Training of Lessee and Contractor Employees Engaged in Oil and Gas and Sulphur Operations in the Outer Continental Shelf (OCS)
Federal RegisterFeb 5, 1997
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DEPARTMENT OF THE INTERIOR
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: Final rule.
-----------------------------------------------------------------------
SUMMARY: Their rule amends MMS regulations governing the training of
lessee and contractor employees engaged in oil and gas and sulphur
operations in the OCS. MMS is making this amendment to simplify the
training options and to provide the flexibility to use alternative
training methods.
EFFECTIVE DATE: March 7, 1997.
FOR FURTHER INFORMATION CONTACT: Mr. Joseph Levine, Information and
Training Branch, at (703) 787-1033.
SUPPLEMENTARY INFORMATION: On November 2, 1995, MMS published the
proposed rule in the Federal Register (60 FR 55683). During the 90-day
comment period that ended on January 31, 1996, MMS held a workshop. The
workshop held on December 6, 1995, in New Orleans, Louisiana, received
excellent participation from industry and training schools. We are
highlighting the comments we received for the proposed rule in the
``Response to Comments'' section.
Response to Comments
MMS received 28 comments on the proposed rule. We appreciate the
suggestions and comments that we received. We also appreciate the
positive comments on our new ``plain English'' style of writing
regulations.
We reviewed all of the comments, and in some instances, we revised
the final language based on these comments. MMS grouped the major
comments and organized them by regulation paragraph number or subject
as highlighted in the comment table.
Comment Table
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Requirement/subject Comment MMS response
------------------------------------------------------------------------
250.210..................... ``Alternative Disagree--MMS is not
Training'' limiting the
definition is methods, we're only
restrictive. giving examples by
using the term
``such as.''
250.210, 250.217, 250.222... Typographical errors Agree--We noted and
appear in the corrected the
Federal Register. errors.
250.214 (a) and (b)......... MMS should add a 60- Disagree--MMS wants
day grace period to to eliminate the
the training limits. cost and confusion
caused by using the
training
``windows'' of the
past.
250.214(c).................. The ``combination Disagree--Although
courses'' have too the hours have
many hours. slightly increased,
we moved small
tubing training to
well workover.
[[Page 5321]]
250.214..................... MMS needs a Agree--MMS added a
transition table table to ensure the
for the training smoothest
requirements since transition to the
each student is on new training
a different cycle. requirements
[250.214(d)].
250.219..................... Clarify that Agree--Although MMS
temporary employees did not mean to
need training or a imply that the
trained individual trained individual
(not necessarily a must be classified
supervisor) to as a supervisor, we
supervise them. adopted the
suggestion.
250.220..................... Change ``* * * (who Agree.
can evaluate their
work) * * *'' to
``* * * (who is
capable of
evaluating the
impact of the work
done''.
250.222..................... Is the only self- No, computer-based
paced training that is only one form of
MMS allows computer- self-paced
based?. training.
250.225(a)(2)............... Delete ``* * * Agree.
(instructors must
complete training
from an approved
training
organization) * *
*''.
250.225(j).................. Specify simulator Agree.
requirements for
workovers.
250.226(a).................. Schools should not Disagree--MMS may
need to maintain need 5 years of
training records data and we wish to
for 5 years because have the maximum
of the new training under the statute
period. of limitations.
250.228(a).................. MMS should specify Agree.
that the instructor
should only run one
simulator and have
teams of three or
less.
250.229 Table (a) number 21. Include drilling Agree.
supervisors in the
functions.
250.229..................... One commenter wanted Disagree--Considerin
MMS to g the special
significantly nature of well
expand the elements servicing and
in well-servicing workover, we feel
training and well that it is not
workover. appropriate to
expand their
training at this
time.
No refresher training....... Keep refresher Disagree--MMS
training for well deleted the
control because refresher
refreshers contain requirement and
course flexibility made the basic
to cover recent course more
field developments. frequent. With more
frequent basic
courses you can
still have the
flexibility to
cover field
developments. Also,
MMS does not
prohibit refresher
training.
Open-book tests............. Clarify the policy Agree--We now
on open-versus specify that we
closed-book tests. allow open
regulations and a
formula sheet
without examples
for well-control
tests (Sec.
250.227(a)(5)).
Third-parties............... The majority of MMS agrees with the
comments was comments and
against MMS having elected not to have
third-parties a third-party
accredit schools. accredit training
Those against programs. Instead,
having third- we plan to move
parties accredit into a performance-
schools cited based training
additional costs, program through a
potential conflicts future rulemaking.
of interest, and
additional
management layers
as their main
concerns.
Testing-out................. MMS should allow Disagree--MMS and
employees to take much of industry
and pass a test in sees value in
lieu of taking taking training
training. even if an employee
can pass the test.
A future rulemaking
will address
performance
measures.
------------------------------------------------------------------------
Also, MMS is changing the term ``certify'' to ``accredit'' in this
final rule because it is more accurate in the context of schools.
Executive Order (E.O.) 12866
This rule is not a significant rule under E.O. 12866.
E.O. 12988
The Department of the Interior (DOI) certified to the Office of
Management and Budget (OMB) that this rule meets the applicable civil
justice reform standards provided in sections 3(a) and 3(b)(2) of E.O.
12988.
Unfunded Mandates Reform Act of 1995
DOI determined and certifies according to the Unfunded Mandates
Reform Act, 2 U.S.C. 1502 et seq., that this rule will not impose a
cost of $100 million or more in any given year on State, local, and
tribal governments, or the private sector.
Regulatory Flexibility Act
DOI determined that this rule will not have a significant effect on
a substantial number of small entities.
Paperwork Reduction Act
This rule has been examined under the Paperwork Reduction Act of
1995 and has been found to contain no new reporting and information
collection requirements. OMB approved the existing information
collection requirements under OMB Control No. 1010-0078. An agency may
not conduct or sponsor, and a person is not required to respond to, a
collection of information unless it displays a currently valid OMB
control number. The reporting burden is estimated to average 13.5 hours
per response. Responses are mandatory. Proprietary data are covered
under 30 CFR 250.18.
Send comments regarding any aspect of this collection of
information, including suggestions for reducing the burden, to the
Information Collection Clearance Officer; Minerals Management Service;
Mail Stop 2053; 381 Elden Street; Herndon, Virginia 20170-4817 and to
the Office of Information and Regulatory Affairs; OMB; Attention: Desk
Officer for the Department of the Interior (1010-0078), 725 17th Street
NW, Washington, D.C. 20503.
Takings Implication Assessment
DOI determined that this rule does not represent a governmental
action capable of interfering with constitutionally protected rights.
Thus, DOI does not need to prepare a Takings Implication Assessment
pursuant to E.O. 12630, Governmental Actions and Interference with
Constitutionally Protected Property Rights.
National Environmental Policy Act
DOI determined that this rule does not constitute a major Federal
action significantly affecting the quality of the human environment,
therefore, an
[[Page 5322]]
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: January 27, 1997.
Sylvia V. Baca,
Deputy Assistant Secretary, Land and Minerals Management.
For the reasons stated in the preamble, the Minerals Management
Service (MMS) is amending 30 CFR part 250 to read 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. MMS is revising Subpart O 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?
250.212 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 accredit training organizations to teach?
250.224 How long is a training organization's accreditation valid?
250.225 What information must a training organization submit to
MMS?
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?
250.233 Can a training organization lose its accreditation?
Subpart O--Training
Sec. 250.209 Question index table.
The table in this section lists frequently asked training questions
and the location for the answers. The subjects are grouped as follows:
(a) General training requirements--Secs. 250.211 through 250.216.
(b) Departures from training requirements--Secs. 250.217 through
250.222.
(c) Training program accreditations--Secs. 250.223 through 250.229
and Sec. 250.233.
(d) MMS testing information--Secs. 250.230 through 250.232.
------------------------------------------------------------------------
Frequently asked questions CFR citation
------------------------------------------------------------------------
What is MMS's goal for well control and production
safety systems training?............................... Sec. 250.211
What type of training must I provide for my employees?.. Sec. 250.212
What documentation must I provide to trainees?.......... Sec. 250.213
How often must I provide training to my employees and
for how many hours?.................................... Sec. 250.214
Where must I get training for my employees?............. Sec. 250.215
Where can I find training guidelines for other topics?.. Sec. 250.216
Can I get an exception to the training requirements?.... Sec. 250.217
Can my employees change job certification?.............. Sec. 250.218
What must I do if I have temporary employees or on-the-
job trainees?.......................................... Sec. 250.219
What must manufacturer's representatives in production
safety systems do?..................................... Sec. 250.220
May I use alternative training methods?................. Sec. 250.221
What is MMS looking for when it reviews an alternative
training program?...................................... Sec. 250.222
Who may accredit training organizations to teach?....... Sec. 250.223
How long is a training organization's accreditation
valid?................................................. Sec. 250.224
What informaiton must a training organization submit to
MMS?................................................... Sec. 250.225
What additional requirements must a training
organization follow?................................... Sec. 250.226
What are MMS's requirements for the written test?....... Sec. 250.227
What are MMS's requirements for the hands-on simulator
and well test?......................................... Sec. 250.228
What elements must a basic course cover?................ Sec. 250.229
If MMS tests employees at my worksite, what must I do?.. Sec. 250.230
If MMS tests trainees at a training organization's
facility, what must occur?............................. Sec. 250.231
Why might MMS conduct its own tests?.................... Sec. 250.232
Can a training organization lose its accreditation?..... Sec. 250.233
------------------------------------------------------------------------
Sec. 250.210 Definitions.
Terms used in this subpart have the following meaning:
Alternative training methods means self-paced or team-paced
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 means both installing the original equipment and
replacing the equipment.
[[Page 5323]]
Lessee means the person, organization, agent, or designee
authorized to explore, develop, and produce leased deposits.
Maintaining means preventive maintenance, routine repair, and
replacing defective components.
Operating means testing, adjusting, calibrating, and recording test
and calibration results for the equipment.
Production safety systems employee 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.
Training means 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 approved by MMS to teach well
control for drilling, well completion/well workover, and well
servicing, and production safety systems.
Well-completion/well-workover (WO) well control includes small
tubing operations.
Well-servicing (WS) well control means snubbing and coil tubing.
Well-workover rig means a drilling rig used for well completion/
well workover.
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 according to the table
in this section.
------------------------------------------------------------------------
Training
Type of employee requirements Comments
------------------------------------------------------------------------
Drilling floorhand.......... Drilling well-
control course.\1\
Complete a well- You must log the
control drill at time it took to
the job site within complete each drill
the time limit in the driller's
prescribed by log and furnish the
company operating time to the
procedures.\2\. floorhand.
Participate in well- You must record the
control drills date and time it
under subpart D of took to complete
this part.\2\. each 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 the
qualifying test date and time it
consisting of a took to complete
well-control drill each drill in the
at the job site operations log.
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 times
control.\1\. during snubbing or
coil tubing
operations.
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 safety
devices.\1\
Employees who work in well Either WO well-
completion operations control course or
before or during tree drilling well-
installation. control course.\1\
------------------------------------------------------------------------
\1\ Employee may not work in the OCS unless this requirement is met.
\2\ Employee must complete this requirement before exceeding 6 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 course(s) required for their job. The employees
must carry the documents or keep them at the job site.
Sec. 250.214 How often must I provide training to my employees and 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 employees complete a well-control course on October 31, 1998, they
must again complete the training by October 31, 2000.
(b) You must ensure that applicable employees complete basic or
advanced production safety systems training at least every 3 years. For
example, if your employees complete production safety systems training
on October 31, 1998, they must again complete the training by October
31, 2001.
(c) You must ensure that your employees have at least the amount of
training listed in the table in Sec. 250.214(c). The maximum number of
hours per day of well control or production safety instruction time is
9 hours.
[[Page 5324]]
Training Hours
------------------------------------------------------------------------
Surface Subsea
option, option, No options,
Basic/advanced course minimum minimum minimum
hours hours \1\ hours
------------------------------------------------------------------------
Drilling (D)..................... 28 32 ...........
Well Completion/Workover (WO).... 32 36 ...........
Well Servicing (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 4 hours.
(d) For the first training course after March 7, 1997, you must
ensure that your employee follows the following transition schedule
table for well control.
Well Control Transition
------------------------------------------------------------------------
If your employees Then the employees must
------------------------------------------------------------------------
A. Completed a basic course on or after A. Complete an appropriate
[insert date 365 days prior to the basic course within 2 years to
effective date of the rule] or maintain certification, or
B. Completed a basic course before B. Complete an appropriate
[insert date 365 days prior to the basic course by [insert date
effective date of the rule]. 365 days after the effective
date of the rule].\2\
------------------------------------------------------------------------
\1\ Example A: If the effective date of this regulation is November 1,
1996, and your employees completed a basic course in Drilling and
Workover/Completion well control on December 9, 1995, your employees
must complete a basic Drilling and Workover/Completion well-control
course by December 9, 1997.
\2\ Example B: If the effective date of this regulation is November 1,
1996, and your employees completed a basic course in Well Servicing
[snubbing option] well control on November 15, 1994, your employees
must complete a basic course in Well Servicing [snubbing option] by
November 1, 1997.
(e) For the first training course after March 7, 1997, you must
ensure that your employee follows the following transition schedule
table for production.
Production Transition
------------------------------------------------------------------------
If your employees Then your employees must
------------------------------------------------------------------------
A. Completed a basic course on or after A. Complete a basic course
[insert date 545 days prior to the within 3 years to maintain
effective date of the rule], or certification, or
B. Completed a basic course before B. Complete a basic course by
[insert date 545 days prior to the [insert date 545 days after
effective date of the rule] the effective date of the
rule].
------------------------------------------------------------------------
(f) After your employee completes the transition training specified
in paragraph (d) or (e) of this section, the training cycle will be 2
years for well control and 3 years for production training (as shown in
Sec. 250.214 (a) and (b)).
Sec. 250.215 Where must I get training for my employees?
You must provide training by a training organization or program
approved by MMS.
Sec. 250.216 Where can I find training guidelines for other topics?
You can find guidelines in the subparts shown 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:
(a) MMS determines that the exception won't jeopardize the safety
of your personnel or create a hazard to the environment; and
(b) You need the exception because of unavoidable circumstances
that make compliance infeasible or impractical.
Sec. 250.218 Can my employees change job certification?
Only if you ensure that the employees complete training for the new
job before entering on duty.
Sec. 250.219 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 individual 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 is
also capable of evaluating the impact of the work done) accompany her/
him.
[[Page 5325]]
Sec. 250.221 May I use alternative training methods?
(a) You may receive a 1-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 What 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 accredit training organizations to teach?
MMS may accredit a training organization or program.
Sec. 250.224 How long is a training organization's accreditation
valid?
An accreditation is valid for a maximum of 4 years. A training
organization may apply to MMS before the fourth anniversary of the
effective accreditation date. The training organization must state the
changes (additions and deletions) to the last approved training
curriculum and plan.
Sec. 250.225 What information must a training organization submit to
MMS?
(a) Two copies of the detailed plan that includes the:
(1) Curriculum;
(2) Names and credentials of the instructors;
(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 the
training organization separates 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) Two copies of the training manual.
(c) A cross-reference that relates the requirements of this supbart
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,
(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 materials (for the advanced training option) such as
advanced training techniques or case studies.
(j) Information on the 3-D simulator or test wells:
(1) Capability for surface and/or subsea drilling well control, WO
and completion 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) The training organization must keep training records for each
trainee for 5 years. For example, if a trainee completed a well-control
course in 1996, the training organization may destroy the records at
the end of the year 2001. The training organization must keep the
following trainee record information:
(1) Daily attendance record including complete student sign-in
sheet and 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-year
timeframe starts with the program approval date. For example, if a
training program was accredited in 1995, at the end of the year 2000,
the training organization 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 current 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
personnel for their use during an onsite review.
(i) Submit the course schedule to the approving organization after
approval of the training program, annually, and before 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 and a class roster.
The class roster 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;
[[Page 5326]]
(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) The trainee's social security number;
(10) Trainee's employer;
(11) Actual job title of trainee;
(12) Job of 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;
(4) Offer a retest, when necessary, using different questions of
equal difficulty;
(5) Allow open-book regulations and a formula sheet (without
examples) for well control only; and
(6) Allocate no more than the following amount of time to the
minimum instruction time: 1 hour for a single course, 2 hours for a
combination of two basic courses, or 2.5 hours for a combination of
three or more courses.
(b) A trainee who fails a retest must repeat the training and pass
the test in order to work in the OCS in their job classification.
Sec. 250.228 What are MMS's requirements for the hands-on simulator
and well test?
(a) The training organization must ensure that:
(1) The test simulates a surface BOP (or subsea stack for the
subsea option) and the simulator is 3-D with actual gauges and dials.
(2) The instructor runs only one simulator and has a maximum of
three students in each team.
(3) The simulator test time allocated to the minimum instruction
time is 1 hour per course (i.e., 2 hours for a combination of two basic
courses, etc.).
(4) The trainees are able to:
(i) Kill the well before removing the three;
(ii) Determine slow pump rates;
(iii) Recognizes kick warnings sings;
(iv) Shut in a well
(v) Complete kill sheets;
(vi) Initiate kill procedures;
(vii) Maintain appropriate bottomhole pressure;
(viii) Maintain constant bottomhole pressure;
(ix) Recognize and handle unusual well-control situations;
(x) Control the kick as it reaches the choke line; and
(xi) Determine if kick gas or fluids are removed.
(5) In the subsea option, the trainees are able to:
(i) Determine choke line friction pressures for subsea BOP stacks;
and
(ii) Discuss and demonstrate procedures such as circulating the
riser and removing trapped gas in a subsea BOP stack.
(6) 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 to work in the OCS in their job classification.
Sec. 250.229 What elements must a basic course cover?
See Table (a) of this section for well control and Table (b) of
this section for production safety systems. The checks in 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 .............. .............. .............. ..............
vales.
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 hole during trips
including the importance of
filing 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 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.
[[Page 5327]]
Well completion & well .............. .............. ..............
workover requirements
(Subparts E & F of 30 CFR
part 250).
14. Procedures & sequentials
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..................... .............. .............. ..............
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
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.
[[Page 5328]]
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, and
check valve).
33. Methods for killing a
producing well, including:
Bullheading................. .............. .............. ..............
Lubricating & bleeding...... .............. .............. ..............
Coil tubing................. .............. .............. ..............
Applications (stimulation .............. .............. .............. ..............
operations, initiating
flow, & cleaning out sand
in tubing).
Equipment description (coil .............. .............. .............. ..............
tubing, reel, injecting
head, control assembly &
injector hosit).
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
fulid).
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 (useable & .............. .............. ..............
required).
Fluid pumps................. .............. .............. ..............
Maintenance that includes .............. .............. ..............
charging fluid & inspection
procedures.
35. Instructions on stripping & .............. .............. .............. ..............
snubbing operators & 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 basic production process component
Protection concepts
3. Hands on training on safety devices covering, installing, operating,
repairing or maintaining equipment:
[[Page 5329]]
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.
(c) You must correct any deficiencies found by MMS. Steps for
correcting deficiencies may include:
(1) Isolating problems by doing more testing; and
(2) Reassigning employees or conducting training (MMS will not
identify the employees it tests).
Sec. 250.231 If MMS test 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 for safe and clean operations.
Sec. 250.233 Can a training organization lose its accreditation?
Yes, an accredited organization can lose its accreditation. MMS may
revoke or suspend an organization's accreditation for noncompliance
with regulations or conditions of its accredited program, or assess
civil penalties under subpart N of this part.
[FR Doc. 97-2721 Filed 2-4-97; 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.