in existing remote operated pipe handling equipment on

installation. A minimum frequency for training should be once per offshore period (14

days). The training should be intensified based on changes in personnel / crew

composition, the competence of the crew and introduction of new equipment. Manual


operations


operations as a result of equipment failure can be regarded as training, reference are

made to attachment 2. A failure of the anti collision system shall be treated in accordance

with attachment 4. Equipment being used shall at all times have updated operating

instructions and documentation according to current regulation.

8 PROCEDURE FOR APPLICATION FOR EXEMPTION

The companies shall have a dynamic approach to the requirements in the Activity

Regulations and the Facility Regulation in order to implement as soon as possible,

reference to the Framework HSE regulation regarding ”continuous improvement” and

risk reduction principles. It is emphasised that all of the PSA regulation shall be

followed meaning that the companies are responsible for being in compliance with the

regulation with reference to the Framework HSE regulation regarding prudent activities.

Norwegian Oil and Gas/NSA members shall verify the rig status in connection with

every rig operation and identify all non-conformances related to the requirements

established in this document.

Each company should adapt the guidelines in Attachment 2, 3 and 4 to own organisation.

Application shall not be sent to PSA regarding exception from the Activity Regulations

and the Facility Regulation. Potential deviations from this guideline shall be considered

within the company.


operations


9 MARKING OF EQUIPMENT

Marking must be performed in such a way that there will be no conflict or confused with

other relevant marking.

9.1 PURPOSE

That the combination of equipment to the different dimensions is correct

Increase efficiency during assembling

Marking is to prevent mismatch of handling equipment and tubulars. However, each

individual is responsible for ensuring that equipment has the correct labelling/tagging or

markings required, and according to corresponding documentation, before equipment is put

in operation. The equipment shall be marked properly and be easy to identify and

correspond with the documentation.

9.2 EXAMPLES OF EQUIPMENT TO BE MARKED

Elevators

Inserts for multirange elevators

Slips

Inserts for multirange slips

Lifting subs

9.3 RENTED EQUIPMENT

Equipment delivered by Service companies/rental companies shall be documented and

marked (labelled) in a format recognizable to the user. Equipment which is not marked shall

not be used.


operations


10 GUIDELINES FOR FILLING IN THE MATRIX

10.1 HEADING

10.2 TABLE

Norwegian Oil and Gas - 081 recommended guidelines for remote pipe handling operations

Rig:

Performed date: dd.mm.yyyy

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Description of non conformances

and compensated measures in

addition to general requirements,

see section 6.

Compensating measures:

1 Bit

Req.=

Require

ment

M M NA M NA NA M

Drill bits shall preferably be put

together onshore, before arrival

at the rig. This to reduce the

number of manual operations

offshore.

Rig Procedures;

Report the rig specific procedures

here. Rig specific procedures are

required for manual pipe handling

operations. If in compliance with

remote operation requirement, there

will be no need for rig specific manual

procedures according to this

document (risk analysis - HAZID).

Rig specific conditions are also listed

in this column.

Level that realistically can

be achieved (for available

equipment)).

M = manual operation

NA= Not applicable

R = remote operated

R1 = R1 reference

R = new change in

requirement to Remote

operation in 2009

(compared to the 2006

revision)

The rig

specific level

regarding

own

equipment

Sequence in

an

operation,

e.g. from

pipe deck to

cat walk

Rig name


operations


10.3 FOOTER

Document no and name

Revision no: x Rev. date: xx.xx.xx Page: x of xx x

Fill in revision

no

Fill in revision

date

Page no

Norwegian Oil and Gas recommended guidelines for remote pipe handling operations


11 ATTACHMENTS

11.1 ATTACHMENT 1: DEVIATION MATRIX

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Description of non conformances and compensating measures in addition

to general requirements.

M = manual operation, NA = Not Applicable, R = Remote Operation,

Compensating Measures:

1 Drill Bit Req M M NA M NA NA M

Drill bits shall preferably be installed onshore, before arrival the rig, in

order to reduce manual operations offshore.

Rig Procedure no:

2 DC Req R R R1 R1 R1 R R

R1 Operation can be performed manually when the DC have a total length of

less than 300 m (does not apply for modified Drill Collars).

DC with recess for elevator and slips to be used during remote operation,

otherwise a slips type elevator shall be used.

Rig Procedure no;

3 Lifting Sub for

DC and BHA

Req NA NA M NA NA M R1

R1 Manual operation when lift subs are installed on DC joint on CatWalk.

Lift sub length adjusted to the rigs equipment shall preferably be installed

and prepared onshore.

Rig Procedure no;

Norwegian Oil and Gas Association’s recommended guidelines for remote pipe handling operations


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4 JAR Req R R R R M R R

Norwegian Oil and Gas/NSA members must influence suppliers to deliver

JAR with recess for elevator. If this is not possible, the Jar shall, if possible,

be delivered with lifting sub with length fitted to rig equipment.

Rig Procedure no:

5 Dog-collar Req NA NA NA NA M1 NA NA

M1 Use of Manuel Dog-collar clamp shall be limited. Remote operated Dog-

collar shall be used when longer lengths of the same dimensions are run.

Rig Procedure no:

6 X/O Req M M M M M M R1

R1 Every rig must ensure that proper length of X/O’s suitable for remote

operation is being used. New XO’s shall have a design that makes it

possible for remote operation during make/break. X/O adjusted to the

equipment shall preferably be prepared and assembled onshore.

Rig Procedure no:



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7 Stabilizers /

Holeopener

Req M M M M M M R1

R1 On new builds, upgrading or replacement of Iron Roughneck, a system

that handles stabilizers / hole openers remotely shall preferably be chosen.

Stabilizers shall be designed in a way that makes it possible to part/split

them with the Iron Roughneck.

Stabilizers with removable rings must be avoided.

Rig Procedure no;

8 DP, HWDP Req R R R R R1 R R2

R1 Manual operation is allowed if string weight is less then

recommendation from the equipment supplier,

R2 All types of pipe, DP - DC etc. which has been exposed for "over torque”

and can not be broken with remote operated equipment, can be broken

manually, see Attachment 3.

Thin walled pipes can be made up manually (TLC, thin walled tubes etc.)

All standard operations shall be remote operated.

Rig Procedure no;



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9 Non Magnetic

DC

Req R1 R R2 R2 R2 R R

R1 Manuel operation is permitted where a magnet is still in use.On new

builds, upgrading or replacement of pipe deck cranes, a system that handles

non-magnetic pipes, shall be selected.

R2 Operation can be performed manually when the DC have a total length

of less than 300 m (does not apply for modified Drill Collars).

DC with recess for elevator and slips to be used during remote operation,

otherwise a slips type elevator shall be used.

Rig Procedure no;

10 DP < 3 ½” Req R R M R1 R2 R3 R

R1 Manual operation is allowed if no inserts are available in the market for

pipes <3 ½ ”.

R2 Manual operation is allowed if string weight is less then

recommendation from equipment supplier.

R3 Manual stabbing/guiding/centring can only be accepted in special cases;

if the remote operated equipment cannot be adjusted to the correct

dimension. On new build, upgrading or replacement of remote operated

equipment, solutions that make remote operations possible shall be

selected.



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Rig Procedure no;

11 Casing Req R2 R2 R R R1 R R2

R1 Manual equipment can be used when the weight of the string is less then

the recommendation from the supplier of the remote operated equipment.

R2 Manuel handling of casing > 20”

The casing shall be filled from a suitable arrangement through the topdrive,

such that work in red zone is avoided. Ref. attachment 3, deformed or

impaired pipes.

Rig Procedure no;

12 Non Magnetic

Casing

Req R1 R R R R2 R R

R1 Manual operation is permitted only where magnets still are being used.

R2 Manual equipment can be used when the weight of the string is less then


On new builds, upgrading or replacement of equipment, a system that

makes remote operation possible shall be selected. Ref. attachment 3,

deformed or impaired pipes.

Rig Procedure no;



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13 Slick Casing /

Liners

Req R R R1 NA R R2 R

R1 Applies only for make / break of lift subs, otherwise a manual slips type

elevator shall be used.

R2 Manual installation of Stabbing Guide can be accepted where it can lead

to damage to seal area /threads.

Rig Procedure no;

14 Centralizers Req NA NA NA NA NA NA R1

R1 Centralizers shall preferably be installed onshore. Manual handling can

be done if no other type of centralizer will work with the pipe handling

equipment.


makes remote operation possible shall be selected.

Rig Procedure no;

15 WO Riser <20”

Req R R R R R R M Short pipes and XO’s can be handled manually.

Rig Procedure no;



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16

Marin Risers

and Slip Joint >

20”

Req M M M R M M NA

Rig Procedure no;

17 BOP Test Tool Req M M NA M M M R

Rig Procedure no;

18 Perforating

Guns

Req R1 R R NA R R R

R1 Perforating guns shall not be handled with magnet cranes.

Perforating guns built for remote operation shall be used, unless specific

requirements to function is not available in the market.

Rig Procedure no ;

19 Fishing

Equipment

Req M M M M M M M

With reference to XO, current manual handling of fishing equipment can be

accepted. This is not a standard operation.

A Safe Job Analyses (SJA) shall be performed before releasing the fish on

deck.

Rig Procedure no;



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20 Protectors Req NA NA R1 NA NA NA NA

R1 On new builds, upgrading or replacement of equipment; A system that

enables remote operation of tubulars (without protectors), shall be selected.

Rig Procedure no;

21 Mud Bucket Req NA NA NA F NA NA NA

Rig Procedure no;

22 Dope

Req

. NA NA NA R1 NA NA NA

R1 On new builds, upgrading or replacement of equipment, a system that

makes remote operation possible, shall be selected.

Casing and tubing shall be doped onshore prior to shipping offshore.

Rig Procedure no;

23 DP Pup Joints

Req M M M M F M R

Every rig has to research and find the proper length for Pup Joints suitable

for remote operation or Pup Joints must be replaced to fit rig equipment.

This must be documented.

Rig Procedure no;



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24

Casing/Tubing

and Pup Joints

Req R R R R R1 R R R1 Manual equipment can be used when the weight of the string is less then


Rig Procedure no;

25

Non magnetic

Casing/Tubing

and Pup Joints

Req R1 R R R R2 R R

R1 Assemblies that are too long for remote operated handling, can be

handled manually. Manual operation is allowed where magnets are still in

use.

R2 Manual equipment can be used when the weight of the string is less then the

recommendation from the supplier of the remote operated equipment.

Rig Procedure nr;

26 Screens Req M R R R R M M

Sensitive completion components which can be damaged of remote

operated equipment can be operated manually. In that case, a HAZID shall

be performed. SJA shall be performed before the operation starts.

Rig Procedure no;

27 Inner string Req R R M M M M M

2 7/8" and 3 1/2" string shall be standardized to fit remote operated rig

equipment. If the joint cannot be racked in the derrick in a safe way, the

joints must be laid down (remote operated).

Rig Procedure no;



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28 Lateral Well

Equipment

Req M M M M M M M Operations which can be remotely operated shall be remotely operated.

Rig Procedure no;

29 Completion

Equipment

Req M M M M M R1 M R1 For equipment which can be made up for remote operation, operation

shall be remotely operated.

Rig Procedure no;

30

Double

Production

Tubing

Req M R M R R M M

Equipment and components which can be damaged by using remote

operated equipment can be manually handled. A HAZID shall be prepared

and a SJA executed prior to start of operation.

Rig Procedure no;

31 MWD /

Mud Motors

Req

. R R R R M M M

Equipment and components which can be damaged by using remote

operated equipment can be manually handled. Equipment should be fit for

remote operation and lifting sub should be avoided.

For lifting sub, see item #3.

Rig Procedure no;



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32 Coil Tubing

BHA’s

Req M M M M M M M BHA’s shall if possible be prepared and made up onshore. Operations that

can be remotely operated shall be remotely operated.

Rig Procedure no;

33 False Rotary

Table

Req NA NA NA R R R R Pipe that normally shall be remotely operated shall also be operated

remotely by use of false rotary table.

Rig Procedure no;

34

Drilling with

Pup Joint /

Drilling Stand

Req

. NA NA NA R R R R1

R1 If the iron roughneck is not designed to function as a “back up” tong, a

manually rig tong can be used. Procedure(s) shall be worked out.


makes remote operation possible shall be selected.

Rig Procedure no;

35 Casing/Liner

Drilling

Req R R R R R1 R R

R1 If the weight of the string is less then recommended from the equipment

supplier, manual operation is allowed.

For retrievable BHA, manual operation is allowed.

Rig Procedure no;



11.2 ATTACHMENT 2: REMOTE OPERATED EQUIPMENT FAILURES

Guideline for Temporary Failure of Remote Operated Pipe Handling Equipment.

Responsible person onshore informs *

NO

YES

YES

YES

NO

YES

Failure in remote controlled

pipe handling equipment

Could immediate

stop for repair

result in loss of

well control?

Immediate action for

manual operation *)

Manuel operation until

Well control is

established.

Could immediate

stop for repair result

in hole problems or

damage to the well?

Immediate action for

manual operation *)

Manual operation until

the drill string is inside the

casing or possibilities for

well damages are

eliminated.

Are spare parts and

required personnel

available onboard to

start the repair?

Stop for

Repair

Carry out operational risk assessment

in accordance with current procedures

in order to evaluate personnel risk

when manual pipe handling until the

equipment is repaired. Carry out

compensating measures.

NO

Is the risk level

acceptable?

Stop for repair

*) Immediate actions prior to manual operation

1) Safe job analysis shall be carried out if there

are no procedure / work description available.

2) Procedures for manual pipe handling

- is available

- is known to the involved personnel

- is used

3) Relevant equipment

- is available

- is approved

- is maintained

4) Report of the reason/incident

5) Drilling responsible person onboard informs

responsible person onshore

Each company should adapt guidelines to own organization.

NO

Manual Handling

can continue until

the equipment is

repaired.



11.3 ATTACHMENT 3: PULLING DEFORMED OR IMPAIRED PIPES

Guidelines while pulling Deformed or Impaired Pipes out of the hole (No notification to PSA

required).

Can remote operated

pipe handling

equipment be used

without increasing the

risk?

Will available

equipment on site be

suitable to continue the

operation in manual?

?mode?

Is the risk level

acceptable?

Manual handling can be accepted until

remote operation is normalized and

resumed.

Carry out operational risk assessment/SJA

based on possibly dropped load/string.

Carry out operational risk assessment / SJA in

accordance with current procedures for manual

operation.

Stop operation until suitable equipment is

available on site

Pipes is deformed or impaired

Continue POOH according to rig

specific matrix

Stop operation, implement compensating

measures until risk level is acceptable.

YES

YES

YES

NO

NO

NO

*) Immediate actions prior to manual

operation

1) Safe job analysis shall be carried out if

there are no procedure / work description

available.

2) Procedures for manual pipe handling

- is available

- is known to the involved personnel

- is used

3) Relevant equipment

- is available

- is approved

- is maintained

4) Report of the reason/incident

5) Drilling responsible person onboard

informs responsible person onshore




11.4 ATTACHMENT 4: FAILURE IN ANTI-COLLISION SYSTEM

Guidelines for Temporary Failure of Anti-collision System, Crown Saver and Floor Saver.

YES

YES

YES

NO

Failure in anti-collision

system.

Is failed

equipment

involved in the

operations?

Can immediate

stop for repair

result in loss of

well control?

Immediate action

prior to operation in

by pass mode *)

Continue operations in

by pass mode until the

risk for loosing well

control is at an

acceptable level

Can immediate

stop result in hole

problems or

damage to the

well?

Are parts and

personnel available

on board to start

repair? Stop for Repair

NO

Carry out operational risk

assessment in accordance with

current procedures, for evaluation

of personnel risk in connection with

anti collision system entirely or

partly out of function.

Is the risk level

acceptable?

Stop for repair

The operation can

continue with the system

entirely or partly out of

function

Responsible

person onshore

informs other

*

Continue operation

when failed

equipment has been

parked in a safe

position

YES

NO

NO

*) Immediate actions prior to operation

1. Safe job analysis.

2. Report of the reason/incident

3. Drilling responsible person onboard informs

responsible person onshore.

Immediate action

prior to

operation in by

pass mode *)


Continue operations in

by pass mode until the

drill string is inside

casing or until the risk

for well damage is

eliminated.

YES

NO

recommended guidelines for remote pipe handling operations.pdf

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