Training of Lessee and Contractor Employees Engaged in Oil and Gas and Sulphur Operations in the Outer Continental Shelf (OCS)
Federal RegisterNov 2, 1995
Ask Donna
What actually matters in this document.
Text
DEPARTMENT OF THE INTERIOR
Minerals Management Service
30 CFR Part 250
RIN 1010-AB99
Training of Lessee and Contractor Employees Engaged in Oil and
Gas and Sulphur Operations in the Outer Continental Shelf (OCS)
AGENCY: Minerals Management Service (MMS), Interior.
ACTION: Proposed rule.
-----------------------------------------------------------------------
SUMMARY: This proposed rule would amend MMS regulations governing the
training of lessee and contractor employees engaged in oil and gas and
sulphur operations in the OCS. MMS is amending these regulations to
simplify the training options, to provide the flexibility to use
alternative training methods, and to provide the option to allow third
parties to certify schools.
DATES: MMS will consider all comments we receive by January 31, 1996.
We will begin reviewing comments at that time and may not fully
consider comments we receive after January 31, 1996.
ADDRESSES: Mail or hand-carry comments to the Department of the
Interior; Minerals Management Service; Mail Stop 4700; 381 Elden
Street; Herndon, Virginia 22070-4817; Attention: Chief, Engineering and
Standards Branch.
FOR FURTHER INFORMATION CONTACT:
Jerry Richard, Information and Training Branch, telephone (703) 787-
1582 or FAX (703) 787-1575.
SUPPLEMENTARY INFORMATION: On August 5, 1994, MMS published an advance
notice of proposed rulemaking (ANPR) concerning the training of lessee
and contractor employees engaged in drilling, well-completion, well-
workover, well-servicing, or production operations in the OCS. The ANPR
suggested five options to improve the existing regulations at 30 CFR
Part 250, Subpart O, Training. The ANPR also encouraged the public to
suggest other viable options.
During the comment period, which ended on October 19, 1994, MMS
held a workshop to provide a mechanism to exchange ideas about
improvements to subpart O. MMS announced the September 29, 1994,
workshop in the Federal Register on August 31, 1994.
MMS received 33 comments from industry, support contractors,
training schools, and academia. Some comments favored a third-party
certification option and others favored the current system with minor
changes to be more flexible.
MMS agrees that it should be more flexible in training options and
it should allow a third party to relive some of the burden to the
Government. After analyzing the comments received from the ANPR and the
workshop and after analyzing our future goals, MMS determined that it
needs to amend the existing training regulations.
The revision would:
--Streamline the current regulations by 80 percent
--Provide flexibility to use alternative training methods
--Provide the option for a third party to certify schools
MMS is developing the criteria for approving third parties to
certify training schools and their programs. We plan to have the
criteria available for the
[[Page 55684]]
final rule because we anticipate that this proposed rule will generate
interest from potential third parties.
Once MMS begins shifting, to a third party, the burden of
certifying the numerous training schools and their frequent training
plan updates, the Federal Government will save resources. Although the
third party will probably charge each potential school a service fee,
MMS anticipates that market competition will make the fee nonminal. The
students may receive a slight tuition increase to absorb the fee. MMS
anticipates that any cost increase to industry may be offset by the
increased flexibility provided by this proposed rule.
This rulemaking is the first step to change the way MMS regulates
worker qualifications and training. Our vision for the future of the
training program is for more of a partnership with industry by using a
performance-based system. Under a performance-based system, MMS would
shift the responsibility to industry for establishing training methods.
However, the training that employees receive would need to continue to
provide safety for personnel and the environment. MMS could appraise
the adequacy of industry's training through methods that could include
random inspections, tests or drills, and by analyzing accidents or near
accidents. MMS is just beginning to write performance-based regulations
and we would appreciate your comments on this subject.
MMS is also considering opening up the option for industry to
integrate its training requirements into a safety and environmental
management plan (SEMP). You may know that the objective of the SEMP
program is to reduce the risk of accidents and pollution from OCS
operations by incorporating safety management practices into facility
management and procedures. Using a SEMP may provide an alternative
means to fulfill some of industry's regulatory obligations. Please send
us your ideas and comments on the future of using a SEMP.
We hope that you find this proposed rule clear, and more user-
oriented. MMS may conduct a workshop on this proposed training rule. We
will notify you under separate notice.
Author: Sharon Buffington, Engineering and Standards Branch,
MMS, prepared this document.
Executive Order (E.O.) 12866
This proposed rule is not a significant rule under E.O. 12866.
Regulatory Flexibility Act
The Department of the Interior (DOI) determined that this proposed
rule will not have a significant effect on a substantial number of
small entities. In general, the entities that engage in offshore
activities are not considered small due to the technical and financial
resources and experience necessary to safely conduct such activities.
Paperwork Reduction Act
This proposed rule does not add any new collection requirements.
The Office of Management and Budget (OMB) previously approved the
collection requirements under OMB No. 1010-0078.
Takings Implication Assessment
The DOI determined that this proposed rule does not represent a
governmental action capable of interference with constitutionally
protected property rights. Thus, DOI does not need to prepare a Takings
Implication Assessment pursuant to E.O. 12630, Government Action and
Interference with Constitutionally Protected Property Rights.
E.O. 12778
The DOI certified to OMB that this proposed rule meets the
applicable civil justice reform standards provided in Sections 2(a) and
2(b)(2) of E.O. 12778.
National Environmental Policy Act
The DOI determined that this action does not constitute a major
Federal action significantly affecting the quality of the human
environment; therefore, an Environmental Impact Statement is not
required.
List of Subjects in 30 CFR Part 250
Continental shelf, Environmental impact statements, Environmental
protection, Government contracts, Incorporation by reference,
Investigations, Mineral royalties, Oil and gas development and
production, Oil and gas exploration, Oil and gas reserves, Penalties,
Pipelines, Public lands--mineral resources, Public lands--rights-of-
way, Reporting and recordkeeping requirements, Sulphur development and
production, Sulphur exploration, Surety bonds.
Dated: September 5, 1995.
Bob Armstrong,
Assistant Secretary, Land and Minerals Management.
For the reasons in the preamble, Minerals Management Service (MMS)
proposes to amend 30 CFR part 250 as follows:
PART 250--OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER
CONTINENTAL SHELF
1. The authority citation for part 250 continues to read as
follows:
Authority: 43 U.S.C. 1334.
2. Subpart O is revised to read as follows:
Subpart O--Training
Sec.
250.209 Question index table.
250.210 Definitions.
250.211 What is MMS's goal for well-control and production safety
systems training?
210.212 What type of training must I provide for my employees?
250.213 What documentation must I provide to trainees?
250.214 How often must I provide training to my employees and for
how many hours?
250.215 Where must I get training for my employees?
250.216 Where can I find training guidelines for other topics?
250.217 Can I get an exception to the training requirements?
250.218 Can my employees change job certification?
250.219 What must I do if I have temporary employees or on-the-job
trainees?
250.220 What must manufacturer's representatives in production
safety systems do?
250.221 May I use alternative training methods?
250.222 What is MMS looking for when it reviews an alternative
training program?
250.223 Who may certify a training organization to teach?
250.224 How long is a training organization's certification valid
for?
250.225 What information must a training organization submit to MMS
(or an MMS-approved third party)?
250.226 What additional requirements must a training organization
follow?
250.227 What are MMS's requirements for the written test?
250.228 What are MMS's requirements for the hands-on simulator and
well test?
250.229 What elements must a basic course cover?
250.230 If MMS tests employees at my worksite, what must I do?
250.231 If MMS tests trainees at a training organization's
facility, what must occur?
250.232 Why might MMS conduct its own tests?
Subpart O--Training
Sec. 250.209 Question index table.
(a) For your convenience in locating information, we grouped the
questions in table 250.209(b) as follows:
(1) General training requirements--Secs. 250.211 through 250.216.
(2) Departures from training requirements--Secs. 250.217 through
250.222.
[[Page 55685]]
(3) Training program certifications--Secs. 250.223 through 250.229.
(4) MMS testing information--Secs. 250.230 through 250.232.
(b) Table 250.209(b) is as follows:
Table 250.209(b)
------------------------------------------------------------------------
------------------------------------------------------------------------
Definitions Sec. 250.210
What is MMS's goal for well- Sec. 250.211
control and production safety
systems training?
What type of training must I Sec. 250.212
provide for my employees?
What documentation must I Sec. 250.213
provide to trainees?
How often must I provide Sec. 250.214
training to my employees and
for how many hours?
Where must I get training for my Sec. 250.215
employees?
Where can I find training Sec. 250.216
guidelines for other topics?
Can I get an exception to the Sec. 250.217
training requirements?
Can my employees change job Sec. 250.218
certification?
What must I do if I have Sec. 250.219
temporary employees or on-the-
job trainees?
What must manufacturer's Sec. 250.220
representatives in production
safety systems do?
May I use alternative training Sec. 250.221
methods?
What is MMS looking for when it Sec. 250.222
reviews an alternative training
program?
Who may certify a training Sec. 250.223
organization to teach?
How long is a training Sec. 250.224
organization's certification
valid for?
What information must a training Sec. 250.225
organization submit to MMS (or
an MMS-approved third party)?
What additional requirements Sec. 250.226
must a training organization
follow?
What are MMS's requirements for Sec. 250.227
the written test?
What are MMS's requirements for Sec. 250.228
the hands-on simulator and well
test?
What elements must a basic Sec. 250.229
course cover?
If MMS tests employees at my Sec. 250.230
worksite, what must I do?
If MMS tests trainees at a Sec. 250.231
training organization's
facility, what must occur?
Why might MMS conduct its own Sec. 250.232
tests?
------------------------------------------------------------------------
Sec. 250.210 Definitions.
Terms used in this subpart have the following meaning:
Alternative training methods includes self-paced or team-based
training that may use a computer-based system such as compact disc
interactive (CDI), compact disc read only memory (CDROM), or Laser
Discs.
Completed training means that the trainee successfully met MMS's
requirements for that training.
Employees means direct employees and contract employees of lessees.
Floorhands means rotary helpers, derrickmen, or their equivalent.
I or you means the lessee or contractor engaged in oil, gas or
sulphur operations in the Outer Continental Shelf (OCS).
Installing includes installing and replacing the equipment.
Lessee means the person, organization, agent or designee authorized
to explore, develop and produce leased deposits.
Maintaining includes preventive maintenance, routine repair, and
replacing defective components.
Operating includes testing, adjusting, calibrating, and recording
test and calibration results for the equipment.
Production Safety Systems employees means employees engaged in
installing, repairing, testing, maintaining, or operating surface or
subsurface safety devices and the platform employee who is responsible
for production operations.
Supervisors means the driller, toolpusher, operator's
representative, or their equivalent.
Third-Third Certifier means a party that MMS has approved to
certify a training organization or training program.
Training includes a basic or an advanced class in well-control for
drilling, well-completion/well-workover, well-servicing, and production
safety systems.
Training organization means a party certified by MMS or an MMS-
approved third-party certifier to teach well-control for drilling,
well-completion/well-workover, well-servicing, and production safety
systems.
Well-completion/well-workover (WO) well-control includes small
tubing.
Well-servicing (WS) well-control includes snubbing and coil tubing.
Well-workover rig means a drilling rig used for well completions.
Sec. 250.211 What is MMS's goal for well-control and production safety
systems training?
The goal is to ensure that employees who work in the following
areas receive training that results in safe and clean operations:
(a) Drilling well-control;
(b) WO well-control;
(c) WS well-control; and
(d) Production Safety Systems.
Sec. 250.212 What type of training must I provide for my employees?
You must provide training for your employees in accordance with the
following table:
------------------------------------------------------------------------
Training
Type of employee requirements Comments
------------------------------------------------------------------------
Drilling floorhand.............. Drilling well
control.\1\
Complete a well You must log the
control drill at time it took to
the job site complete the
within the time drill in the
limit prescribed driller's log and
by company furnish the time
operating to the floorhand.
procedures.\2\
Participate in You must record
well control the date and time
drills under it took to
subpart D of this complete each
part.\2\ drill in the
driller's log.
Receive copy of a
drilling well
control
manual.\2\
Drilling supervisor............. Drilling well
control
course.\1\
Qualify to direct
well control
operations.\1\
WO floorhands................... WO well control
course.\1\
Complete the You must record
qualifying the date and time
testing it took to
consisting of a complete each
well control drill in the
drill at the job operations log.
site within the
time limit set by
company
procedures.\2\
Participate in
weekly well
control drills
under subparts E
and F of this
part.\2\
Receive a well
control
manual.\2\
WO supervisors.................. WO well control
course.\1\
Qualify to direct
well control
operations.\1\
WS work crews................... At least one crew Trained employee
member is trained must be in work
in WS well area at all time
control.\1\ during snubbing
or coil tubing
operations.
[[Page 55686]]
At least one crew
member must be
qualified to
direct well
control
operations.\1\
Production safety systems Must complete
employees. training that
enables them to
install, test,
maintain, &
operate
subsurface
surface safety
devices.\1\
Employees who work in well Either WO well
completion operations before or control course or
during tree installation. drilling well
control
course.\1\
------------------------------------------------------------------------
\1\ Employee may not work in the OCS unless this requirement is met.
\2\ Employee must complete this requirement before exceeding six months
of cumulative employment.
Sec. 250.213 What documentation must I provide to trainees?
You must give your employees documents that show they have
completed the training courses required for their job. The employee
must either carry the documents or keep them at the job site.
Sec. 250.214 How often must I provide training to my employees for how
many hours?
(a) You must ensure that applicable employees complete basic or
advanced well-control training at least every 2 years. For example, if
your employee completed a well control course on May 31, 1996, they
must again complete training by May 31, 1998.
(b) You must ensure that applicable employees complete basic or
advance production safety systems training at least every 3 years. For
example, if your employee completes production safety systems training
on May 31, 1996, they must again complete the training by May 31, 1999.
(c) You must ensure that your employees have at least the following
amount of training:
------------------------------------------------------------------------
Surface Subsea No
option option options
Basic/advanced course minimum minimum minimum
hours hours hours
---------------------------------------------------------\1\------------
Drilling (D).............................. 28 32 --
Well-Completion/Workover (WO)............. 32 36 --
Well-Serving (WS)......................... -- -- 18
Combination D/WO.......................... 40 44 --
Combination D/WS.......................... 44 48 --
Combination WO/WS......................... 48 52 --
Combination D/WO/WS....................... 55 59 --
Production Safety Systems................. -- -- 30
------------------------------------------------------------------------
\1\ The subsea option includes the minimum hours from the surface option
plus four hours.
Sec. 250.215 Where must I get training for my employees?
You must provide training by a training organization or program
approved by MMS or by an MMS-approved third-party.
Sec. 250.216 Where can I find training guidelines for other topics?
You can find guidelines in the subparts of this part listed in the
following table:
------------------------------------------------------------------------
Topic Subpart of part 250
------------------------------------------------------------------------
Pollution control.......................... C
Crane operations........................... A
Welding and burning........................ D
Hydrogen sulfide........................... D
------------------------------------------------------------------------
Sec. 250.217 Can I get an exception to the training requirements?
MMS may grant an exception to well-control or production safety
systems training if you meet both of the following:
(a) MMS determines that the exception won't jeopardize the safety
of your personnel or create a hazard to the environment.
(b) You need the exception because of unavoidable circumstances
that make compliance infeasible for impractical.
Sec. 250.218 Can my employees change job certification?
Only if you ensure that the employee completes training for the new
job before entering on duty.
Sec. 250.19 What must I do if I have temporary employees or on-the-job
trainees?
You must ensure that temporary employees and on-the-job trainees
complete the appropriate training unless a trained supervisor is
directly supervising the employee.
Sec. 250.220 What must manufacturer's representatives in production
safety systems do?
A manufacturer's representative who is working on company supplied
equipment must:
(a) Receive training by the manufacturer to install, service, or
repair the specific safety device or safety systems; and
(b) Have an individual trained in production safety systems (who
can evaluate their work) accompany them.
Sec. 250.221 May I use alternative training methods?
Yes.
(a) You may receive a one-year provisional approval from MMS to use
alternative training methods that may involve team or self-paced
training using a computer-based system.
(b) You may receive up to 3 additional years (4 years total) from
MMS to use alternative training methods (through onsite reviews).
Sec. 250.222 AWhat is MMS looking for when it reviews an alternative
training program?
(a) The alternative training must teach methods to operate
equipment that result in safe and clean operations.
(b) MMS will determine, through onsite MMS reviews and unannounced
audits during the provisional period, if the:
(1) Training environment is conducive to learning;
(2) Trainees interact effectively with the moderator or training
administrator;
(3) Trainees function as a team (for well-control only); and
(4) Tests are challenging and cover all important safety concepts
and practical procedures to ensure safety.
(c) MMS may also speak with the trainees to determine if the
trainees felt the training met their needs for their job.
Sec. 250.223 Who may certify a training organization to teach?
Either MMS or an MMS-approved third party may certify a training
organization or program.
Sec. 250.224 How long is a training organization's certification valid
for?
A certificate is valid for a maximum of 4 years. A training
organization may apply to MMS to recertify its program before the
fourth anniversary of the effective certification date. The training
organization must state the changes
[[Page 55687]]
(additions and deletions) to the last approved training curriculum and
plan.
Sec. 250.225 What information must a training organization submit to
MMS (or an MMS-approved third party)?
(a) Two copies of the detailed plan that includes the:
(1) Curriculum;
(2) Names and credentials of the instructors (instructors must
complete training from an approved training organization);
(3) Mailing and street address of the training facility and the
location of the records;
(4) Location for the simulator and lecture areas and how you
separate the areas;
(5) Presentation methods (video, lecture, film, etc.);
(6) Percentage of time for each presentation method;
(7) Testing procedures and a sample test; and
(8) List of any portions of the course that cover the subsea
training option instead of the surface training option.
(b) A training manual.
(c) A cross-reference that relates the requirements of this subpart
to the elements in the program.
(d) A copy of the handouts.
(e) A copy of the training certificate that includes the following:
(1) Candidate's full name;
(2) Candidate's social security number or an MMS-issued or third
party issued identification number;
(3) Name of the training school;
(4) Course name (e.g., basic WS well-control course);
(5) Option (surface or subsea);
(6) Training completion date;
(7) Job classification (e.g., drilling supervisor; and
(8) Certificate expiration date.
(f) Course outlines identified by:
(1) Name (e.g., ``WS well-control course'');
(2) Type (basic or advanced); and
(3) Option (surface or subsea).
(g) Time (hours per student) for the following:
(1) Teaching;
(2) Using the simulator (for well-control);
(3) Hands-on training (for production safety systems); and
(4) Completing the test (written and simulator).
(h) Special instruction methods for students who respond poorly to
conventional training (including oral assistance).
(i) Additional material (for the advanced training option) such as
advanced training techniques or case studies.
(j) Information on the simulator or test wells:
(1) Capability for surface and or subsea drilling well-control
training;
(2) Capability to simulate lost circulation and secondary kicks;
and
(3) Types of kicks.
Sec. 250.226 What additional requirements must a training
organization follow?
(a) Keep training records of each trainee for 5 years after the
date the trainee completed the training. For example, if a trainee
completed a course in 1995, you may destroy the 1995 records at the end
of the year 2000. Keep the following trainee record information:
(1) Daily attendance record including makeup time;
(2) Written test and retest (including simulator test);
(3) Evaluation of the trainee's simulator test or retest;
(4) ``Kill sheets'' for simulator test or retest; and
(5) Copy of the trainee's certificate.
(b) Keep records of the training program for 5 years. The 5 years
starts with the program approval date. For example, if a training
program was certified in 1995, at the end of the year 2000 you may
destroy the records for 1995. Keep the following training record
information:
(1) Complete and current training program plan and a technical
manual;
(2) A copy of each class roster; and
(3) Copies of schedules and schedule changes.
(c) Supply trainees with copies of Government regulations on the
training subject matter.
(d) Provide a certificate to each trainee who successfully
completes training.
(e) Ensure that the subsea training option has an additional 4
hours of training and covers problems in well-control when drilling
with a subsea blowout preventer (BOP) stack including:
(1) Choke line friction determinations;
(2) Using marine risers;
(3) Riser collapse;
(4) Removing trapped gas from the BOP after controlling a well
kick; and
(5) ``U'' tube effect as gas hits the choke line.
(f) Ensure that trainees who are absent from any part of a course
make up the missed portion within 14 days after the end of the course
before providing a written or simulator test to the trainee.
(g) Ensure that classes contain 18 or fewer candidates.
(h) Furnish a copy of the training program and plan to MMS for
their use during an onsite review.
(i) Submit the course schedule to MMS at the following times--after
MMS approves the training program, annually, and prior to any program
changes. The schedule must include the:
(1) Name of the course;
(2) Class dates;
(3) Type of course; and
(4) Course location.
(j) Provide all basic course trainees a copy of the training
manual.
(k) Provide all advanced course trainees handouts necessary to
update the manuals the trainee has as a result of previous training
courses.
(l) When each course ends, send MMS a letter listing each trainee
who completed the course. The letter must contain the following
information for each trainee:
(1) Name of training organization;
(2) Course location (e.g., Thibodeaux, Louisiana);
(3) Trainee's full name;
(4) Name of course (e.g., Drilling well-control or WS well-
control);
(5) Course type (i.e., basic or advanced training);
(6) Options (e.g., subsea);
(7) Date trainee completed course;
(8) Name(s) of instructor(s) teaching the course;
(9) Either the trainee's social security number or an MMS-issued or
third party issued identification number;
(10) Trainee's employer;
(11) Actual job title of trainee;
(12) Job for each awarded certificate; and
(13) Test scores (including course element scores) for each
successful trainee.
(m) Ensure that test scores for combination training have a
separate score element for each designation and for each option. For
example, training in subsea drilling and in WO would have separate test
scores for the drilling, WO, and for the subsea portion.
Sec. 250.227 What are MMS's requirements for the written test?
(a) The training organization must:
(1) Administer the test at the training facility;
(2) Use 70 percent as a passing grade for each course element
(drilling, well-completion, etc.);
(3) Ensure that the tests are confidential and nonrepetitive; and
(4) Offer a retest, when necessary, using different questions of
equal difficulty.
(b) A trainee who fails a retest must repeat the training and pass
the test in order to work in the OCS in their classification.
[[Page 55688]]
Sec. 250.228 What are MMS's requirements for the hands-on simulator
and well test?
(a) The test must simulate a surface blowout preventer (BOP) or
subsea stack. You must have a 3-D simulator with actual gauges and
dials. The trainees must be able to demonstrate to the instructor the
ability to:
(1) Kill the well prior to removing the tree;
(2) Determine slow pump rates;
(3) Recognize kick warning signs;
(4) Shut in a well;
(5) Complete kill sheets;
(6) Initiate kill procedures;
(7) Maintain appropriate bottomhole pressure;
(8) Maintain constant bottomhole pressure;
(9) Recognize and handle unusual well control situations;
(10) Control the kick as it reaches the choke line; and
(11) Determine if kill gas or fluids are removed.
(b) In the subsea option, trainees must demonstrate the ability to:
(1) Determine choke line friction pressures for subsea BOP stacks;
and
(2) Discuss and demonstrate procedures such as circulating the
riser and removing trapped gas in a subsea BOP stack.
(c) Offer a retest, when necessary, using different questions of
equal difficulty.
(d) A trainee who fails a retest must repeat the training and pass
the test to work in the OCS in their job classification.
Sec. 250.229 What elements must a basic course cover?
See Sec. 250.229 Table (a) for well control and Sec. 250.229 Table
(b) for production safety systems. The checks in Sec. 250.229 Table (a)
indicate the required training elements that apply to each job. Tables
(a) and (b) follow:
Table (a).--Well Control
----------------------------------------------------------------------------------------------------------------
Drilling WO
Elements for basic training ---------------------------------------- WS
Super Floor Super Floor
----------------------------------------------------------------------------------------------------------------
1. Hands-on:
Training to operate choke manifold........................ ........ ........ ........
Training to operate stand pipe............................ ........ ........ ........
Training to operate mud room valves....................... ........ ........ ........ ........
2. Care, handling & characteristics of drilling & completion
fluids....................................................... ........ ........ ........
3. Care, handling & characteristics of well completion/well
workover fluids & packer fluids.............................. ........ ........
4. Major causes of uncontrolled fluids from a well including:
Failure to keep the hole full............................. ........ ........ ........
Swabbing effect........................................... ........ ........ ........
Loss of circulation....................................... ........ ........ ........
Insufficient drilling fluid density....................... ........ ........ ........
Abnormally pressured formations........................... ........ ........ ........
Effect of too rapidly lowering of the pipe in the hole.... ........ ........ ........
5. Importance & instructions of measuring the volume of fluid
to fill the hole during trips................................ ........ ........ ........ ........
6. Importance & instructions of measuring the volume of fluid
to fill the hold during trips including the importance of
filling the hole as it relates to shallow gas conditions..... ........ ........ ........ ........
7. Filling the tubing & casing with fluid to control
bottomhole pressure.......................................... ........ ........ ........ ........
8. Warning signals that indicate kick & conditions that lead
to a kick.................................................... ........
9. Controlling shallow gas kicks and using diverters.......... ........ ........ ........ ........
10. At least one bottomhole pressure well control method
including conditions unique to a surface or subsea BOP stack. ........ ........ ........
11. Installing, operating, maintaining & testing BOP &
diverter systems............................................. ........ ........ ........ ........
12. Installing, operating, maintaining & testing BOP systems.. ........ ........ ........ ........
13. Government regulations on:
Emergency shutdown systems................................ ........ ........ ........ ........
Production safety systems................................. ........ ........ ........ ........
Drilling procedures....................................... ........ ........ ........ ........
Wellbore plugging & abandonment........................... ........ ........
Pollution prevention & waste management...................
Well completion & well workover requirements (Subparts E &
F of 30 CFR part 250).................................... ........ ........ ........
14. Procedures & sequential steps, for shutting in a well:
BOP system................................................ ........ ........
Surface/subsurface safety system.......................... ........ ........ ........ ........
Choke manifold............................................ ........ ........ ........
15. Well control exercises with a simulator suitable for
modeling well completion/well workover....................... ........ ........ ........ ........
16. Well control exercises with a simulator suitable for
modeling drilling............................................ ........ ........ ........ ........
17. Instructions & simulator or test well experience on
organizing & directing a well killing operation.............. ........ ........ ........
18. At least two simulator practice problems (rotate the
trainees & have teams of 3 or less members).................. ........ ........ ........
19. Care, operation, & purpose {& installation (for
supervisors)} of the well control equipment.................. ........
20. Limitations of the equipment that may wear or be subjected
to pressure.................................................. ........ ........
21. Instructions in well control equipment, including:
Surface equipment......................................... ........ ........ ........
Well completion/well workover, BOP & tree equipment....... ........ ........ ........ ........
Downhole tools & tubulars................................. ........ ........ ........ ........
Tubing hanger, back pressure valve (threaded/profile),
landing nipples, lock mandrels for corresponding nipples
& operational procedures for each, gas lift equipment &
running & pulling tools operation........................ ........ ........ ........ ........
Packers................................................... ........ ........ ........ ........
[[Page 55689]]
22. Instructions in special tools & systems, such as:
Automatic shutdown systems (control points, activator
pilots, monitor pilots, control manifolds & subsurface
systems)................................................. ........ ........ ........ ........
Flow string systems (tubing, mandrels & nipples, flow
couplings, blast joints, & sliding sleeves).............. ........ ........ ........ ........
Pumpdown equipment (purpose, applications, requirements,
surface circulating systems, entry loops & tree
connection/flange)....................................... ........ ........ ........ ........
23. Instructions for detecting entry into abnormally pressured
formations & warning signals................................. ........ ........ ........ ........
24. Instructions on well completion/well control problems..... ........ ........ ........ ........
25. Well control problems during well completion/well workover
including:
Killing a flow............................................ ........ ........ ........ ........
Simultaneous drilling, completion & workover operations on
the same platform........................................ ........ ........ ........ ........
Killing a producing well.................................. ........ ........ ........ ........
Removing the tree......................................... ........ ........ ........ ........
26. Calculations on the following:
Fluid density increase that controls fluid flow into the
wellbore................................................. ........ ........ ........
Fluid density to pressure conversion & the danger of
formation breakdown under the pressure caused by the
fluid column especially when setting casing in shallow
formations............................................... ........ ........ ........ ........
Fluid density to pressure conversion & the danger of
formation breakdown under the pressure caused by the
fluid column............................................. ........ ........ ........ ........
Equivalent pressures at the casing seat depth............. ........ ........ ........ ........
Drop in pump pressure as fluid density increases; & the
relationship between pump pressure, pump rate, & fluid
density.................................................. ........ ........ ........
Pressure limitations on casings........................... ........ ........ ........
Hydrostatic pressure & pressure gradient.................. ........ ........ ........
27. Unusual well control situations, including the following:
Drill pipe is off the bottom or out of the hole/work
string is off the bottom or out of the hole.............. ........ ........ ........
Lost circulation occurs................................... ........ ........ ........
Drill pipe is plugged/work string is plugged.............. ........ ........ ........
There is excessive casing pressure........................ ........ ........ ........
There is a hole in drill pipe/hole in the work string/hole
in the casing string..................................... ........ ........ ........
Multiple completions in the hole.......................... ........ ........ ........ ........
28. Special well-control problems-drilling with a subsea stack
(subsea students) includes:
Choke line friction determinations........................ ........ ........ ........
Using marine risers....................................... ........ ........ ........
Riser collapse............................................ ........ ........ ........
Removing trapped gas from the BOP stack after controlling
a well kick.............................................. ........ ........ ........
``U'' tube effect as gas hits the choke line.............. ........ ........ ........
29. Mechanics of various well controlled situations,
including:
Gas bubble migration & expansion.......................... ........ ........ ........
Bleeding volume from a shut-in well during gas migration.. ........ ........ ........
Excessive annular surface pressure........................ ........ ........ ........
Differences between a gas kick & a salt water and/or oil
kick..................................................... ........ ........ ........
Special well control techniques (such as, but not limited
to, barite plugs & cement plugs)......................... ........ ........ ........
Procedures & problems involved when experiencing lost
circulation.............................................. ........ ........ ........
Procedures & problems involved when experiencing a kick
while drilling in a hydrogen sulfide (H2S) environment... ........ ........
Procedures & problems--experiencing a kick during
snubbing, coil-tubing, or small tubing operations and
stripping & snubbing operations with work string......... ........ ........ ........
30. Reasons for well completion/well workover, including:
Reworking a reservoir to control production............... ........ ........ ........
Water coning.............................................. ........ ........ ........ ........
Completing from a new reservoir........................... ........ ........ ........
Completing multiple reservoirs............................ ........ ........ ........
Stimulating to increase production........................ ........ ........ ........
Repairing mechanical failure.............................. ........ ........ ........
31. Methods on preparing a well for entry:
Using back pressure valves................................ ........ ........ ........ ........
Using surface & subsurface safety systems................. ........ ........ ........
Removing the tree & tubing hangar......................... ........ ........
Installing & testing BOP & wellhead prior to removing back
pressure valves & tubing plugs........................... ........ ........ ........
32. Instructions in small tubing units:
Applications (stimulation operations, cleaning out tubing
obstructions, and plugback and squeeze cementing)........ ........ ........ ........ ........
Equipment description (derrick & drawworks, small tubing,
pumps, weighted fluid facilities, and weighted fluids)... ........ ........ ........ ........
BOP equipment (rams, wellhead connection, & check valve... ........ ........ ........ ........
33. Methods for killing a producing well, including:..........
Bullheading............................................... ........ ........ ........
Lubricating & bleeding.................................... ........ ........ ........
[[Page 55690]]
Coil tubing............................................... ........ ........ ........
Applications (stimulation operations, initiating flow, &
cleaning out sand in tubing)............................. ........ ........ ........ ........
Equipment description (coil tubing, reel, injection head,
control assembly & injector hoist)....................... ........ ........ ........ ........
BOP equipment (tree connection or flange, rams, injector
assembly & circulating system)........................... ........ ........ ........ ........
Snubbing.................................................. ........ ........ ........
Types (rig assist & stand alone).......................... ........ ........ ........ ........
Applications (running & pulling production or kill
strings, resetting weight on packers, fishing for lost
wireline tools or parted kill strings & circulating
cement or fluid)......................................... ........ ........ ........ ........
Equipment (operating mechanism, power supply, control
assembly & basket, slip assembly, mast & counterbalance
winch & access window)................................... ........ ........ ........ ........
BOP equipment (tree connection or flange, rams, spool,
traveling slips, manifolds, auxiliary--full opening
safety valve inside BOP, maintenance & testing).......... ........ ........ ........ ........
34. The purpose & use of BOP closing units, including the
following:
Charging procedures include precharge & operating pressure ........ ........ ........
Fluid volumes (usable & required)......................... ........ ........ ........
Fluid pumps............................................... ........ ........ ........
Maintenance that includes charging fluid & inspection
procedures............................................... ........ ........ ........
35. Instructions on stripping & snubbing operations & using
the BOP system for working pipe in or out of a wellbore under
pressure..................................................... ........ ........ ........ ........
----------------------------------------------------------------------------------------------------------------
Table (b).--Production Safety Systems
------------------------------------------------------------------------
-------------------------------------------------------------------------
1. Government Regulations:
Pollution prevention & waste management.
Requirements for well completion/well workover operations.
2. Instructions in the following: (contained in, but not limited to, API
RP 14C):
Failures or malfunctions, in systems that cause abnormal conditions
& the detection of abnormal conditions.
Primary & secondary protection devices & procedures.
Safety devices that control undesirable events.
Safety analysis concepts.
Safety analysis of each basis production process component.
Protection concepts.
3. Hands on training on safety devices covering, installing, operating,
repairing or maintaining equipment:
High-low pressure sensors.
High-low level sensors.
Combustible gas detectors.
Pressure relief devices.
Flow line check valves.
Surface safety valves.
Shutdown valves.
Fire (flame, heat, or smoke) detectors.
Auxiliary devices (3-way block & bleed valves, time relays, 3-way
snap acting valves, etc.).
Surface-controlled subsurface safety valves &/or surface-control
equipment.
Subsurface-controlled subsurface safety valves.
4. Instructions on inspecting, testing & maintaining surface &
subsurface devices & surface control systems for subsurface safety
valves.
5. Instructions in at least one safety device that illustrates the
primary operation principle in each class for safety devices:
Basic operations principles.
Limits affecting application.
Problems causing equipment malfunction & how to correct these
problems.
A test for proper actuation point & operation.
Adjustments or calibrations.
Recording inspection results & malfunctions.
Special techniques for installing safety devices.
6. Instructions on the basic principle & logic of the emergency support
system:
Combustible & toxic gas detection system.
Liquid containment system.
Fire loop System.
Other fire detection systems.
Emergency shutdown system.
Subsurface safety valves.
------------------------------------------------------------------------
Sec. 250.230 If MMS tests employees at my worksite, what must I do?
(a) You must allow MMS to test employees at your worksite.
(b) You must identify your employees by:
(1) Current job classification;
(2) Name of the operator;
(3) Name of the most recent basic or advanced course taken by your
employees for their current job; and
(4) Name of the training organization.
[[Page 55691]]
(c) You must correct any deficiencies found by MMS.
Steps for correcting deficiencies may include:
(1) Isolating problem areas by doing more testing; and
(2) Reassigning employees or conducting the training they need (MMS
will not identify the employees it tests).
Sec. 250.231 If MMS tests trainees at a training organization's
facility, what must occur?
(a) Training organizations must allow MMS to test trainees.
(b) The trainee must pass the MMS-conducted test or a retest in
order for MMS to consider that the trainee completed the training.
Sec. 250.232 Why might MMS conduct its own tests?
MMS needs to identify the effectiveness of a training program that
provides safe and clean operations.
[FR Doc. 95-27077 Filed 11-1-95; 8:45 am]
BILLING CODE 4310-MR-M
This is a copy of a public record, reproduced as it was published. It is not legal advice, and it may not be the version a court would rely on. Check the official source before you cite it.