Annular Casing Pressure Management for Offshore Wells, 23582-23587 [2010-10291]
Download as PDF
<![CDATA[
23582
Federal Register / Vol. 75, No. 85 / Tuesday, May 4, 2010 / Rules and Regulations
Issued in Fort Worth, Texas, on April 23,
2010.
Anthony D. Roetzel,
Manager, Operations Support Group, ATO
Central Service Center.
BILLING CODE 4910–13–P
21, 2010, applicants shall comply with
the net worth requirements set forth in
paragraphs (n)(2)(iii) of this section.’’ is
corrected to read ‘‘Effective on May 20,
2010, applicants shall comply with the
net worth requirements set forth in
paragraph (n)(2)(iii) of this section.’’
DEPARTMENT OF HOUSING AND
URBAN DEVELOPMENT
Dated: April 29, 2010.
Camille E. Acevedo,
Associate General Counsel for Legislation and
Regulations.
[FR Doc. 2010–10325 Filed 5–3–10; 8:45 am]
[FR Doc. 2010–10424 Filed 5–3–10; 8:45 am]
24 CFR Part 202
BILLING CODE 4210–67–P
[Docket No. FR 5356–C–03]
RIN 2502–AI81
DEPARTMENT OF THE INTERIOR
Federal Housing Administration:
Continuation of FHA Reform—
Strengthening Risk Management
Through Responsible FHA-Approved
Lenders; Correction
Minerals Management Service
AGENCY:
WReier-Aviles on DSKGBLS3C1PROD with RULES
Annular Casing Pressure Management
for Offshore Wells
Final rule; correction.
SUMMARY: HUD is correcting a final rule
that appeared in the Federal Register of
April 20, 2010 (75 FR 20718). This final
rule adopted changes pertaining to the
approval of mortgage lenders by the
Federal Housing Administration (FHA)
that are designed to strengthen FHA by
improving its management of risk.
Although the preamble to the final rule
correctly provides that the revised net
worth requirements will take effect for
applicants to the FHA programs on May
20, 2010, the corresponding regulatory
text incorrectly provides that the
requirements will take effect on June 21,
2010. This document makes the
necessary correction.
DATES: Effective Date: May 20, 2010.
FOR FURTHER INFORMATION CONTACT:
Camille E. Acevedo, Associate General
Counsel for Legislation and Regulations,
Office of General Counsel, Department
of Housing and Urban Development,
451 7th Street, SW., Room 10276,
Washington, DC 20410–8000; telephone
number 202–708–1793 (this is not a tollfree number). Persons with hearing or
speech impairments may access this
number through TTY by calling the tollfree Federal Information Relay Service
at 800–877–8339.
SUPPLEMENTARY INFORMATION: In FR Doc.
2010–8837 appearing on page 20718 in
the Federal Register of Tuesday, April
20, 2010, the following correction is
made:
§ 202.5
[Corrected]
1. On page 20733, in the third column,
in § 202.5 General approval standards,
in paragraph (n)(2)(i), ‘‘Effective on June
■
VerDate Mar<15>2010
14:28 May 03, 2010
Jkt 220001
[Docket ID: MMS–2007–OMM–0068]
RIN 1010–AD47
Office of General Counsel,
HUD.
ACTION:
30 CFR Part 250
AGENCY: Minerals Management Service
(MMS), Interior.
ACTION: Final rule.
SUMMARY: This final rule will establish
regulations to address sustained casing
pressure in oil and gas wells completed
in the Outer Continental Shelf.
Sustained casing pressure is a problem
that, if left untreated, could cause
serious harm to human life and the
environment. The final rule will
establish criteria for monitoring and
testing of wells with sustained casing
pressure, and will also incorporate the
American Petroleum Institute’s
Recommended Practice for managing
annular casing pressure. New
regulations are needed because the
current regulations do not adequately
address the requirements for wells that
have sustained casing pressure. This
rule will promote human safety and
environmental protection, and require
Outer Continental Shelf lessees to
follow best industry practices for wells
with sustained casing pressure.
DATES: Effective Date: This rule becomes
effective on June 3, 2010. The
incorporation by reference of the
publication listed in the regulation is
approved by the Director of the Federal
Register as of June 3, 2010.
FOR FURTHER INFORMATION CONTACT: For
comments or questions on procedural
issues, contact Kirk Malstrom, Office of
Offshore Regulatory Programs,
Regulations and Standards Branch, 703–
787–1751. For questions on technical
issues, contact Russell Hoshman,
Technical Assessment and Operations
PO 00000
Frm 00018
Fmt 4700
Sfmt 4700
Support Section, Gulf of Mexico Outer
Continental Shelf Region, 504–736–
2627.
SUPPLEMENTARY INFORMATION: On July
31, 2009, MMS published the proposed
rule Annular Casing Pressure
Management for Offshore Wells (74 FR
38147). The comment period for the
proposed rule was open for 60 days.
During the comment period, MMS
received three comments. Two
comments were in favor of this rule and
the remaining comment was not
associated with this rulemaking.
There are no changes between the
proposed and final rule language. There
are also no changes to the procedural
matters discussion regarding
information collection requirements,
cost estimates, benefits, or impacts to
small entities.
Public Comments: The MMS received
three comments on the proposed rule
1010–AD47 Annular Casing Pressure
Management for Offshore Wells. The
comments received are summarized as
follows:
• British Petroleum (BP)—BP, a large
oil and gas company, expressed the
importance of this rule and how they
have been involved with MMS and
industry to develop the industry
standard.
• Offshore Operators Committee
(OOC)—OOC, a large oil and gas
industry organization, stated their
support of this rulemaking and their
involvement with the industry standard.
• Private citizen—This comment is
not associated with this rulemaking.
The two applicable comments
received on the proposed rule are fully
supportive of this rulemaking.
Background: Sustained casing
pressure (SCP) is pressure between the
casing and the well’s tubing, or between
strings of casing, that rebuilds after
being bled down. The SCP represents an
ongoing safety hazard and can cause
serious or immediate harm or damage to
human life, the marine and coastal
environment, and property. The oil and
gas industry in the Gulf of Mexico
(GOM) has suffered serious accidents as
a result of high SCP, and the lack of
proper control and monitoring of these
pressures. With over 8,000 affected
wells in the GOM with SCP in at least
one annulus, immediate elimination of
all SCP has proved to be impractical and
exceedingly costly. The MMS has
sought to identify and eliminate SCP in
cases that represent a clear hazard to the
safety of personnel or the environment,
and establish a monitoring system for
the rest, all the while working towards
elimination of the problem.
The MMS is currently addressing the
issue of casing pressure in a 1994 Letter
E:\FR\FM\04MYR1.SGM
04MYR1
Federal Register / Vol. 75, No. 85 / Tuesday, May 4, 2010 / Rules and Regulations
to Lessees (LTL) and a 2009 Notice to
Lessees (NTL), 2009 G–22, August 3,
2009. Once the final rulemaking
becomes effective, both the 1994 LTL
and the 2009 NTL on casing pressure
will be rescinded.
Included in this final rule is the
incorporation of a jointly developed
industry standard that addresses
management of casing pressure. The
American Petroleum Institute (API),
industry, and MMS have worked
collectively to produce API
Recommended Practice (RP) 90. As
explained in API RP 90, Section 3,
Annular Casing Pressure Management
Program, this RP is based on
establishing an annular casing pressure
management program that filters out
non-problematic wells that present an
acceptable level of risk, thus allowing
for a more focused effort on wells that
are problematic. The management
program, as outlined in API RP 90,
includes monitoring, diagnostic testing,
determining maximum allowable
wellhead operating pressure (MAWOP)
for each annulus, documentation, and
risk assessment considerations.
For further background information
on this rulemaking, refer to the
published proposed rule 1010–AD47
Annular Casing Pressure Management
for Offshore Wells (74 FR 38147, July
31, 2009).
Procedural Matters
WReier-Aviles on DSKGBLS3C1PROD with RULES
Regulatory Planning and Review
(Executive Order (E.O.) 12866)
This final rule is not a significant rule
as determined by the Office of
Management and Budget (OMB) and is
not subject to review under E.O. 12866.
(1) This final rule will not have an
annual effect of $100 million or more on
the economy. It will not adversely affect
in a material way the economy,
productivity, competition, jobs, the
environment, public health or safety, or
State, local, or tribal governments or
communities. There will be some costs
associated with this rulemaking, mostly
for diagnostic testing, MAWOP
calculations, and reporting to MMS.
Taking into account paperwork burden
requirements, diagnostic testing, and
MAWOP calculations, the costs
associated with this rulemaking will be
approximately $5 million industrywide. The final rule will not require any
new equipment to be installed and
diagnostic testing is currently being
done throughout industry and is not
new.
(2) This final rule will not create a
serious inconsistency or otherwise
interfere with an action taken or
planned by another agency.
VerDate Mar<15>2010
14:28 May 03, 2010
Jkt 220001
(3) This final rule will not alter the
budgetary effects of entitlements, grants,
user fees, or loan programs or the rights
or obligations of their recipients. The
changes in the final rule are strictly
planning requirements for management
of annular casing pressure in offshore
wells.
(4) This final rule will not raise novel
legal or policy issues arising out of legal
mandates, the President’s priorities, or
the principles set forth in E.O. 12866.
Regulatory Flexibility Act
The Department of the Interior
certifies that this final rule will not have
a significant economic effect on a
substantial number of small entities
under the Regulatory Flexibility Act (5
U.S.C. 601 et seq.).
This rulemaking will affect lessees
and operators of leases and pipeline
right-of-way holders in the OCS. This
could include about 130 active Federal
oil and gas lessees. Small entities that
operate under this rule are coded under
the Small Business Administration’s
North American Industry Classification
System (NAICS) codes 211111, Crude
Petroleum and Natural Gas Extraction,
and 213111, Drilling Oil and Gas Wells.
For these NAICS code classifications, a
small company is one with fewer than
500 employees. Based on these criteria,
an estimated 70 percent (91) of these
companies are considered small. This
final rule, therefore, will affect a
substantial number of small entities.
This rule will affect every well in the
OCS, and every operator both large and
small will have the same criteria per
well regardless of company size.
Nonetheless, this rulemaking will not
have a significant economic effect on a
substantial number of small entities
because management of annular casing
pressure will be a moderate cost, mostly
attributable to diagnostic testing. Taking
into account recordkeeping, diagnostic
testing, and MAWOP calculations, the
costs associated with this rulemaking
will be approximately $5 million
industry-wide. In comparison, to
remediate the approximate 8,000 wells
with SCP (approximately $250,000 per
well) would cost approximately $2
billion. The costs that are associated
with this rulemaking will be minor
when compared to SCP remediation
costs and will not impede a company of
any size.
Your comments are important. The
Small Business and Agriculture
Regulatory Enforcement Ombudsman
and 10 Regional Fairness Boards were
established to receive comments from
small businesses about Federal agency
enforcement actions. The Ombudsman
will annually evaluate the enforcement
PO 00000
Frm 00019
Fmt 4700
Sfmt 4700
23583
activities and rate each agency’s
responsiveness to small business. If you
wish to comment on the actions of
MMS, call 1–888–734–3247. You may
comment to the Small Business
Administration without fear of
retaliation. Allegations of
discrimination/retaliation filed with the
Small Business Administration will be
investigated for appropriate action.
Small Business Regulatory Enforcement
Fairness Act
This final rule is not a major rule
under the Small Business Regulatory
Enforcement Fairness Act (5 U.S.C. 801
et seq.). This final rule:
a. Will not have an annual effect on
the economy of $100 million or more.
b. Will not cause a major increase in
costs or prices for consumers,
individual industries, Federal, State, or
local government agencies, or
geographic regions.
c. Will not have significant adverse
effects on competition, employment,
investment, productivity, innovation, or
the ability of U.S.-based enterprises to
compete with foreign-based enterprises.
Unfunded Mandates Reform Act of 1995
This final rule will not impose an
unfunded mandate on State, local, or
tribal governments or the private sector
of more than $100 million per year. The
final rule will not have a significant or
unique effect on State, local, or tribal
governments or the private sector. A
statement containing the information
required by the Unfunded Mandates
Reform Act (2 U.S.C. 1501 et seq.) is not
required.
Takings Implication Assessment (E.O.
12630)
Under the criteria in E.O. 12630, this
final rule does not have significant
takings implications. The final rule is
not a governmental action capable of
interference with constitutionally
protected property rights. A Takings
Implication Assessment is not required.
Federalism (E.O. 13132)
Under the criteria in E.O. 13132, this
final rule does not have federalism
implications. This final rule will not
substantially and directly affect the
relationship between the Federal and
State governments. To the extent that
State and local governments have a role
in OCS activities, this final rule will not
affect that role. A Federalism
Assessment is not required.
Civil Justice Reform (E.O. 12988)
This rule complies with the
requirements of E.O. 12988.
Specifically, this rule:
E:\FR\FM\04MYR1.SGM
04MYR1
23584
Federal Register / Vol. 75, No. 85 / Tuesday, May 4, 2010 / Rules and Regulations
Meets the criteria of section 3(a)
requiring that all regulations be
reviewed to eliminate errors and
ambiguity and be written to minimize
litigation; and
Meets the criteria of section 3(b)(2)
requiring that all regulations be written
in clear language and contain clear legal
standards.
Consultation With Indian Tribes (E.O.
13175)
Under the criteria in E.O. 13175, we
have evaluated this final rule and
determined that it has no substantial
effects on federally recognized Indian
tribes. There are no Indian or tribal
lands in the OCS nor tribally owned
businesses subject to the regulation.
Paperwork Reduction Act (PRA)
The final rule contains no new
reporting or recordkeeping
requirements, and an Office of
Management and Budget (OMB)
submission under the PRA (44 U.S.C.
3501 et seq.) is not required. The PRA
provides that an agency may not
conduct or sponsor a collection of
information unless it displays a
currently valid OMB control number.
Until OMB approves a collection of
information and assigns a control
number, you are not required to
respond. The final regulations will
replace the references to LTLs and NTLs
with specific cites to the Code of
Federal Regulations. The final
rulemaking refers to, but does not
change, information collection
requirements under approved OMB
Control Number 1010–0067 (18,756
hours, expiration 12/31/2010).
National Environmental Policy Act
This rule does not constitute a major
Federal action significantly affecting the
quality of the human environment. A
detailed statement under the National
Environmental Policy Act of 1969 is not
required because we reached a Finding
of No Significant Impact. A copy of the
Environmental Assessment can be
viewed at https://www.Regulations.gov.
(type in ‘‘environmental assessment’’ for
the document type and use the
keyword/ID ‘‘MMS–2007–OMM–0068.’’)
Data Quality Act
In developing this rule, we did not
conduct or use a study, experiment, or
survey requiring peer review under the
Data Quality Act (Pub. L. 106–554, app.
C section 515, 114 Stat. 2763, 2763A–
153–154).
Effects on the Energy Supply (E.O.
13211)
This rule is not a significant energy
action under the definition in E.O.
13211. A Statement of Energy Effects is
not required.
List of Subjects in 30 CFR Part 250
Administrative practice and
procedure, Continental shelf,
Environmental protection, Incorporation
by reference, Oil and gas exploration,
and Reporting and recordkeeping
requirements.
Dated: April 2, 2010.
Ned Farquhar,
Assistant Secretary—Land and Minerals
Management.
For the reasons stated in the preamble,
the Minerals Management Service
(MMS) is amending 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: 31 U.S.C. 9701, 43 U.S.C. 1334.
2. Amend § 250.198 by adding
paragraph (h)(78) to read as follows:
■
§ 250.198 Documents incorporated by
reference.
*
*
*
*
*
(h) * * *
(78) API RP 90, Annular Casing
Pressure Management for Offshore
Wells, First Edition, August 2006,
Product No. G09001, incorporated by
reference at § 250.518.
*
*
*
*
*
■ 3. Revise § 250.517(c) to read as
follows:
§ 250.517
Tubing and wellhead equipment.
*
*
*
*
*
(c) When the tree is installed, you
must equip wells to monitor for casing
pressure according to the following
chart:
If you have * * *
you must equip * * *
so you can monitor * * *
(1) fixed platform wells, ...................
(2) subsea wells, .............................
(3) hybrid* wells, .............................
the wellhead, .................................
the tubing head, .............................
the surface wellhead, ....................
all annuli (A, B, C, D, etc., annuli).
the production casing annulus (A annulus).
all annuli at the surface (A and B riser annuli). If the production casing below the mudline and the production casing riser above the
mudline are pressure isolated from each other, provisions must be
made to monitor the production casing below the mudline for casing pressure.
* Characterized as a well drilled with a subsea wellhead and completed with a surface casing head, a surface tubing head, a surface tubing
hanger, and a surface christmas tree.
*
*
*
*
*
4. Add an undesignated center
heading and new §§ 250.518 through
250.530 to Subpart E—Oil and Gas
Well-Completion Operations to read as
follows:
*
*
*
*
*
WReier-Aviles on DSKGBLS3C1PROD with RULES
■
Casing Pressure Management
Sec.
250.518 What are the requirements for
casing pressure management?
250.519 How often do I have to monitor for
casing pressure?
250.520 When do I have to perform a casing
diagnostic test?
VerDate Mar<15>2010
14:28 May 03, 2010
Jkt 220001
250.521 How do I manage the thermal
effects caused by initial production on a
newly completed or recompleted well?
250.522 When do I have to repeat casing
diagnostic testing?
250.523 How long do I keep records of
casing pressure and diagnostic tests?
250.524 When am I required to take action
from my casing diagnostic test?
250.525 What do I submit if my casing
diagnostic test requires action?
250.526 What must I include in my
notification of corrective action?
250.527 What must I include in my casing
pressure request?
250.528 What are the terms of my casing
pressure request?
PO 00000
Frm 00020
Fmt 4700
Sfmt 4700
250.529 What if my casing pressure request
is denied?
250.530 When does my casing pressure
request become invalid?
§ 250.518 What are the requirements for
casing pressure management?
Once you install your wellhead, you
must meet the casing pressure
management requirements of API RP 90
(incorporated by reference as specified
in § 250.198) and the requirements of
§§ 250.519 through 250.530. If there is a
conflict between API RP 90 and the
casing pressure requirements of this
E:\FR\FM\04MYR1.SGM
04MYR1
Federal Register / Vol. 75, No. 85 / Tuesday, May 4, 2010 / Rules and Regulations
23585
§ 250.519 How often do I have to monitor
for casing pressure?
subpart, you must follow the
requirements of this subpart.
You must monitor for casing pressure
in your well according to the following
table:
If you have * * *
you must monitor * * *
with a minimum one pressure data point recorded per * * *
(a) fixed platform wells, ...................
(b) subsea wells, .............................
(c) hybrid wells, ...............................
(d) wells operating under a casing
pressure request on a manned
fixed platform,
(e) wells operating under a casing
pressure request on an unmanned fixed platform,
monthly, .........................................
continuously, ..................................
continuously, ..................................
daily, ..............................................
month for each casing.
day for the production casing.
day for each riser and/or the production casing.
day for each casing.
weekly, ...........................................
week for each casing.
§ 250.520 When do I have to perform a
casing diagnostic test?
observing or imposing casing pressure
according to the following table:
(a) You must perform a casing
diagnostic test within 30 days after first
If you have a * * *
you must perform a casing diagnostic test if * * *
(1) fixed platform well, ....................
(2) subsea well, ...............................
the casing pressure is greater than 100 psig.
the measurable casing pressure is greater than the external hydrostatic pressure plus 100 psig measured
at the subsea wellhead.
a riser or the production casing pressure is greater than 100 psig measured at the surface.
(3) hybrid well, ................................
(b) You are exempt from performing a
diagnostic pressure test for the
production casing on a well operating
under active gas lift.
§ 250.521 How do I manage the thermal
effects caused by initial production on a
newly completed or recompleted well?
A newly completed or recompleted
well often has thermal casing pressure
during initial startup. Bleeding casing
pressure during the startup process is
considered a normal and necessary
operation to manage thermal casing
pressure; therefore, you do not need to
evaluate these operations as a casing
diagnostic test. After 30 days of
continuous production, the initial
production startup operation is
complete and you must perform casing
diagnostic testing as required in
§§ 250.520 and 250.522.
§ 250.522 When do I have to repeat casing
diagnostic testing?
Casing diagnostic testing must be
repeated according to the following
table:
When * * *
you must repeat diagnostic testing * * *
(a) your casing pressure request approved term has expired, ................
(b) your well, previously on gas lift, has been shut-in or returned to
flowing status without gas lift for more than 180 days,
immediately.
immediately on the production casing (A annulus). The production casing (A annulus) of wells on active gas lift are exempt from diagnostic
testing.
within 30 days.
within 30 days.
WReier-Aviles on DSKGBLS3C1PROD with RULES
(c) your casing pressure request becomes invalid, .................................
(d) a casing or riser has an increase in pressure greater than 200 psig
over the previous casing diagnostic test,
(e) after any corrective action has been taken to remediate undesirable
casing pressure, either as a result of a casing pressure request denial or any other action,
(f) your fixed platform well production casing (A annulus) has pressure
exceeding 10 percent of its minimum internal yield pressure (MIYP),
except for production casings on active gas lift,
(g) your fixed platform well’s outer casing (B, C, D, etc., annuli) has a
pressure exceeding 20 percent of its MIYP,
within 30 days.
once per year, not to exceed 12 months between tests.
once every 5 years, at a minimum.
§ 250.523 How long do I keep records of
casing pressure and diagnostic tests?
at the field office nearest the well until
the well is abandoned.
Records of casing pressure and
diagnostic tests must be kept at the field
office nearest the well for a minimum of
2 years. The last casing diagnostic test
for each casing or riser must be retained
§ 250.524 When am I required to take
action from my casing diagnostic test?
VerDate Mar<15>2010
14:28 May 03, 2010
Jkt 220001
You must take action if you have any
of the following conditions:
PO 00000
Frm 00021
Fmt 4700
Sfmt 4700
(a) Any fixed platform well with a
casing pressure exceeding its maximum
allowable wellhead operating pressure
(MAWOP);
(b) Any fixed platform well with a
casing pressure that is greater than 100
psig and that cannot bleed to 0 psig
E:\FR\FM\04MYR1.SGM
04MYR1
23586
Federal Register / Vol. 75, No. 85 / Tuesday, May 4, 2010 / Rules and Regulations
through a 1⁄2-inch needle valve within
24 hours, or is not bled to 0 psig during
a casing diagnostic test;
(c) Any well that has demonstrated
tubing/casing, tubing/riser, casing/
casing, riser/casing, or riser/riser
communication;
(d) Any well that has sustained casing
pressure (SCP) and is bled down to
prevent it from exceeding its MAWOP,
except during initial startup operations
described in § 250.521;
(e) Any hybrid well with casing or
riser pressure exceeding 100 psig; or
(f) Any subsea well with a casing
pressure 100 psig greater than the
external hydrostatic pressure at the
subsea wellhead.
§ 250.525 What do I submit if my casing
diagnostic test requires action?
Within 14 days after you perform a
casing diagnostic test requiring action
under § 250.524:
You must submit either:
to the appropriate:
and it must include:
You must also:
(a) a notification of corrective action; or,
District Manager and copy the
Regional Supervisor, Field Operations,
requirements under § 250.526 ......
submit an Application for Permit
to Modify or Corrective Action
Plan within 30 days of the diagnostic test.
(b) a casing pressure request, .......
Regional Supervisor, Field Operations,
requirements under § 250.527.
§ 250.526 What must I include in my
notification of corrective action?
The following information must be
included in the notification of corrective
(a) Lessee or Operator name;
(b) Area name and OCS block number;
(c) Well name and API number; and
(d) Casing diagnostic test data.
WReier-Aviles on DSKGBLS3C1PROD with RULES
§ 250.527 What must I include in my
casing pressure request?
The following information must be
included in the casing pressure request:
(a) API number;
(b) Lease number;
(c) Area name and OCS block number;
(d) Well number;
(e) Company name and mailing
address;
(f) All casing, riser, and tubing sizes,
weights, grades, and MIYP;
(g) All casing/riser calculated
MAWOPs;
(h) All casing/riser pre-bleed down
pressures;
(i) Shut-in tubing pressure;
(j) Flowing tubing pressure;
(k) Date and the calculated daily
production rate during last well test (oil,
gas, basic sediment, and water);
(l) Well status (shut-in, temporarily
abandoned, producing, injecting, or gas
lift);
(m) Well type (dry tree, hybrid, or
subsea);
(n) Date of diagnostic test;
(o) Well schematic;
(p) Water depth;
(q) Volumes and types of fluid bled
from each casing or riser evaluated;
(r) Type of diagnostic test performed:
(1) Bleed down/buildup test;
(2) Shut-in the well and monitor the
pressure drop test;
(3) Constant production rate and
decrease the annular pressure test;
(4) Constant production rate and
increase the annular pressure test;
(5) Change the production rate and
monitor the casing pressure test; and
(6) Casing pressure and tubing
pressure history plot;
(s) The casing diagnostic test data for
all casing exceeding 100 psig;
(t) Associated shoe strengths for
casing shoes exposed to annular fluids;
(u) Concentration of any H2S that may
be present;
(v) Whether the structure on which
the well is located is manned or
unmanned;
(w) Additional comments; and
(x) Request date.
§ 250.528 What are the terms of my casing
pressure request?
Casing pressure requests are approved
by the Regional Supervisor, Field
Operations, for a term to be determined
by the Regional Supervisor on a case-bycase basis. The Regional Supervisor may
impose additional restrictions or
requirements to allow continued
operation of the well.
§ 250.529 What if my casing pressure
request is denied?
(a) If your casing pressure request is
denied, then the operating company
must submit plans for corrective action
to the respective District Manager
within 30 days of receiving the denial.
The District Manager will establish a
specific time period in which this
corrective action will be taken. You
must notify the respective District
Manager within 30 days after
completion of your corrected action.
(b) You must submit the casing
diagnostic test data to the appropriate
Regional Supervisor, Field Operations,
within 14 days of completion of the
diagnostic test required under
§ 250.522(e).
§ 250.530 When does my casing pressure
request approval become invalid?
A casing pressure request becomes
invalid when:
(a) The casing or riser pressure
increases by 200 psig over the approved
casing pressure request pressure;
(b) The approved term ends;
(c) The well is worked-over, sidetracked, redrilled, recompleted, or acid
stimulated;
(d) A different casing or riser on the
same well requires a casing pressure
request; or
(e) A well has more than one casing
operating under a casing pressure
request and one of the casing pressure
requests become invalid, then all casing
pressure requests for that well become
invalid.
■ 5. Revise § 250.617(c) to read as
follows:
§ 250.617
Tubing and wellhead equipment.
*
*
*
*
*
(c) When reinstalling the tree, you
must:
(1) Equip wells to monitor for casing
pressure according to the following
chart:
If you have * * *
you must equip * * *
so you can monitor * * *
(i) fixed platform wells, ....................
(ii) subsea wells, .............................
the wellhead, .................................
the tubing head, .............................
all annuli (A, B, C, D, etc., annuli).
the production casing annulus (A annulus).
VerDate Mar<15>2010
14:28 May 03, 2010
Jkt 220001
PO 00000
Frm 00022
Fmt 4700
Sfmt 4700
E:\FR\FM\04MYR1.SGM
04MYR1
Federal Register / Vol. 75, No. 85 / Tuesday, May 4, 2010 / Rules and Regulations
23587
If you have * * *
you must equip * * *
so you can monitor * * *
(iii) hybrid* wells, .............................
the surface wellhead, ....................
all annuli at the surface (A and B riser annuli). If the production casing below the mudline and the production casing riser above the
mudline are pressure isolated from each other, provisions must be
made to monitor the production casing below the mudline for casing pressure.
*Characterized as a well drilled with a subsea wellhead and completed with a surface casing head, a surface tubing head, a surface tubing
hanger, and a surface christmas tree.
(2) Follow the casing pressure
management requirements in subpart E
of this part.
*
*
*
*
*
[FR Doc. 2010–10291 Filed 5–3–10; 8:45 am]
BILLING CODE 4310–MR–P
DEPARTMENT OF HOMELAND
SECURITY
Coast Guard
33 CFR Part 100
[Docket No. USCG–2010–0346]
Annual Seattle Yacht Club’s ‘‘Opening
Day’’ Marine Parade
Coast Guard, DHS.
Notice of enforcement of
regulation.
AGENCY:
WReier-Aviles on DSKGBLS3C1PROD with RULES
ACTION:
SUMMARY: The Coast Guard will enforce
the Special Local Regulation in Portage
Bay, Portage Cut (Montlake Cut), and
Union Bay, WA during the Annual
Seattle Yacht Club’s ‘‘Opening Day’’
Marine Parade from 8 a.m. through 6
p.m. on May 2, 2010. This action is
necessary to ensure participant and
spectator safety while preventing vessel
congestion in these waterways during
the parade. During the enforcement
period, no spectators shall anchor,
block, loiter in, or impede the transit of
participants or official patrol vessels in
the regulated area. Further, due to the
large number of craft confined within
this small body of water, all vessels,
both spectator and participants will
maintain a ‘‘NO WAKE’’ speed.
DATES: The regulations in 33 CFR
100.1304 will be enforced from 8 a.m.
through 6 p.m. on May 2, 2010.
FOR FURTHER INFORMATION CONTACT: If
you have questions on this notice, call
or e-mail Ensign Ashley M. Wanzer,
Sector Seattle Waterways Management
Division, Coast Guard; telephone 206–
217–6175, e-mail
SectorSeattleWWM@uscg.mil.
The Coast
Guard will enforce the Special Local
Regulation for the annual Seattle Yacht
Club’s ‘‘Opening Day’’ Marine Parade in
33 CFR 100.1304 on May 2, 2010, from
SUPPLEMENTARY INFORMATION:
VerDate Mar<15>2010
14:28 May 03, 2010
Jkt 220001
8 a.m. to 6 p.m. These regulations can
be found in the May 4, 1989 issue of the
Federal Register (54 FR 19167).
Under the provisions of 33 CFR
100.1304, the regulated area shall be
closed for the duration of the event to
all vessel traffic not participating in the
event and authorized by the event
sponsor or Coast Guard Patrol
Commander. All persons or vessels not
registered with the sponsor as
participants or not part of the regatta
patrol are considered spectators.
Spectator vessels must be at anchor
within a designated spectator area or
moored to a waterfront facility in a way
that will not interfere with the progress
of the event. The following are
established as spectator areas:
Northwest of the University Bridge,
north of the log boom which will be
placed in Union Bay, and east of
Webster Point.
No spectators shall anchor, block,
loiter in, or impede the through transit
of participants or official patrol vessels
in the regulated area during the effective
dates and times unless cleared for such
entry by the Patrol Commander.
Due to the large number of craft
confined within this small body of
water, all vessels, both spectator and
participants, will maintain a ‘‘NO
WAKE’’ speed. This requirement will be
strictly enforced to preserve the safety of
both life and property.
The Coast Guard may be assisted by
other Federal, State, or local law
enforcement agencies in enforcing this
regulation.
This notice is issued under authority
of 33 CFR 100.1304 and 5 U.S.C. 552(a).
If the Captain of the Port determines
that the regulated area need not be
enforced for the full duration stated in
this notice, she may use a Broadcast
Notice to Mariners to grant general
permission to enter the regulated area.
Dated: April 6, 2010.
Suzanne E. Englebert,
Captain, U.S. Coast Guard, Captain of the
Port, Puget Sound.
[FR Doc. 2010–10310 Filed 4–30–10; 11:15 am]
BILLING CODE 9110–04–P
PO 00000
Frm 00023
Fmt 4700
Sfmt 4700
DEPARTMENT OF HOMELAND
SECURITY
Coast Guard
33 CFR Part 100
[Docket No. USCG–2010–0345]
Seattle Seafair Unlimited Hydroplane
Race
Coast Guard, DHS.
Notice of enforcement of
regulation.
AGENCY:
ACTION:
SUMMARY: The Coast Guard will enforce
the special local regulation supporting
the Seattle Seafair Unlimited
Hydroplane Race on Lake Washington,
WA from 10 a.m. on August 5, 2010
through 6 p.m. on August 8, 2010
during hydroplane race times. This
action is necessary to ensure public
safety from the inherent dangers
associated with high-speed races while
ensuring unencumbered access for
rescue personnel in the event of an
emergency. During the enforcement
period, no person or vessel will be
allowed to enter the safety zone without
the permission of the Captain of the
Port, on-scene Patrol Commander or
Designated Representative.
DATES: The regulations in 33 CFR
100.1301 will be enforced on: August 5,
2010 from 10 a.m. to 3 p.m.; August 6,
2010 from 8:30 a.m. to 6 p.m.; August
7, 2010 from 8:30 a.m. to 6 p.m.; and
August 8, 2010 from 7:30 a.m. to 6 p.m.
FOR FURTHER INFORMATION CONTACT: If
you have questions on this notice, call
or e-mail Ensign Ashley M. Wanzer,
Sector Seattle Waterways Management
Division, Coast Guard; telephone 206–
217–6175, e-mail
SectorSeattleWWM@uscg.mil.
SUPPLEMENTARY INFORMATION: The Coast
Guard will enforce the special local
regulation for the annual Seattle Seafair
Unlimited Hydroplane Race in 33 CFR
100.1301 on August 5, 2010 from 10
a.m. to 3 p.m.; August 6, 2010 from 8:30
a.m. to 6 p.m.; August 7, 2010 from 8:30
a.m. to 6 p.m.; and August 8, 2010 from
7:30 a.m. to 6 p.m.
Under the provisions of 33 CFR
100.1301, the Coast Guard will restrict
general navigation in the following area:
E:\FR\FM\04MYR1.SGM
04MYR1
]]>Agencies
[Federal Register Volume 75, Number 85 (Tuesday, May 4, 2010)]
[Rules and Regulations]
[Pages 23582-23587]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 2010-10291]
=======================================================================
-----------------------------------------------------------------------
DEPARTMENT OF THE INTERIOR
Minerals Management Service
30 CFR Part 250
[Docket ID: MMS-2007-OMM-0068]
RIN 1010-AD47
Annular Casing Pressure Management for Offshore Wells
AGENCY: Minerals Management Service (MMS), Interior.
ACTION: Final rule.
-----------------------------------------------------------------------
SUMMARY: This final rule will establish regulations to address
sustained casing pressure in oil and gas wells completed in the Outer
Continental Shelf. Sustained casing pressure is a problem that, if left
untreated, could cause serious harm to human life and the environment.
The final rule will establish criteria for monitoring and testing of
wells with sustained casing pressure, and will also incorporate the
American Petroleum Institute's Recommended Practice for managing
annular casing pressure. New regulations are needed because the current
regulations do not adequately address the requirements for wells that
have sustained casing pressure. This rule will promote human safety and
environmental protection, and require Outer Continental Shelf lessees
to follow best industry practices for wells with sustained casing
pressure.
DATES: Effective Date: This rule becomes effective on June 3, 2010. The
incorporation by reference of the publication listed in the regulation
is approved by the Director of the Federal Register as of June 3, 2010.
FOR FURTHER INFORMATION CONTACT: For comments or questions on
procedural issues, contact Kirk Malstrom, Office of Offshore Regulatory
Programs, Regulations and Standards Branch, 703-787-1751. For questions
on technical issues, contact Russell Hoshman, Technical Assessment and
Operations Support Section, Gulf of Mexico Outer Continental Shelf
Region, 504-736-2627.
SUPPLEMENTARY INFORMATION: On July 31, 2009, MMS published the proposed
rule Annular Casing Pressure Management for Offshore Wells (74 FR
38147). The comment period for the proposed rule was open for 60 days.
During the comment period, MMS received three comments. Two comments
were in favor of this rule and the remaining comment was not associated
with this rulemaking.
There are no changes between the proposed and final rule language.
There are also no changes to the procedural matters discussion
regarding information collection requirements, cost estimates,
benefits, or impacts to small entities.
Public Comments: The MMS received three comments on the proposed
rule 1010-AD47 Annular Casing Pressure Management for Offshore Wells.
The comments received are summarized as follows:
British Petroleum (BP)--BP, a large oil and gas company,
expressed the importance of this rule and how they have been involved
with MMS and industry to develop the industry standard.
Offshore Operators Committee (OOC)--OOC, a large oil and
gas industry organization, stated their support of this rulemaking and
their involvement with the industry standard.
Private citizen--This comment is not associated with this
rulemaking.
The two applicable comments received on the proposed rule are fully
supportive of this rulemaking.
Background: Sustained casing pressure (SCP) is pressure between the
casing and the well's tubing, or between strings of casing, that
rebuilds after being bled down. The SCP represents an ongoing safety
hazard and can cause serious or immediate harm or damage to human life,
the marine and coastal environment, and property. The oil and gas
industry in the Gulf of Mexico (GOM) has suffered serious accidents as
a result of high SCP, and the lack of proper control and monitoring of
these pressures. With over 8,000 affected wells in the GOM with SCP in
at least one annulus, immediate elimination of all SCP has proved to be
impractical and exceedingly costly. The MMS has sought to identify and
eliminate SCP in cases that represent a clear hazard to the safety of
personnel or the environment, and establish a monitoring system for the
rest, all the while working towards elimination of the problem.
The MMS is currently addressing the issue of casing pressure in a
1994 Letter
[[Page 23583]]
to Lessees (LTL) and a 2009 Notice to Lessees (NTL), 2009 G-22, August
3, 2009. Once the final rulemaking becomes effective, both the 1994 LTL
and the 2009 NTL on casing pressure will be rescinded.
Included in this final rule is the incorporation of a jointly
developed industry standard that addresses management of casing
pressure. The American Petroleum Institute (API), industry, and MMS
have worked collectively to produce API Recommended Practice (RP) 90.
As explained in API RP 90, Section 3, Annular Casing Pressure
Management Program, this RP is based on establishing an annular casing
pressure management program that filters out non-problematic wells that
present an acceptable level of risk, thus allowing for a more focused
effort on wells that are problematic. The management program, as
outlined in API RP 90, includes monitoring, diagnostic testing,
determining maximum allowable wellhead operating pressure (MAWOP) for
each annulus, documentation, and risk assessment considerations.
For further background information on this rulemaking, refer to the
published proposed rule 1010-AD47 Annular Casing Pressure Management
for Offshore Wells (74 FR 38147, July 31, 2009).
Procedural Matters
Regulatory Planning and Review (Executive Order (E.O.) 12866)
This final rule is not a significant rule as determined by the
Office of Management and Budget (OMB) and is not subject to review
under E.O. 12866.
(1) This final rule will not have an annual effect of $100 million
or more on the economy. It will not adversely affect in a material way
the economy, productivity, competition, jobs, the environment, public
health or safety, or State, local, or tribal governments or
communities. There will be some costs associated with this rulemaking,
mostly for diagnostic testing, MAWOP calculations, and reporting to
MMS. Taking into account paperwork burden requirements, diagnostic
testing, and MAWOP calculations, the costs associated with this
rulemaking will be approximately $5 million industry-wide. The final
rule will not require any new equipment to be installed and diagnostic
testing is currently being done throughout industry and is not new.
(2) This final rule will not create a serious inconsistency or
otherwise interfere with an action taken or planned by another agency.
(3) This final rule will not alter the budgetary effects of
entitlements, grants, user fees, or loan programs or the rights or
obligations of their recipients. The changes in the final rule are
strictly planning requirements for management of annular casing
pressure in offshore wells.
(4) This final rule will not raise novel legal or policy issues
arising out of legal mandates, the President's priorities, or the
principles set forth in E.O. 12866.
Regulatory Flexibility Act
The Department of the Interior certifies that this final rule will
not have a significant economic effect on a substantial number of small
entities under the Regulatory Flexibility Act (5 U.S.C. 601 et seq.).
This rulemaking will affect lessees and operators of leases and
pipeline right-of-way holders in the OCS. This could include about 130
active Federal oil and gas lessees. Small entities that operate under
this rule are coded under the Small Business Administration's North
American Industry Classification System (NAICS) codes 211111, Crude
Petroleum and Natural Gas Extraction, and 213111, Drilling Oil and Gas
Wells. For these NAICS code classifications, a small company is one
with fewer than 500 employees. Based on these criteria, an estimated 70
percent (91) of these companies are considered small. This final rule,
therefore, will affect a substantial number of small entities. This
rule will affect every well in the OCS, and every operator both large
and small will have the same criteria per well regardless of company
size.
Nonetheless, this rulemaking will not have a significant economic
effect on a substantial number of small entities because management of
annular casing pressure will be a moderate cost, mostly attributable to
diagnostic testing. Taking into account recordkeeping, diagnostic
testing, and MAWOP calculations, the costs associated with this
rulemaking will be approximately $5 million industry-wide. In
comparison, to remediate the approximate 8,000 wells with SCP
(approximately $250,000 per well) would cost approximately $2 billion.
The costs that are associated with this rulemaking will be minor when
compared to SCP remediation costs and will not impede a company of any
size.
Your comments are important. The Small Business and Agriculture
Regulatory Enforcement Ombudsman and 10 Regional Fairness Boards were
established to receive comments from small businesses 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 actions of MMS, call 1-888-734-
3247. You may comment to the Small Business Administration without fear
of retaliation. Allegations of discrimination/retaliation filed with
the Small Business Administration will be investigated for appropriate
action.
Small Business Regulatory Enforcement Fairness Act
This final rule is not a major rule under the Small Business
Regulatory Enforcement Fairness Act (5 U.S.C. 801 et seq.). This final
rule:
a. Will not have an annual effect on the economy of $100 million or
more.
b. Will not cause a major increase in costs or prices for
consumers, individual industries, Federal, State, or local government
agencies, or geographic regions.
c. Will not have significant adverse effects on competition,
employment, investment, productivity, innovation, or the ability of
U.S.-based enterprises to compete with foreign-based enterprises.
Unfunded Mandates Reform Act of 1995
This final rule will not impose an unfunded mandate on State,
local, or tribal governments or the private sector of more than $100
million per year. The final rule will not have a significant or unique
effect on State, local, or tribal governments or the private sector. A
statement containing the information required by the Unfunded Mandates
Reform Act (2 U.S.C. 1501 et seq.) is not required.
Takings Implication Assessment (E.O. 12630)
Under the criteria in E.O. 12630, this final rule does not have
significant takings implications. The final rule is not a governmental
action capable of interference with constitutionally protected property
rights. A Takings Implication Assessment is not required.
Federalism (E.O. 13132)
Under the criteria in E.O. 13132, this final rule does not have
federalism implications. This final rule will not substantially and
directly affect the relationship between the Federal and State
governments. To the extent that State and local governments have a role
in OCS activities, this final rule will not affect that role. A
Federalism Assessment is not required.
Civil Justice Reform (E.O. 12988)
This rule complies with the requirements of E.O. 12988.
Specifically, this rule:
[[Page 23584]]
Meets the criteria of section 3(a) requiring that all regulations
be reviewed to eliminate errors and ambiguity and be written to
minimize litigation; and
Meets the criteria of section 3(b)(2) requiring that all
regulations be written in clear language and contain clear legal
standards.
Consultation With Indian Tribes (E.O. 13175)
Under the criteria in E.O. 13175, we have evaluated this final rule
and determined that it has no substantial effects on federally
recognized Indian tribes. There are no Indian or tribal lands in the
OCS nor tribally owned businesses subject to the regulation.
Paperwork Reduction Act (PRA)
The final rule contains no new reporting or recordkeeping
requirements, and an Office of Management and Budget (OMB) submission
under the PRA (44 U.S.C. 3501 et seq.) is not required. The PRA
provides that an agency may not conduct or sponsor a collection of
information unless it displays a currently valid OMB control number.
Until OMB approves a collection of information and assigns a control
number, you are not required to respond. The final regulations will
replace the references to LTLs and NTLs with specific cites to the Code
of Federal Regulations. The final rulemaking refers to, but does not
change, information collection requirements under approved OMB Control
Number 1010-0067 (18,756 hours, expiration 12/31/2010).
National Environmental Policy Act
This rule does not constitute a major Federal action significantly
affecting the quality of the human environment. A detailed statement
under the National Environmental Policy Act of 1969 is not required
because we reached a Finding of No Significant Impact. A copy of the
Environmental Assessment can be viewed at https://www.Regulations.gov.
(type in ``environmental assessment'' for the document type and use the
keyword/ID ``MMS-2007-OMM-0068.'')
Data Quality Act
In developing this rule, we did not conduct or use a study,
experiment, or survey requiring peer review under the Data Quality Act
(Pub. L. 106-554, app. C section 515, 114 Stat. 2763, 2763A-153-154).
Effects on the Energy Supply (E.O. 13211)
This rule is not a significant energy action under the definition
in E.O. 13211. A Statement of Energy Effects is not required.
List of Subjects in 30 CFR Part 250
Administrative practice and procedure, Continental shelf,
Environmental protection, Incorporation by reference, Oil and gas
exploration, and Reporting and recordkeeping requirements.
Dated: April 2, 2010.
Ned Farquhar,
Assistant Secretary--Land and Minerals Management.
0
For the reasons stated in the preamble, the Minerals Management Service
(MMS) is amending 30 CFR part 250 as follows:
PART 250--OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER
CONTINENTAL SHELF
0
1. The authority citation for part 250 continues to read as follows:
Authority: 31 U.S.C. 9701, 43 U.S.C. 1334.
0
2. Amend Sec. 250.198 by adding paragraph (h)(78) to read as follows:
Sec. 250.198 Documents incorporated by reference.
* * * * *
(h) * * *
(78) API RP 90, Annular Casing Pressure Management for Offshore
Wells, First Edition, August 2006, Product No. G09001, incorporated by
reference at Sec. 250.518.
* * * * *
0
3. Revise Sec. 250.517(c) to read as follows:
Sec. 250.517 Tubing and wellhead equipment.
* * * * *
(c) When the tree is installed, you must equip wells to monitor for
casing pressure according to the following chart:
------------------------------------------------------------------------
you must equip * so you can monitor *
If you have * * * * * * *
------------------------------------------------------------------------
(1) fixed platform wells,..... the wellhead,.... all annuli (A, B, C,
D, etc., annuli).
(2) subsea wells,............. the tubing head,. the production casing
annulus (A annulus).
(3) hybrid* wells,............ the surface all annuli at the
wellhead,. surface (A and B
riser annuli). If
the production
casing below the
mudline and the
production casing
riser above the
mudline are pressure
isolated from each
other, provisions
must be made to
monitor the
production casing
below the mudline
for casing pressure.
------------------------------------------------------------------------
* Characterized as a well drilled with a subsea wellhead and completed
with a surface casing head, a surface tubing head, a surface tubing
hanger, and a surface christmas tree.
* * * * *
0
4. Add an undesignated center heading and new Sec. Sec. 250.518
through 250.530 to Subpart E--Oil and Gas Well-Completion Operations to
read as follows:
* * * * *
Casing Pressure Management
Sec.
250.518 What are the requirements for casing pressure management?
250.519 How often do I have to monitor for casing pressure?
250.520 When do I have to perform a casing diagnostic test?
250.521 How do I manage the thermal effects caused by initial
production on a newly completed or recompleted well?
250.522 When do I have to repeat casing diagnostic testing?
250.523 How long do I keep records of casing pressure and diagnostic
tests?
250.524 When am I required to take action from my casing diagnostic
test?
250.525 What do I submit if my casing diagnostic test requires
action?
250.526 What must I include in my notification of corrective action?
250.527 What must I include in my casing pressure request?
250.528 What are the terms of my casing pressure request?
250.529 What if my casing pressure request is denied?
250.530 When does my casing pressure request become invalid?
Sec. 250.518 What are the requirements for casing pressure
management?
Once you install your wellhead, you must meet the casing pressure
management requirements of API RP 90 (incorporated by reference as
specified in Sec. 250.198) and the requirements of Sec. Sec. 250.519
through 250.530. If there is a conflict between API RP 90 and the
casing pressure requirements of this
[[Page 23585]]
subpart, you must follow the requirements of this subpart.
Sec. 250.519 How often do I have to monitor for casing pressure?
You must monitor for casing pressure in your well according to the
following table:
------------------------------------------------------------------------
with a minimum one
If you have * * * you must monitor pressure data point
* * * recorded per * * *
------------------------------------------------------------------------
(a) fixed platform wells,..... monthly,......... month for each
casing.
(b) subsea wells,............. continuously,.... day for the
production casing.
(c) hybrid wells,............. continuously,.... day for each riser
and/or the
production casing.
(d) wells operating under a daily,........... day for each casing.
casing pressure request on a
manned fixed platform,
(e) wells operating under a weekly,.......... week for each casing.
casing pressure request on an
unmanned fixed platform,
------------------------------------------------------------------------
Sec. 250.520 When do I have to perform a casing diagnostic test?
(a) You must perform a casing diagnostic test within 30 days after
first observing or imposing casing pressure according to the following
table:
------------------------------------------------------------------------
you must perform a casing diagnostic
If you have a * * * test if * * *
------------------------------------------------------------------------
(1) fixed platform well,.......... the casing pressure is greater than
100 psig.
(2) subsea well,.................. the measurable casing pressure is
greater than the external
hydrostatic pressure plus 100 psig
measured at the subsea wellhead.
(3) hybrid well,.................. a riser or the production casing
pressure is greater than 100 psig
measured at the surface.
------------------------------------------------------------------------
(b) You are exempt from performing a diagnostic pressure test for
the production casing on a well operating under active gas lift.
Sec. 250.521 How do I manage the thermal effects caused by initial
production on a newly completed or recompleted well?
A newly completed or recompleted well often has thermal casing
pressure during initial startup. Bleeding casing pressure during the
startup process is considered a normal and necessary operation to
manage thermal casing pressure; therefore, you do not need to evaluate
these operations as a casing diagnostic test. After 30 days of
continuous production, the initial production startup operation is
complete and you must perform casing diagnostic testing as required in
Sec. Sec. 250.520 and 250.522.
Sec. 250.522 When do I have to repeat casing diagnostic testing?
Casing diagnostic testing must be repeated according to the
following table:
------------------------------------------------------------------------
you must repeat diagnostic
When * * * testing * * *
------------------------------------------------------------------------
(a) your casing pressure request immediately.
approved term has expired,.
(b) your well, previously on gas lift, immediately on the production
has been shut-in or returned to casing (A annulus). The
flowing status without gas lift for production casing (A annulus)
more than 180 days, of wells on active gas lift
are exempt from diagnostic
testing.
(c) your casing pressure request within 30 days.
becomes invalid,.
(d) a casing or riser has an increase within 30 days.
in pressure greater than 200 psig over
the previous casing diagnostic test,
(e) after any corrective action has within 30 days.
been taken to remediate undesirable
casing pressure, either as a result of
a casing pressure request denial or
any other action,
(f) your fixed platform well production once per year, not to exceed 12
casing (A annulus) has pressure months between tests.
exceeding 10 percent of its minimum
internal yield pressure (MIYP), except
for production casings on active gas
lift,
(g) your fixed platform well's outer once every 5 years, at a
casing (B, C, D, etc., annuli) has a minimum.
pressure exceeding 20 percent of its
MIYP,
------------------------------------------------------------------------
Sec. 250.523 How long do I keep records of casing pressure and
diagnostic tests?
Records of casing pressure and diagnostic tests must be kept at the
field office nearest the well for a minimum of 2 years. The last casing
diagnostic test for each casing or riser must be retained at the field
office nearest the well until the well is abandoned.
Sec. 250.524 When am I required to take action from my casing
diagnostic test?
You must take action if you have any of the following conditions:
(a) Any fixed platform well with a casing pressure exceeding its
maximum allowable wellhead operating pressure (MAWOP);
(b) Any fixed platform well with a casing pressure that is greater
than 100 psig and that cannot bleed to 0 psig
[[Page 23586]]
through a \1/2\-inch needle valve within 24 hours, or is not bled to 0
psig during a casing diagnostic test;
(c) Any well that has demonstrated tubing/casing, tubing/riser,
casing/casing, riser/casing, or riser/riser communication;
(d) Any well that has sustained casing pressure (SCP) and is bled
down to prevent it from exceeding its MAWOP, except during initial
startup operations described in Sec. 250.521;
(e) Any hybrid well with casing or riser pressure exceeding 100
psig; or
(f) Any subsea well with a casing pressure 100 psig greater than
the external hydrostatic pressure at the subsea wellhead.
Sec. 250.525 What do I submit if my casing diagnostic test requires
action?
Within 14 days after you perform a casing diagnostic test requiring
action under Sec. 250.524:
----------------------------------------------------------------------------------------------------------------
You must submit either: to the appropriate: and it must include: You must also:
----------------------------------------------------------------------------------------------------------------
(a) a notification of corrective District Manager and requirements under Sec. submit an Application
action; or, copy the Regional 250.526. for Permit to Modify
Supervisor, Field or Corrective Action
Operations, Plan within 30 days of
the diagnostic test.
(b) a casing pressure request,....... Regional Supervisor, requirements under Sec.
Field Operations, 250.527.
----------------------------------------------------------------------------------------------------------------
Sec. 250.526 What must I include in my notification of corrective
action?
The following information must be included in the notification of
corrective
(a) Lessee or Operator name;
(b) Area name and OCS block number;
(c) Well name and API number; and
(d) Casing diagnostic test data.
Sec. 250.527 What must I include in my casing pressure request?
The following information must be included in the casing pressure
request:
(a) API number;
(b) Lease number;
(c) Area name and OCS block number;
(d) Well number;
(e) Company name and mailing address;
(f) All casing, riser, and tubing sizes, weights, grades, and MIYP;
(g) All casing/riser calculated MAWOPs;
(h) All casing/riser pre-bleed down pressures;
(i) Shut-in tubing pressure;
(j) Flowing tubing pressure;
(k) Date and the calculated daily production rate during last well
test (oil, gas, basic sediment, and water);
(l) Well status (shut-in, temporarily abandoned, producing,
injecting, or gas lift);
(m) Well type (dry tree, hybrid, or subsea);
(n) Date of diagnostic test;
(o) Well schematic;
(p) Water depth;
(q) Volumes and types of fluid bled from each casing or riser
evaluated;
(r) Type of diagnostic test performed:
(1) Bleed down/buildup test;
(2) Shut-in the well and monitor the pressure drop test;
(3) Constant production rate and decrease the annular pressure
test;
(4) Constant production rate and increase the annular pressure
test;
(5) Change the production rate and monitor the casing pressure
test; and
(6) Casing pressure and tubing pressure history plot;
(s) The casing diagnostic test data for all casing exceeding 100
psig;
(t) Associated shoe strengths for casing shoes exposed to annular
fluids;
(u) Concentration of any H2S that may be present;
(v) Whether the structure on which the well is located is manned or
unmanned;
(w) Additional comments; and
(x) Request date.
Sec. 250.528 What are the terms of my casing pressure request?
Casing pressure requests are approved by the Regional Supervisor,
Field Operations, for a term to be determined by the Regional
Supervisor on a case-by-case basis. The Regional Supervisor may impose
additional restrictions or requirements to allow continued operation of
the well.
Sec. 250.529 What if my casing pressure request is denied?
(a) If your casing pressure request is denied, then the operating
company must submit plans for corrective action to the respective
District Manager within 30 days of receiving the denial. The District
Manager will establish a specific time period in which this corrective
action will be taken. You must notify the respective District Manager
within 30 days after completion of your corrected action.
(b) You must submit the casing diagnostic test data to the
appropriate Regional Supervisor, Field Operations, within 14 days of
completion of the diagnostic test required under Sec. 250.522(e).
Sec. 250.530 When does my casing pressure request approval become
invalid?
A casing pressure request becomes invalid when:
(a) The casing or riser pressure increases by 200 psig over the
approved casing pressure request pressure;
(b) The approved term ends;
(c) The well is worked-over, side-tracked, redrilled, recompleted,
or acid stimulated;
(d) A different casing or riser on the same well requires a casing
pressure request; or
(e) A well has more than one casing operating under a casing
pressure request and one of the casing pressure requests become
invalid, then all casing pressure requests for that well become
invalid.
0
5. Revise Sec. 250.617(c) to read as follows:
Sec. 250.617 Tubing and wellhead equipment.
* * * * *
(c) When reinstalling the tree, you must:
(1) Equip wells to monitor for casing pressure according to the
following chart:
------------------------------------------------------------------------
you must equip * so you can monitor *
If you have * * * * * * *
------------------------------------------------------------------------
(i) fixed platform wells,..... the wellhead,.... all annuli (A, B, C,
D, etc., annuli).
(ii) subsea wells,............ the tubing head,. the production casing
annulus (A annulus).
[[Page 23587]]
(iii) hybrid* wells,.......... the surface all annuli at the
wellhead,. surface (A and B
riser annuli). If
the production
casing below the
mudline and the
production casing
riser above the
mudline are pressure
isolated from each
other, provisions
must be made to
monitor the
production casing
below the mudline
for casing pressure.
------------------------------------------------------------------------
*Characterized as a well drilled with a subsea wellhead and completed
with a surface casing head, a surface tubing head, a surface tubing
hanger, and a surface christmas tree.
(2) Follow the casing pressure management requirements in subpart E
of this part.
* * * * *
[FR Doc. 2010-10291 Filed 5-3-10; 8:45 am]
BILLING CODE 4310-MR-P
