29604 Federal Register / Vol. 63, No. 104 / Monday, June 1, 1998 /Rules and Regulations

(2) The principal purpose for which

the Department intends to use the

information;

(3) The routine uses the Department

may make of the information; and

(4) The effects on the individuals, if

any, of not providing the information;

(d) Ensure that the component

maintains no system of records without

public notice and that it notifies

appropriate Department officials of the

existence or development of any system

of records that is not the subject of a

current or planned public notice;

(e) Maintain all records that are used

by the Department in making any

determination about an individual with

such accuracy, relevance, timeliness,

and completeness as is reasonably

necessary to ensure fairness to the

individual in the determination;

(f) Except as to disclosures made to an

agency or made under the FOIA, make

reasonable efforts, prior to

disseminating any record about an

individual, to ensure that the record is

accurate, relevant, timely, and complete;

(g) Maintain no record describing how

an individual exercises his or her First

Amendment rights, unless it is

expressly authorized by statute or by the

individual about whom the record is

maintained, or is pertinent to and

within the scope of an authorized law

enforcement activity;

(h) When required by the Act,

maintain an accounting in the specified

form of all disclosures of records by the

Department to persons, organizations, or

agencies;

(i) Maintain and use records with care

to prevent the unauthorized or

inadvertent disclosure of a record to

anyone; and

(j) Notify the appropriate Department

official of any record that contains

information that the Privacy Act does

not permit the Department to maintain.

§ 16.55 Other rights and services.

Nothing in this subpart shall be

construed to entitle any person, as of

right, to any service or to the disclosure

of any record to which such person is

not entitled under the Privacy Act.

4. Appendix I of part 16 is revised to

read as follows:

Appendix I to Part 16—Components of

the Department of Justice

Unless a separate address is listed below,

the address for each component is:

(component name), U.S. Department of

Justice, 950 Pennsylvania Avenue, NW.,

Washington, DC 20530–0001. For all

components marked by an asterisk, FOIA and

Privacy Act requests should be sent to the

Office of Information and Privacy, U.S.

Department of Justice, Flag Bldg., Suite 570,

Washington, DC 2053–0001. The components

are:

A

Office of the Attorney General *

Office of the Deputy Attorney General *

Office of the Associate Attorney General *

Office of the Solicitor General

B

Office of Information and Privacy *

Office of the Inspector General

Office of the Intelligence Policy and Review

Office of Intergovernmental Affairs *

Office of Investigative Agency Policies

Office of Legal Counsel

Office of Legislative Affairs *

Office of Policy Development *

Office of Professional Responsibility

Office of Public Affairs *

C

Antitrust Division, U.S. Department of

Justice, LPB Bldg., Suite 200, Washington,

DC 20530–0001

Civil Division, U.S. Department of Justice,

901E Bldg., Room 808, Washington, DC

20530–0001

Civil Rights Division, U.S. Department of

Justice, NYAV Bldg., Room 8000B,

Washington, DC 20530–0001

Criminal Division, U.S. Department of

Justice, WCTR Bldg., Suite 1075,

Washington, DC 20503–0001

Environment and Natural Resources

Division, U.S. Department of Justice, Post

Office Box 4390, Washington, DC 20044–

4390

Justice Management Division

Tax Division, U.S. Department of Justice, JCB

Bldg., Room 6823, Washington, DC 20503–

0001

Bureau of Prisons, U.S. Department of

Justice, HOLC Bldg., Room 738, 320 First

Street, NW., Washington, DC 20534–0001

Community Relations Service, U.S.

Department of Justice, BICN Bldg., Suite

2000, Washington, DC 20530–0001

Drug Enforcement Administration, U.S.

Department of Justice, Washington, DC

20537–0001

Executive Office for Immigration Review,

U.S. Department of Justice, Suite 2400,

5107 Leesburg Pike, Falls Church, VA

22041–0001

Executive Office for United States Attorneys,

U.S. Department of Justice, BICN Bldg.,

Room 7100, Washington, DC 20530–0001

Executive Office for United States Trustees,

U.S. Department of Justice, 901E Bldg.,

Room 780, Washington, DC 20530–0001

Federal Bureau of Investigation, U.S.

Department of Justice, 935 Pennsylvania

Avenue, NW., Washington, DC 20535–0001

(for field offices, consult your telephone

book)

Foreign Claims Settlement Commission, U.S.

Department of Justice, BICN Bldg., Room

6002, 600 E Street, NW., Washington, DC

20579–0001

Immigration and Naturalization Service, U.S.

Department of Justice, CAB Bldg., 425 Eye

Street, NW., Washington, DC 20536–0001

(for field offices, consult your telephone

book)

INTERPOL-U.S. National Central Bureau,

U.S. Department of Justice, Washington,

DC 20530–0001

National Drug Intelligence Center, U.S.

Department of Justice, Fifth Floor, 319

Washington Street, Johnstown, PA 15901–

1622

Office of Community Oriented Policing

Services, U.S. Department of Justice, VT1

Bldg., Twelfth Floor, Washington, DC

20530–0001

Office of Justice Programs, U.S. Department

of Justice, Room 5337, 810 Seventh Street,

NW., Washington, DC 20531–0001

Pardon Attorney, U.S. Department of Justice,

FRST Bldg., Fourth Floor, Washington, DC

20530–0001

United States Marshals Service, U.S.

Department of Justice, Lincoln Place, Room

1250, CSQ3, 600 Army Navy Drive,

Arlington, VA 22202–4210

PART 50—STATEMENTS OF POLICY

5. The authority citation for part 50

continues to read as follows:

Authority: 5 U.S.C. 301; 28 U.S.C. 509,

510; and 42 U.S.C. 1921 et seq., 1973c.

§ 50.8 [Removed and Reserved]

6. Section 50.8 of part 50 is removed

and reserved.

Dated: May 22, 1998.

Janet Reno,

Attorney General.

[FR Doc. 98–14341 Filed 5–29–98; 8:45 am]

BILLING CODE 4410–BE–M

DEPARTMENT OF THE INTERIOR

Minerals Management Service

30 CFR Part 250

RIN 1010–AC37

Blowout Preventer (BOP) Testing

Requirements for Drilling and

Completion Operations

AGENCY: Minerals Management Service

(MMS), Interior.

ACTION: Final rule.

SUMMARY: This rule amends the

regulations governing the testing

requirements for BOP systems used in

drilling and completion operations on

the Outer Continental Shelf (OCS). The

rule allows a lessee up to 14 days

between BOP pressure tests. MMS based

this rule on a study of BOP performance

which concluded that no statistical

difference exists in failure rates for

BOP’s tested between 0- and 7-day

intervals and between 8- and 14-day

intervals. MMS estimates that the 14-

day testing requirement could save

industry $35 to $46 million a year

without compromising safety.

EFFECTIVE DATE: The rule is effective on

June 30, 1998.

FOR FURTHER INFORMATION CONTACT: Bill

Hauser, Engineering and Research

Branch, at (703) 787–1613.
Federal Register / Vol. 63, No. 104 / Monday, June 1, 1998 /Rules and Regulations 29605

SUPPLEMENTARY INFORMATION: MMS

proposed revising the regulations for

BOP testing in a notice of proposed

rulemaking published in the Federal

Register (62 FR 37819) on July 15, 1997.

We received five sets of comments

during the 60-day comment period,

which closed on September 15, 1997.

This final rule amends the regulations

found at 30 CFR 250.407 and 250.516

and becomes effective on June 30, 1998.

On that date, MMS will rescind Notice

to Lessees and Operators (NTL) 97–1N

because the new rule will be in effect.

MMS issued NTL 97–1N on January 31,

1997, to inform lessees that they could

begin testing BOP systems on intervals

up to 14 days.

Comments on the Rule

The five commenters consisted of four

large oil companies and a drilling

contractor. All five commenters

supported the proposed revision to

allow lessees up to 14 days between

BOP pressures tests. In addition, they

commented on the following parts of the

proposed rule: testing frequency for

workovers; testing of blind-shear rams;

test duration; and use of maximum

anticipated surface pressure (MASP) for

determining BOP test pressures. Those

comments and MMS’’ responses are

discussed below.

BOP Testing Frequency During

Workovers

Comment—One company stated that

many workovers include completion or

re-completion operations and asked if

the amended regulations apply to the

completion phase of a workover.

Response—The revised BOP testing

requirements do not apply to the

completion phase of workover

operations. According to the definition

in § 250.601, workover operations mean

the work conducted on wells after the

initial completion for the purpose of

maintaining or restoring the

productivity of the well. After the initial

completion, you must test your BOP

equipment according to the

requirements of subpart F, Oil and Gas

Well-Workover Operations.

Comment—Another commenter asked

MMS to consider similar changes in

testing frequency for workover

operations after gathering necessary

data.

Response—MMS will consider similar

changes to the regulations after the

completion of an appropriate study.

Testing of the Blind or Blind-Shear Ram

Comment—One commenter

recommended that the requirement to

test the blind or blind-shear ram at least

once every 30 days (§ 250.407(d)(4))

should include an exclusion if the ram

was tested during a routine test.

Response—The intent of this

requirement is to ensure that the blind

or blind-shear ram is tested at least once

every 30 days. We revised the second

sentence in this paragraph to now read

as follows: ‘‘Additionally, the interval

between any blind or blind-shear ram

tests may not exceed 30 days.’’ The 30-

day interval begins with any test.

Testing of a Casing Safety Valve

Comment—One commenter asked

MMS to define what was meant by a

‘‘casing safety valve.’’ The commenter

interpreted ‘‘casing safety valve’’ as a

valve installed on a casing swage to

facilitate circulation while running

casing.

Response—We removed the term

‘‘casing safety valve’’ and have revised

the wording of the final rule to be closer

to the current rule. The new wording is

‘‘You must actuate safety valves

assembled with proper casing

connections prior to running casing.’’

Weekly Crew Drills

Comment—One company commented

that the new regulations required

weekly drills to familiarize personnel

engaged in completion operations but

there was not a similar requirement for

drilling personnel.

Response—MMS continues to require

well-controls drills for each drilling

crew. The requirements for well-control

drills during drilling are found in

§ 250.408. That section requires the

lessee to conduct a well-control drill for

each drilling crew.

Test Duration

Comment—One company thought

that MMS should require a 5-minute test

for large blowout preventers because of

the larger fluid volumes needed for

testing and leak detection.

Response—MMS requires a 5-minute

test for subsea BOP equipment because

of the larger volume of fluid in the

system. MMS believes that a 3-minute

test is appropriate for surface blowout

preventer equipment provided the

lessee measures the test pressures on the

outermost half of a 4-hour chart, on a 1-

hour chart, or on a digital recorder.

Use of MASP in Determining Test

Pressures

Comment—Three companies

commented on the use of MASP for

determining test pressures for BOP

equipment. One recommended using

MASP because it was more consistent

with current industry practices and

would reduce undue stress, wear, and

tear on BOP components. The company

recommended using a conservative

method of determining MASP. Another

company recommended that MMS not

use MASP for determining the required

BOP test pressure due to the variety of

methods used by operators to calculate

MASP. The third company did not feel

that changing the test pressures to

MASP will improve the reliability of

BOP equipment if the common

definition of MASP is used. However

that company said that testing to the

rated working pressure can be excessive

and that test pressures should be related

to the design of the well.

Response—MMS believes that these

comments show industry’s interest in

using MASP in determining BOP test

pressures. They also show that MMS

and industry must reach a common

methodology for determining MASP.

Therefore, MMS has decided not to

require the use of MASP for establishing

BOP test pressures in this rule. The rule

continues to require the lessee to test

BOP components at their rated working

pressures (70 percent for an annular

preventer) or as otherwise approved by

the District Supervisor.

As discussed in the preamble of the

proposed rule, District Supervisors base

the approval of alternate test pressures

on a comparison of the anticipated

surface pressure calculations submitted

with the application for permit to drill

(APD) to MASP calculations made by

MMS drilling engineers. If the two

calculations compare favorably, the

District Supervisor approves the

requested test pressures. If the

calculations for anticipated surface

pressure are less than those calculated

by MMS, the District Supervisor advises

the lessee of any necessary revisions to

the APD.

We are currently rewriting the

regulations for Subpart D, Oil and Gas

Drilling Operations, so we will continue

to examine the use of MASP in

determining BOP test pressures. We

plan to publish the Notice of Proposed

Rulemaking for subpart D by the end of

the summer.

Testing at Casing and Liner Points

MMS acknowledged in the preamble

to the proposed rule that there was at

least one situation where it may not be

necessary to test the BOP system. MMS

has added two sentences to

§ 250.407(a)(3) that explain when a

lessee will be allowed to omit a test of

the BOP system at some casing and liner

points. This addition is intended to

clearly describe in the regulatory text

the circumstance when MMS will allow

a lessee to not test the BOP system. That

circumstance occurs when a lessee

doesn’t remove the BOP stack to run
29606 Federal Register / Vol. 63, No. 104 / Monday, June 1, 1998 /Rules and Regulations

casing or a liner, and the required BOPtest pressures for the next section of the

hole are not greater than the test

pressures for the previous BOP test. The

lessee must clearly indicate in its APD

which casing strings and liners meet

these criteria.

Recently, MMS published a final rule

redesignating 30 CFR part 250. The new

numbering is used here as follows:

§ 250.406 replaces § 250.56; § 250.407

replaces § 250.57; § 250.408 replaces

§ 250.58; § 250.516 replaces § 250.86;

and § 250.601 replaces § 250.91.

Procedural Matters

Executive Order (E.O.) 12866

MMS estimates that this final rule

will save the oil and gas industry $34.5

to $46 million per year. These savings

result from having to conduct fewer

BOP tests and increased drilling

efficiency. Direct economic effects are

reduced drilling costs for each well

drilled on the OCS. The rule does not

add any new costs to industry, and it

will not reduce the level of safety to

personnel or the environment. Since the

rule will have an annual effect on the

economy of less than $100 million, the

rule is not a significant regulatory

action.

The rule will not affect the level of

drilling activity on the OCS. It will

reduce the number of BOP tests

conducted, which should result in

reduced drilling time for each well.

Once the lessee completes a well, the rig

will move on to the next well. This will

not have any adverse effects on

employment, investment, productivity,

innovation, or on the ability of U.S.-

based enterprises to compete with

foreign-based enterprises in other

markets because the economic effects

are minor. The rule will have no effect

on competition. Therefore, in

accordance with E. O. 12866, a review

by the Office of Management and

Budget (OMB) is not necessary.

Regulatory Flexibility Act

This final rule will not have any

significant effects on a substantial

number of small entities. This rule

affects only two groups that operate on

the OCS: (1) lessees that contract

drilling operations and (2) drilling

contractors.

A lessee that qualifies as a small

entity could see a minor, positive

economic benefit due to the cost savings

from conducting fewer BOP tests.

However, any savings would probably

be offset by increased costs to contract

a drilling rig. Day rates for offshore

drilling rigs are increasing due to high

rig utilization.

In general, entities that engage in

offshore activities are not small due to

technical and financial resources and

experience needed to safely conduct

these operations. Small entities are more

likely to operate onshore or in State

waters—areas not covered by this rule.

When small entities do work in the

OCS, they are likely to be service

contractors and not owner/operators of

OCS platforms or drilling rigs.

Your comments are important. The

Small Business and Agriculture

Regulatory Enforcement Ombudsman

and 10 Regional Fairness Boards were

established to receive comments from

small business about Federal agency

enforcement actions. The Ombudsman

will annually evaluate the enforcement

activities and rate each agency’s

responsiveness to small business. If you

wish to comment on the enforcement

actions of MMS, call toll-free (888) 734–

3247.

Paperwork Reduction Act (PRA) of 1995

As part of the Notice of Proposed

Rulemaking process, OMB approved the

proposed information collection

requirements in 30 CFR Part 250,

Subpart D, Oil and Gas Drilling

Operations (OMB Control Number

1010–0053) and Subpart E, Oil and Gas

Well-Completion Operations (OMB

Control Number 1010–0067), as

required by the PRA of 1995 (44 U.S.C.

3501 et seq.). MMS did not receive any

comments on the information collection

aspects in the notice of proposed

rulemaking. The final rule did not

change any of the information collection

requirements. PRA provides that 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 collections of information in

these subparts consist of reporting and

recordkeeping requirements on the

conditions of a drilling site and wellcompletion operations in the OCS. MMS

uses the information to determine if

lessees are properly providing for safe

operations and protection of human life

or health and the environment. MMS

estimated the total annual burden for

subpart D to be 108,581 hours. This

reflects a decrease of 12,499

recordkeeping hours as a result of the

rule. The estimated total annual burden

for subpart E is 4,841 hours. MMS

estimates that the rule reduced the

annual burden for subpart E by 2,563

recordkeeping hours.

Takings Implication Assessment

The Department of the Interior (DOI)

certifies that this final rule does not

represent a governmental action capable

of interference with constitutionally

protected property rights. Thus, MMS

did not need to prepare a Takings

Implication Assessment pursuant to

E.O. 12630, Governmental Action and

Interference with Constitutionally

Protected Property Rights.

Unfunded Mandates Reform Act of 1995

DOI has 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.

E.O. 12988

DOI has certified to OMB that this

rule meets the applicable civil justice

reform standards provided in sections

3(a) and 3(b)(2) of E.O. 12988.

National Environmental Policy Act

DOI has determined that this action

does not constitute a major Federal

action significantly affecting the quality

of the human environment. Therefore,

preparation of an Environmental Impact

Statement is not required.

List of Subjects in 30 CFR Part 250

Continental shelf, Environmental

impact statements, Environmental

protection, Government contracts,

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: May 15, 1998.

Sylvia V. Baca,

Deputy Assistant Secretary, Land and

Minerals Management.

For the reasons stated in the

preamble, the Minerals Management

Service (MMS) amends 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: U.S.C. 1334.

2. In § 250.406, the fourth sentence in

paragraph (d)(10)(i) is revised to read as

follows:

§ 250.406 Blowout preventer systems and

system components.

* * * * *

(d) * * *
Federal Register / Vol. 63, No. 104 / Monday, June 1, 1998 /Rules and Regulations 29607

(10) * * *

(i) * * * All required manual and

remotely controlled valves of a kelly

cock or comparable type in a top-drive

system must be essentially full-opening

and tested according to the test pressure

and test frequency as stated in § 250.407

of this part. * * *

3. Section 250.407 is revised to read

as follows:

§ 250.407 Blowout preventer (BOP) system

tests, inspections, and maintenance.

(a) BOP pressure testing timeframes.

You must pressure test your BOP

system:

(1) When installed;

(2) Before 14 days have elapsed since

your last BOP pressure test. You must

begin to test your BOP system before 12

a.m. (midnight) on the 14th day

following the conclusion of the previous

test. However, the District Supervisor

may require testing every 7 days if

conditions or BOP performance warrant;

and

(3) Before drilling out each string of

casing or a liner. The District Supervisor

may allow you to omit this test if you

did not remove the BOP stack to run the

casing string or liner and the required

BOP-test pressures for the next section

of the hole are not greater than the test

pressures for the previous BOP test. You

must indicate in your APD which casing

strings and liners meet these criteria.

(b) BOP test pressures. When you test

the BOP system, you must conduct a

low pressure and a high pressure test for

each BOP component. Each individual

pressure test must hold pressure long

enough to demonstrate that the tested

component(s) holds the required

pressure. Required test pressures are as

follows:

(1) All low pressure tests must be

between 200 and 300 psi. Any initial

pressure above 300 psi must be bled

back to a pressure between 200 and 300

psi before starting the test. If the initial

pressure exceeds 500 psi, you must

bleed back to zero and reinitiate the test.

You must conduct the low pressure test

before the high pressure test.

(2) For ram-type BOP’s, choke

manifold, and other BOP equipment, the

high pressure test must equal the rated

working pressure of the equipment or

the pressure otherwise approved by the

District Supervisor; and

(3) For annular-type BOP’s, the high

pressure test must equal 70 percent of

the rated working pressure of the

equipment or the pressure otherwise

approved by the District Supervisor.

(c) Duration of pressure test. Each test

must hold the required pressure for 5

minutes.

(1) For surface BOP systems and

surface equipment of a subsea BOP

system, a 3-minute test duration is

acceptable if you record your test

pressures on the outermost half of a 4-

hour chart, on a 1-hour chart, or on a

digital recorder.

(2) If the equipment does not hold the

required pressure during a test, you

must remedy the problem and retest the

affected component(s).

(d) Additional BOP testing

requirements. You must:

(1) Use water to test a surface BOP

system;

(2) Stump test a subsurface BOP

system before installation. You must use

water to stump test a subsea BOP

system. You may use drilling fluids to

conduct subsequent tests of a subsea

BOP system;

(3) Alternate tests between control

stations and pods. If a control station or

pod is not functional, you must suspend

further drilling operations until that

station or pod is operable;

(4) Pressure test the blind or blindshear ram during a stump test and at all

casing points. Additionally, the interval

between any blind or blind-shear ram

tests may not exceed 30 days;

(5) Function test annulars and rams

every 7 days between pressure tests;

(6) Pressure-test variable bore-pipe

rams against all sizes of pipe in use,

excluding drill collars and bottom-hole

tools;

(7) Test affected BOP components

following the disconnection or repair of

any well-pressure containment seal in

the wellhead or BOP stack assembly;

(8) Actuate safety valves assembled

with proper casing connections prior to

running casing, and

(9) If you install casing rams, you

must test the ram bonnet before running

casing.

(e) Postponing BOP tests. You may

postpone a BOP test if you have wellcontrol problems such as lost

circulation, formation fluid influx, or

stuck drill pipe. If this occurs, you must

conduct the required BOP test on the

first trip out of the hole. You must

record the reason for postponing any

test in the driller’s report.

(f) Visual inspections. You must

visually inspect your surface and subsea

BOP systems and marine riser at least

once each day if weather and sea

conditions permit. You may use

television cameras to inspect subsea

equipment. The District Supervisor may

approve alternate methods and

frequencies to inspect a marine riser.

Casing risers on fixed structures and

jackup rigs are not subject to the daily

underwater inspections.

(g) BOP maintenance. You must

maintain your BOP system to ensure

that the equipment functions properly.

(h) BOP test records. You must record

the time, date, and results of all pressure

tests, actuations, and inspections of the

BOP system, system components, and

marine riser in the driller’s report. In

addition, you must:

(1) Record BOP test pressures on

pressure charts;

(2) Have your onsite representative

certify (sign and date) BOP test charts

and reports as correct;

(3) Document the sequential order of

BOP and auxiliary equipment testing

and the pressure and duration of each

test. You may reference a BOP test plan

if it is available at the facility;

(4) Identify the control station or pod

used during the test;

(5) Identify any problems or

irregularities observed during BOP

system testing and record actions taken

to remedy the problems or irregularities;

(6) Retain all records, including

pressure charts, driller’s report, and

referenced documents, pertaining to

BOP tests, actuations, and inspections at

the facility for the duration of drilling;

and

(7) After drilling is completed, you

must retain all the records listed in

paragraph (h)(6) of this section for a

period of 2 years at the facility, at the

lessee’s field office nearest the Outer

Continental Shelf (OCS) facility, or at

another location conveniently available

to the District Supervisor.

(i) Alternate methods. The District

Supervisor may require, or approve,

more frequent testing, as well as

different test pressures and inspection

methods, or other practices.

4. Section 250.516 is revised to read

as follows:

§ 250.516 Blowout preventer system tests,

inspections, and maintenance.

(a) BOP pressure testing timeframes.

You must pressure test your BOP

system:

(1) When installed; and

(2) Before 14 days have elapsed since

your last BOP pressure test. You must

begin to test your BOP system before 12

a.m. (midnight) on the 14th day

following the conclusion of the previous

test. However, the District Supervisor

may require testing every 7 days if

conditions or BOP performance warrant.

(b) BOP test pressures. When you test

the BOP system, you must conduct a

low pressure and a high pressure test for

each BOP component. Each individual

pressure test must hold pressure long

enough to demonstrate that the tested

component(s) holds the required

pressure. The District Supervisor may

approve or require other test pressures

or practices. Required test pressures are

as follows:
29608 Federal Register / Vol. 63, No. 104 / Monday, June 1, 1998 /Rules and Regulations

(1) All low pressure tests must be

between 200 and 300 psi. Any initial

pressure above 300 psi must be bled

back to a pressure between 200 and 300

psi before starting the test. If the initial

pressure exceeds 500 psi, you must

bleed back to zero and reinitiate the test.

You must conduct the low pressure test

before the high pressure test.

(2) For ram-type BOP’s, choke

manifold, and other BOP equipment, the

high pressure test must equal the rated

working pressure of the equipment.

(3) For annular-type BOP’s, the high

pressure test must equal 70 percent of

the rated working pressure of the

equipment.

(c) Duration of pressure test. Each test

must hold the required pressure for 5

minutes.

(1) For surface BOP systems and

surface equipment of a subsea BOP

system, a 3-minute test duration is

acceptable if you record your test

pressures on the outermost half of a 4-

hour chart, on a 1-hour chart, or on a

digital recorder.

(2) If the equipment does not hold the

required pressure during a test, you

must remedy the problem and retest the

affected component(s).

(d) Additional BOP testing

requirements. You must:

(1) Use water to test the surface BOP

system;

(2) Stump test a subsurface BOP

system before installation. You must use

water to stump test a subsea BOP

system. You may use drilling or

completion fluids to conduct

subsequent tests of a subsea BOP

system;

(3) Alternate tests between control

stations and pods. If a control station or

pod is not functional, you must suspend

further completion operations until that

station or pod is operable;

(4) Pressure test the blind or blindshear ram at least every 30 days;

(5) Function test annulars and rams

every 7 days;

(6) Pressure-test variable bore-pipe

rams against all sizes of pipe in use,

excluding drill collars and bottom-hole

tools; and

(7) Test affected BOP components

following the disconnection or repair of

any well-pressure containment seal in

the wellhead or BOP stack assembly;

(e) Postponing BOP tests. You may

postpone a BOP test if you have wellcontrol problems. You must conduct the

required BOP test as soon as possible

(i.e., first trip out of the hole) after the

problem has been remedied. You must

record the reason for postponing any

test in the driller’s report.

(f) Weekly crew drills. You must

conduct a weekly drill to familiarize all

personnel engaged in well-completion

operations with appropriate safety

measures.

(g) BOP inspections. You must

visually inspect your BOP system and

marine riser at least once each day if

weather and sea conditions permit. You

may use television cameras to inspect

this equipment. The District Supervisor

may approve alternate methods and

frequencies to inspect a marine riser.

(h) BOP maintenance. You must

maintain your BOP system to ensure

that the equipment functions properly.

(i) BOP test records. You must record

the time, date, and results of all pressure

tests, actuations, crew drills, and

inspections of the BOP system, system

components, and marine riser in the

driller’s report. In addition, you must:

(1) Record BOP test pressures on

pressure charts;

(2) Have your onsite representative

certify (sign and date) BOP test charts

and reports as correct;

(3) Document the sequential order of

BOP and auxiliary equipment testing

and the pressure and duration of each

test. You may reference a BOP test plan

if it is available at the facility;

(4) Identify the control station or pod

used during the test;

(5) Identify any problems or

irregularities observed during BOP

system and equipment testing and

record actions taken to remedy the

problems or irregularities;

(6) Retain all records including

pressure charts, driller’s report, and

referenced documents pertaining to BOP

tests, actuations, and inspections at the

facility for the duration of the

completion activity; and

(7) After completion of the well, you

must retain all the records listed in

paragraph (i)(6) of this section for a

period of 2 years at the facility, at the

lessee’s field office nearest the OCS

facility, or at another location

conveniently available to the District

Supervisor.

(j) Alternate methods. The District

Supervisor may require, or approve,

more frequent testing, as well as

different test pressures and inspection

methods, or other practices.

[FR Doc. 98–14294 Filed 5–29–98; 8:45 am]

BILLING CODE 4310–MR–P

DEPARTMENT OF THE TREASURY

Office of Foreign Assets Control

31 CFR Chapter V

Blocked Persons, Specially Designated

Nationals, Specially Designated

Terrorists, Specially Designated

Narcotics Traffickers, and Blocked

Vessels: Addition of Sudanese

Government Designations, Removal of

Two Individuals, and Unblocking of a

Vessel

AGENCY: Office of Foreign Assets

Control, Treasury.

ACTION: Amendment of final rule.

SUMMARY: The Treasury Department is

adding to appendices A and B to 31 CFR

chapter V the names of 62 entities

which have been determined to act for

or on behalf of, or to be owned or

controlled by the Government of Sudan.

In addition, the entries for two

individuals previously designated as

specially designated narcotics traffickers

are being removed from appendices A

and B. The entry for a vessel is also

being removed from appendix C, as it is

no longer considered to be property in

which the Government of Cuba has an

interest. Technical changes are also

made to the notes to the appendices.

EFFECTIVE DATE: May 26, 1998.

FOR FURTHER INFORMATION CONTACT:

Office of Foreign Assets Control,

Department of the Treasury,

Washington, DC 20220; tel.: 202/622–

2520.

SUPPLEMENTARY INFORMATION:

Electronic Availability

This document is available as an

electronic file on The Federal Bulletin

Board the day of publication in the

Federal Register. By modem, dial 202/

512–1387 and type ‘‘/GO FAC,’’ or call

202/512–1530 for disk or paper copies.

This file is available for downloading

without charge in WordPerfect 5.1,

ASCII, and Adobe AcrobatR readable

(*.PDF) formats. For Internet access, the

address for use with the World Wide

Web (Home Page), Telnet, or FTP

protocol is: fedbbs.access.gpo.gov. The

document is also accessible for

downloading in ASCII format without

charge from Treasury’s Electronic

Library (‘‘TEL’’) in the ‘‘Business, Trade

and Labor Mall’’ of the FedWorld

bulletin board. By modem, dial 703/

321–3339, and select the appropriate

self–expanding file in TEL. For Internet

access, use one of the following

protocols: Telnet = fedworld.gov

(192.239.93.3); World Wide Web (Home

Page) = http://www.fedworld.gov; FTP