[Federal Register Volume 62, Number 223 (Wednesday, November 19, 1997)]
[Rules and Regulations]
[Pages 61692-61695]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 97-30216]
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DEPARTMENT OF TRANSPORTATION
Research and Special Programs Administration
49 CFR Parts 191, 192 and 195
[Docket No. RSPA 97-2096; Amdt Nos. 191-12; 192-81; 195-59]
RIN 2137-AC99
Pipeline Safety: Regulations Implementing Memorandum of
Understanding With the Department of the Interior
AGENCY: Research and Special Programs Administration (RSPA), DOT.
ACTION: Direct final rule.
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SUMMARY: This direct final rule (DFR) would implement a provision of a
December 10, 1996, Memorandum of Understanding (MOU) between the
Department of the Interior (DOI) and the Department of Transportation
(DOT) regarding Outer Continental Shelf (OCS) pipelines by
redesignating the point at which an OCS pipeline is subject to RSPA
regulations. Under this rule, RSPA would establish and enforce design,
construction, operation, and maintenance regulations and investigate
certain accidents for all pipelines located downstream of the point at
which operating responsibility for the pipelines transfers from a
producing operator to a transporting operator.
DATES: This direct final rule takes effect March 19, 1998. If RSPA does
not receive any adverse comment or notice of intent to file an adverse
comment by January 20, 1998 the rule will become effective on the date
specified. RSPA will issue a subsequent notice in the Federal Register
by February 17, 1998, after the close of the comment period, to confirm
that fact and reiterate the effective date. If an adverse comment or
notice of intent to file an adverse comment is received, RSPA will
issue a timely notice in the Federal Register to confirm that fact and
to withdraw the DFR in whole or in part. RSPA may then incorporate the
adverse comment into a subsequent DFR or may publish a notice of
proposed rulemaking.
ADDRESSES: Written comments on the subject of this DFR may be submitted
to the Dockets Facility, U.S. Department of Transportation, 400 Seventh
Street, SW, Plaza 401, Washington, DC 20590-0001. Comments should
identify the docket number of this DFR, RSPA-97-2096. Persons should
submit the original and one copy. Persons wishing to receive
confirmation of receipt of their comments must include a stamped, self-
addressed postcard. Alternatively, comments may be submitted via e-mail
to le.herrick@rspa.dot.gov. The Dockets facility is open from 10:00
a.m. to 5:00 p.m., Monday through Friday, except on Federal holidays.
FOR FURTHER INFORMATION CONTACT: L.E. Herrick, (202) 366-5523 or e-mail
le.herrick@rspa.dot.gov regarding the subject matter of this DFR, or
the Dockets Facility, (202) 366-5046, regarding copies of this DFR or
other information in the docket.
SUPPLEMENTARY INFORMATION:
Background
Under an MOU dated May 6, 1976, RSPA regulated hazardous liquid,
carbon dioxide, and natural gas pipelines located downstream of the
outlet flange of each facility where hydrocarbons are first produced or
where produced hydrocarbons are first separated, dehydrated, or
otherwise processed, whichever facility is farther downstream. DOI
regulated those pipelines located upstream of this point. The
Departments agreed to change this regulatory boundary with the signing
of the December 10, 1996, MOU. The 1996 MOU was the result of
negotiations that began in the summer of 1993, which included a high
degree of participation from the regulated industry. RSPA and DOI's
Minerals Management Service (MMS) solicited public comments on a draft
MOU through a joint Federal Register notice (60 FR 27546; May 24,
1995). The notice also announced a public meeting at the MMS Gulf of
Mexico regional office in New Orleans, Louisiana, on August 1, 1995, to
discuss the proposal. Over 70 people attended the meeting, which
generated over 100 pages of comments from natural gas and petroleum
trade organizations; natural gas and oil exploration and production
companies; transmission companies; offshore construction companies; and
industry consultants. Twenty-three individuals and organizations
submitted written comments on the Federal Register notice. A transcript
of this meeting and copies of the comments are available in Docket No.
RSPA-97-2096.
In May 1996, RSPA and MMS met with an industry workgroup
representing OCS oil and natural gas producers and transmission
pipeline
[[Page 61693]]
operators. The workgroup proposed that the agencies allow individual
operators of production and transportation facilities to define the
boundaries of their respective facilities. They suggested that
producers and transporters can best make such decisions based on the
unique operating characteristics of each facility. Under this rule,
RSPA would establish and enforce design, construction, operation, and
maintenance regulations and investigate certain accidents for all OCS
transportation pipelines beginning downstream of the point at which
operating responsibility transfers from a producing operator to a
transporting operator. Producing operators are companies which are
engaged in the extraction and processing of hydrocarbons on the OCS.
Transporting operators are companies which are engaged in the
transportation of those hydrocarbons.
Intent of the Rule
The intent of this rule is to require OCS production and
transportation pipeline operators to designate the specific points on
their pipelines where operating responsibility transfers from a
producing operator to an adjoining transporting operator. The rule
would amend 49 CFR parts 191, 192 and 195. Generally, operators will
have 60 days after the date the rule becomes final to durably mark the
specific points at which operating responsibility transfers. In most
cases, the specific transfer points will be easily identifiable because
of specific valves or flanges where the adjoining operations connect,
or because of differences in paint used by adjoining operators to
protect and maintain pipeline coatings or surfaces. For those instances
in which the transfer points are not identifiable by a durable marking,
each operator will have 180 days after the final rule becomes effective
to identify the transfer points on a schematic. The 180-day period will
give operators time to identify the transfer points during routine
maintenance. If it is not practicable to durably mark a transfer point,
and the transfer point is located above water, then the operator must
depict the transfer point on a schematic maintained near the transfer
point. Some transfer points may be located underwater. In such cases,
the operator must identify the transfer point on a schematic which must
be maintained at the nearest upstream facility and provided to RSPA
upon request.
For those instances in which adjoining operators do not or can not
agree on a transfer point, RSPA's Office of Pipeline Safety (OPS) and
MMS will make a joint determination of the boundary.
The OPS and MMS may, through their enforcement agencies and in
consultation with the affected parties, agree to exceptions to the
general boundary description (operations transfer point) on a facility-
by-facility or area-by-area basis. Operators may also petition OPS and
MMS for exceptions to the general boundary description.
Conversion to service: A pipeline previously used in service and
not subject to DOT regulations which comes under these regulations as a
result of this rulemaking qualifies for use under the DOT regulations
if the operator prepares and follows a written procedure to carry out
the requirements of 49 CFR 192.14 or 195.5 (Conversion to service
subject to this part). Pipeline segments designed and constructed under
DOT regulations before March 19, 1998 may continue to operate under DOT
design and construction requirements until significant modifications or
repairs are made to those segments. After March 19, 1998 DOI
operational and maintenance requirements will apply to those segments.
Rulemaking Analysis
The December 1996 MOU redefined the DOT/DOI regulatory boundary
definition from the OCS facility where hydrocarbons are ``first
produced, separated, dehydrated, or otherwise processed'' to the point
at which ``operating responsibility for the pipelines transfers from a
producing operator to a transporting operator''. The MOU places, to the
greatest extent practicable, producer-operated pipelines under DOI
regulation and transporter-operated pipelines under DOT regulation. The
changes in this rule would substantially reduce the regulatory burdens
currently caused by the overlapping Federal regulatory responsibilities
and the inconsistencies between the requirements. The changes will
substantially increase the efficiency of governmental resources on the
OCS without compromising safety.
Executive Order (E.O.) 12866
RSPA reviewed this rule under E.O. 12866 and determined that this
is not an economically significant rule. The Office of Management and
Budget (OMB) has not asked to review this rule under E.O. 12866.
Regulatory Flexibility Act
Oil and gas and production and transportation companies are
classified under Standard Industrial Codes (SIC's) by the Census
Bureau. The Small Business Administration further classifies ``small
businesses'' in the various offshore sectors as follows: (1) Oil and
gas producers that have fewer than 500 employees, (2) liquid pipeline
companies than have fewer than 1,500 employees; (3) natural gas
pipeline companies that have gross annual receipts of $25 million or
less; and (4) offshore oil and gas field exploration service or
production service companies that have gross annual receipts of $5
million or less. There are many companies on the OCS that are ``small
businesses'' by these definitions. However, the technology necessary
for conducting offshore oil and gas exploration and development
activities is very complex and costly, and most entities that engage in
offshore activities have considerable financial resources well beyond
what would normally be considered ``small business.'' These entities
customarily conduct their operations by contracting with offshore
drilling or service companies and therefore tend to have relatively few
employees compared to the considerable financial resources of their
operations.
This rule would affect a substantial number of ``small entities;''
however, the economic effects of the rule would not be significant. The
economic effects on the oil and gas production and transportation
companies directly affected by the rule would be insignificant because
of the minimal costs that operators incur during the first year that
the rule is implemented. (In that year, offshore producers would have
to identify all points on their pipelines at which operating
responsibility transfers from a producer to a transporter. In
succeeding years there would be virtually no economic impact resulting
from the rule.) The offshore service companies would be indirectly
affected by the rule through their contractual relationships with the
primary producing and transporting companies--they would not be
directly regulated in any way. This rule would not impose any new
restrictions on small pipeline service companies or manufacturers, nor
will it cause their business practices to change. To the extent that
this rule might eventually cause some of the relatively larger OCS
operators to make modifications to their pipelines, it may have a minor
beneficial effect of increasing demand for the services and equipment
of smaller service companies and manufacturers.
Paperwork Reduction Act
This rule contains a collection of information which RSPA is
submitting
[[Page 61694]]
to the Office of Management and Budget (OMB) for review and approval
under section 3507(d) of the Paperwork Reduction Act of 1995. As part
of RSPA's continuing effort to reduce paperwork and respondent burdens,
RSPA invites the public and other Federal agencies to comment on any
aspect of the reporting burden in 49 CFR 192 and 195 as amended by this
DFR. Submit your comments to the Office of Information and Regulatory
Affairs; OMB; Attention: Desk Officer for the Department of
Transportation (Docket No. RSPA 97-2096); Washington, D.C. 20503. Send
a copy of your comments to L.E. Herrick, Room 2335, 400 Seventh Street,
Washington, DC 20590-0001. You may obtain a copy of the supporting
statement for the collection of information by contacting the Dockets
Facility.
OMB may make a decision to approve or disapprove this collection of
information after 30 days from receipt of our request. Therefore, your
comments are best assured of being considered by OMB if OMB receives
them within that time period. However, RSPA will consider all comments
received during the comment period for this direct final rule.
The Paperwork Reduction Act of 1995 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 title of this collection of information is ``49 CFR 191, 192
and 195 Pipeline Safety: Regulations Implementing Memorandum of
Understanding with the Department of the Interior.''
The collection of information in the DFR and for each transporter
operating a pipeline consists of: (1) Reviewing existing pipeline maps,
(2) conferring and agreeing with operators of adjoining production
pipeline segments concerning the locations of specific transfer points,
and (3) either marking directly on each pipeline or depicting on a
schematic the specific point on each pipeline where operating
responsibility transfers from the producing operator to a transporting
operator. As stated above under the ``Intent of the Rule'' section,
specific transfer points will be easily identifiable in most cases,
either because of specific valves or flanges where the adjoining
operations connect, or because of differences in paint that adjoining
operators use to protect and maintain pipeline coatings or surfaces.
Generally operators will have until 60 days after the date the rule
becomes final to durably mark the points at which operating
responsibility transfers. For those relatively few instances where the
transfer points are not identifiable by durable marking, operators will
have 180 days after the date the rule becomes final to identify, on a
schematic, the transfer points. The requirement to identify the
boundary is mandatory. The RSPA will use the information to determine
the demarcation where DOT will establish and enforce design,
construction, operation, and maintenance regulations and investigate
certain accidents, as distinguished from MMS responsibilities.
In calculating the burden, RSPA assumed that respondents perform
most of the requirements and maintain records in the normal course of
their activities, such as painting their pipelines and maintaining
valves and flanges. RSPA considers these to be usual and customary
practices and did not include them in the burden estimates. Commenters
are invited to provide information if they disagree with this
assumption and they should tell RSPA what are the burden hours and
costs imposed by this collection of information (i.e., marking of
transfer points).
The regulated community consists of approximately 160 Federal OCS
oil and gas producers and 70 transportation pipeline operators. There
are approximately 3,000 points where operating responsibility for
pipelines transfers from a producer to a transporter. The RSPA assumes
from discussions with MMS and the operators that about 2,400
(representing 80 percent) of these transfer points are already marked.
Therefore, this rulemaking would require a one-time identification and
marking of about 600 points where operating responsibility for
pipelines transfers from a producer to a transporter. For the 2,400
transfer points that are clearly marked, there would be no information
burden. The 600 unmarked transfer points, on the other hand, would
require widely-varying times for identification depending on whether a
painted line or a schematic was used to identify the transfer point.
The public reporting burden for this information collection
requirement is estimated to average 5 hours per response for each
transfer point. This includes the time for reviewing instructions,
searching existing data sources, gathering and maintaining the data
needed, and completing the required marking. Based on 600 unmarked
transfer points, RSPA estimates that the total one-time burden of this
collection of information to be 3,000 hours total. The average
annualized burden over a 3-year period would be 1,000 hours. Based on
$35 per hour, the total burden hour cost to respondents is estimated to
be $35,000 annually.
Takings Implication Assessment
The DOT certifies that the rule does not represent a governmental
action capable of interference with constitutionally protected property
rights. Thus, a Takings Implication Assessment need not be prepared
pursuant to E.O. 12630, Government Action and Interference with
Constitutionally Protected Property Rights.
Unfunded Mandates Reform Act of 1995
This rule does not contain any unfunded mandates to State, local,
or tribal governments, nor would it impose significant regulatory costs
on the private sector. Anticipated costs to the private sector will be
far below the $100 million annual threshold that was established by the
Unfunded Mandates Reform Act.
E.O. 12988
The DOT has certified to OMB that this regulation meets the
applicable civil justice reform standards provided in Sections 3(a) and
3(b)(2) of E.O. 12988.
National Environmental Policy Act
The DOT 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
49 CFR Part 191
Gas, Pipeline safety, Reporting and recordkeeping requirements.
49 CFR Part 192
Pipeline safety, Reporting and recordkeeping requirements.
49 CFR Part 195
Anhydrous ammonia, Carbon dioxide, Petroleum, Pipeline safety,
Reporting and recordkeeping requirements.
For the reasons set out in the preamble, RSPA amends 49 CFR parts
191, 192 and 195 as follows:
PART 191--[AMENDED]
1. The authority citation for part 191 continues to read as
follows:
Authority: 49 U.S.C. 5121, 60102, 60103, 60104, 60108, 60117,
60118, and 60124; and 49 CFR 1.53.
[[Page 61695]]
2. Section 191.1 is amended by adding paragraph (b)(3) to read as
follows:
Sec. 191.1 Scope.
* * * * *
(b) * * *
(3) On the Outer Continental Shelf upstream of the point at which
operating responsibility transfers from a producing operator to a
transporting operator.
3. Section 191.3 is amended by adding a definition in alphabetical
order to read as follows:
Sec. 191.3 Definitions.
* * * * *
Outer Continental Shelf means all submerged lands lying seaward and
outside the area of lands beneath navigable waters as defined in
Section 2 of the Submerged Lands Act (43 U.S.C. 1301) and of which the
subsoil and seabed appertain to the United States and are subject to
its jurisdiction and control.
* * * * *
PART 192--[AMENDED]
1. The authority citation for part 192 continues to read as
follows:
Authority: 49 U.S.C. 5103, 60102, 60104, 60108, 60109, 60110,
60113, and 60118; 49 CFR 1.53.
2. Section 192.1 is amended by adding paragraph (b)(5) to read as
follows:
Sec. 192.1 Scope of part.
* * * * *
(b) * * *
(5) On the Outer Continental Shelf upstream of the point at which
operating responsibility transfers from a producing operator to a
transporting operator.
3. Section 192.3 is amended by adding a definition in alphabetical
order to read as follows:
Sec. 192.3 Definitions.
* * * * *
Outer Continental Shelf means all submerged lands lying seaward and
outside the area of lands beneath navigable waters as defined in
Section 2 of the Submerged Lands Act (43 U.S.C. 1301) and of which the
subsoil and seabed appertain to the United States and are subject to
its jurisdiction and control.
* * * * *
4. Section 192.10 is added to read as follows:
Sec. 192.10 Outer continental shelf pipelines.
Operators of transportation pipelines on the Outer Continental
Shelf (as defined in the Outer Continental Shelf Lands Act; 43 U.S.C.
1331) must identify on all their respective pipelines the specific
points at which operating responsibility transfers to a producing
operator. For those instances in which the transfer points are not
identifiable by a durable marking, each operator will have until
September 15, 1998 to identify the transfer points. If it is not
practicable to durably mark a transfer point and the transfer point is
located above water, the operator must depict the transfer point on a
schematic located near the transfer point. If a transfer point is
located subsea, then the operator must identify the transfer point on a
schematic which must be maintained at the nearest upstream facility and
provided to RSPA upon request. For those cases in which adjoining
operators have not agreed on a transfer point by September 15, 1998 the
Regional Director and the MMS Regional Supervisor will make a joint
determination of the transfer point.
PART 195--[AMENDED]
1. The authority citation for part 195 continues to read as
follows:
Authority: 49 U.S.C. 5103, 60102, 60104, 60108, 60109, 60118;
and 49 CFR 1.53.
2. Section 195.1 is amended by adding a new paragraph (b)(6) and
redesignating paragraphs (b)(6) through (b)(8) as paragraphs (b)(7)
through (b)(9) to read as follows:
Sec. 195.1 Applicability.
* * * * *
(b) * * *
(6) Transportation of hazardous liquid or carbon dioxide in Outer
Continental Shelf pipelines which are located upstream of the point at
which operating responsibility transfers from a producing operator to a
transporting operator.
* * * * *
3. Section 195.2 is amended by adding a definition in alphabetical
order to read as follows:
Sec. 195.2 Definitions.
* * * * *
Outer Continental Shelf means all submerged lands lying seaward and
outside the area of lands beneath navigable waters as defined in
Section 2 of the Submerged Lands Act (43 U.S.C. 1301) and of which the
subsoil and seabed appertain to the United States and are subject to
its jurisdiction and control.
* * * * *
4. Section 195.9 is added to read as follows:
Sec. 195.9 Outer continental shelf pipelines.
Operators of transportation pipelines on the Outer Continental
Shelf must identify on all their respective pipelines the specific
points at which operating responsibility transfers to a producing
operator. For those instances in which the transfer points are not
identifiable by a durable marking, each operator will have until
September 15, 1998 to identify the transfer points. If it is not
practicable to durably mark a transfer point and the transfer point is
located above water, the operator must depict the transfer point on a
schematic maintained near the transfer point. If a transfer point is
located subsea, the operator must identify the transfer point on a
schematic which must be maintained at the nearest upstream facility and
provided to RSPA upon request. For those cases in which adjoining
operators have not agreed on a transfer point by September 15, 1998 the
Regional Director and the MMS Regional Supervisor will make a joint
determination of the transfer point.
Issued in Washington D.C. on November 12, 1997.
Richard B. Felder,
Associate Administrator for Pipeline Safety.
[FR Doc. 97-30216 Filed 11-18-97; 8:45 am]
BILLING CODE 4910-60-P
