Annular Casing Pressure Management for Offshore Wells, 38147-38153 [E9-17874]

Agencies

• DEPARTMENT OF THE INTERIOR
• Minerals Management Service

[Federal Register Volume 74, Number 146 (Friday, July 31, 2009)]
[Proposed Rules]
[Pages 38147-38153]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: E9-17874]


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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: Proposed rule.

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SUMMARY: This proposed rule would establish regulations to address 
sustained casing pressure in oil and gas wells completed on the Outer 
Continental Shelf. Sustained casing pressure is a problem that, if left 
untreated, could cause serious harm to human life or the environment. 
The proposed rule would establish criteria for monitoring and testing 
of wells with sustained casing pressure, and would 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 requirements for wells that have 
sustained casing pressure. This rule would promote human safety and 
environmental protection, and require Outer Continental Shelf lessees 
to follow best industry practices for wells with sustained casing 
pressure.

DATES: Submit comments by September 29, 2009. The MMS may not fully 
consider comments received after this date. Submit comments to the 
Office of Management and Budget on the information collection burden in 
this proposed rule by August 31, 2009. This does not affect the 
deadline for the public to comment to MMS on the proposed regulations.

ADDRESSES: You may submit comments on the rulemaking by any of the 
following methods. Please use the Regulation Identifier Number (RIN) 
1010-AD47 as an identifier in your message. See also Public 
Availability of Comments under Procedural Matters.
     Federal eRulemaking Portal: https://www.regulations.gov. 
Under the tab ``More Search Options,'' click ``Advanced Docket 
Search,'' then select ``Minerals Management Service'' from the agency 
drop-down menu, then click submit. In the Docket ID column, select MMS-
2007-OMM-0068 to submit public comments and to view supporting and 
related materials available for this rulemaking. Information on using 
Regulations.gov, including instructions for accessing documents, 
submitting comments, and viewing the docket after the close of the 
comment period, is available through the site's ``User Tips'' link. The 
MMS will post all comments.
     Mail or hand-carry comments to the Department of the 
Interior; Minerals Management Service; Attention: Regulations and 
Standards Branch (RSB); 381 Elden Street, MS-4024, Herndon, Virginia 
20170-4817. Please reference Annular Casing Pressure Management for 
Offshore Wells, 1010-AD47 in your comments and include your name and 
return address.
     Send comments on the information collection in this rule 
to: Interior Desk Officer 1010-AD47, Office of Management and Budget; 
202-395-5806 (fax); e-mail: oira_docket@omb.eop.gov. Please also send 
a copy to MMS.

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:
    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. Data gathered by MMS

[[Page 38148]]

have shown that SCP is most often caused by leaks in the production 
tubing and tubing connectors. It is also caused by poorly cemented 
casing, channeling in the cemented annulus, and leaks in seals or other 
equipment. If left uncontrolled, this 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. During the period 
from 1980 to 1990, the oil and gas industry in the Gulf of Mexico (GOM) 
suffered four serious accidents as a result of high SCP, and the lack 
of proper control and monitoring of these pressures. In response, MMS 
developed a policy for the GOM Outer Continental Shelf (OCS) under 
which lessees could effectively monitor the SCP of wells in an attempt 
to prevent future accidents.
    As far back as 1977, OCS Order No. 6, Completion of Oil and Gas 
Wells, required the testing and repair of all wells that exhibit SCP. 
The current regulation at 30-CFR-250.517 addresses tubing and wellhead 
equipment. Paragraph (a) of Sec.  250.517 requires that tubing strings 
must maintain pressure integrity. Paragraph (c) requires that wellheads 
be equipped to monitor SCP in all casing annuli, and stipulates that 
the lessee must notify the District Manager if SCP is observed. The 
primary intent of this regulation, with respect to SCP, is to achieve 
and maintain pressure control of wells. Since that regulation was 
issued in 1988, MMS has interpreted Sec.  250.517(c) to mean that no 
SCP is to be maintained on any annulus of an OCS well. With over 8,000 
affected wells in the GOM with SCP in at least one annuli, 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's SCP policy was then further revised with the issuance of 
the 1991 and 1994 Letters to Lessees (LTLs). These documents provided 
further clarification regarding wells with SCP, reporting procedures, 
time retention of field records, and departure procedures. Using the 
procedures of these LTLs, departures from the requirement for no SCP 
were requested and approved under Sec.  250.142. Since the 1994 LTL was 
issued, MMS has identified areas of concern with the existing 
reporting, testing, and monitoring procedures. Once the final 
rulemaking becomes effective, the 1994 LTL will be rescinded.
    On November 9, 2001, MMS published a notice of proposed rulemaking 
(66 FR 56620) to add SCP requirements to 30 CFR part 250, subpart E. 
Various industry representatives commented and had concerns about the 
2001 notice of proposed rulemaking. Industry proposed a research 
project to study and develop guidance for annular casing pressure and 
MMS agreed. In August 2006, industry completed the first step in 
managing annular casing pressure by publishing the American Petroleum 
Institute's Recommended Practice 90, Annular Casing Pressure Management 
for Offshore Wells (API RP 90). The API RP 90 largely utlilizes 
monitoring, diagnostic testing, and documentation to establish an 
annular casing pressure management program. The next step for industry 
would be to develop API RP 65-3, which identifies practices to prevent 
or remediate casing pressure in existing wells.
    The API, industry, and MMS have worked collectively to produce API 
RP 90. As explained in section three of API RP 90, this RP is based on 
establishing an annular casing pressure management program that filters 
out nonproblematic 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.
    The cooperative efforts of both industry and MMS have shown the 
importance and need to manage annular casing pressure. This proposed 
rulemaking would clarify the intended policy and procedures, and 
incorporate API RP 90 into MMS regulations. Along with the 
incorporation of API RP 90, new sections would be added to subparts E 
and F. The new sections proposed to be added in subpart E include 
additional requirements and clarifications beyond that of API RP 90. 
The MMS believes the level of risk in some particulars of API RP 90 
needs to be clarified and enhanced; therefore additional requirements 
are explained in more detail in applicable sections. The following 
contains a brief section by section review of the proposed 
requirements:

Tubing and Wellhead Equipment (Sec.  250.517)

    In this section, only paragraph (c) would be changed. A chart would 
be added to clarify the requirements of the different well types for 
casing pressure monitoring. The current regulation does not apply to 
subsea and hybrid wells.

What are the requirements for casing pressure management? (Sec.  
250.518)

    This section states that MMS would require you to follow API RP 90 
and the proposed requirements in Sec. Sec.  250.519 through 250.530. It 
also emphasizes that if there is a conflict between API RP 90 and 
Sec. Sec.  250.519 through 250.530, you must adhere to the latter.

How often do I have to monitor for casing pressure? (Sec.  250.519)

    With many different well types in the OCS, a table would be added 
to clarify when you must monitor each type of well and how often you 
must record your pressure data.

When do I have to perform a casing diagnostic test? (Sec.  250.520)

    This section states that a casing diagnostic test would be required 
only if you experience casing pressure under the criteria listed for 
each well type. There is an exemption to the requirements of this 
section. You are exempt from performing a diagnostic pressure test for 
the production casing on a well operating under active gas lift.

How do I manage the thermal effects caused by initial production on a 
newly completed or recompleted well? (Sec.  250.521)

    A newly completed or recompleted well often has thermal casing 
pressure during initial startup. Bleeding casing pressure and casing 
fluids during the startup process is considered a normal and necessary 
operation to manage casing pressure; therefore, you do not need to 
evaluate these operations as casing diagnostic tests. However, after 
you complete startup operations, and if you observe casing pressure, 
then the provisions of this section apply.

When do I have to repeat casing diagnostic testing? (Sec.  250.522)

    This section explains the various instances in which you would have 
to repeat casing diagnostic testing. Most repeat tests are attributed 
to timing, pressure, or corrective action.

How long do I keep records of casing pressure and diagnostic tests? 
(Sec.  250.523)

    This section explains how long you would have to keep pressure test 
data in the field office closest to your well. This is so your 
personnel may access the data, and that such data would be available 
for MMS inspection. Requiring the last diagnostic test be kept at the 
nearest field office until the well is

[[Page 38149]]

abandoned helps assure that the abandonment design properly addresses 
casing pressure issues.

When am I required to take action from my casing diagnostic test? 
(Sec.  250.524)

    This section clarifies when action is required based on the results 
of the diagnostic test. By focusing on specific pressure requirements, 
this section will assist lessees and operators in determining when they 
need to take action regarding casing pressure, and limit the number of 
casing pressure requests. Once the rulemaking becomes effective, NTL 
2005 G-09 would be rescinded. Under paragraph (d), you must submit a 
casing pressure request if a well that has increasing casing pressure 
is bled down to prevent it from exceeding its MAWOP, except during 
initial startup operations. A newly completed or recompleted well often 
has thermal casing pressure during initial startup. Bleeding casing 
pressure and casing fluids during the startup process is considered a 
normal and necessary operation to manage casing pressure.

What do I submit if my casing diagnostic test requires action? (Sec.  
250.525)

    This section shows when and where you must submit a notification of 
corrective action or casing pressure request. The new casing pressure 
request is equivalent to the old departure requests, in that under 
certain casing pressure conditions, you still need MMS approval to 
continue operations. In lieu of a casing pressure request, a corrective 
action notice can be submitted if you recognize that you have a well 
with annular casing pressure that requires corrective action. The MMS 
added the corrective action request to allow operators the ability to 
begin corrective action without having to go through the process of the 
casing pressure request and denial before they can begin corrective 
actions. By circumventing the casing pressure request, both MMS and 
industry can focus efforts on the necessary corrective actions. 
Submittals are to be sent to the appropriate locations to help MMS 
processing.

What must I include in my notification of corrective action? (Sec.  
250.526)

    This section would clarify the required contents of a notification 
of corrective action. Once you send in your corrective action notice, 
you are required, within 30 days of the diagnostic test requiring 
action, to submit the appropriate Application for Permit to Modify, 
corrective action plan, and other requirements.

What must I include in my casing pressure request? (Sec.  250.527)

    This section would clarify the required contents of a casing 
pressure request. The information contained in a casing pressure 
request helps MMS facilitate the review and approval process.

What are the terms of my casing pressure request? (Sec.  250.528)

    This section explains that the Regional Supervisor, Field 
Operations would set the term of the request and could also impose 
additional requirements or restrictions to allow continued operations 
of the well.

What if my casing pressure request is denied? (Sec.  250.529)

    If your casing pressure request is denied, this section explains 
that a corrective action plan is required within 30-days of the request 
denial. The corrective action is sent to the District Manager because 
the district office is in charge of approving well operations and 
workovers. After the corrective action is complete and you perform the 
required casing diagnostic tests, you must also send the casing 
diagnostic test data to the Regional Supervisor, Field Operations. The 
Regional Supervisor, Field Operations uses the data to review and bring 
closure to the appropriate casing pressure issue.

When does my casing pressure request become invalid? (Sec.  250.530)

    This section explains when your casing pressure request is no 
longer valid. Most casing pressure requests become invalid due to 
timing, pressure issues, or corrective actions.

Tubing and Wellhead Equipment (Sec.  250.617)

    In this section, only paragraph (c) would be changed. A chart would 
be added to clarify the requirements of the different well types for 
casing pressure monitoring. The current regulation does not apply to 
subsea and hybrid wells.

Procedural Matters

Regulatory Planning and Review (Executive Order (E.O.) 12866)

    This proposed 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 proposed rule would not have an annual effect of $100 
million or more on the economy. It would 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 would be some costs associated with 
this rulemaking, mostly due to 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 would be approximately $5 million 
industry-wide. The proposed rule would not require any new equipment to 
be installed, and diagnostic testing is currently being done throughout 
industry and is not new.
    (2) This proposed rule would not create a serious inconsistency or 
otherwise interfere with an action taken or planned by another agency.
    (3) This proposed rule would 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 proposed rule are 
strictly planning requirements for management of annular casing 
pressure in offshore wells.
    (4) This proposed rule would 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 proposed rule 
would 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.).
    The changes proposed in the rule would 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 fall under the Small Business 
Administration's (SBA) 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 proposed rule, therefore, would 
affect a substantial number of small entities. This rule would affect 
every well on the OCS, and every operator both large and small would 
have the same criteria per well regardless of company size.
    Nonetheless, the changes proposed in the rule would not have a 
significant economic effect on a substantial number of small entities 
because management of annular casing pressure would be a

[[Page 38150]]

moderate cost, mostly attributed to diagnostic testing. Taking into 
account recordkeeping, diagnostic testing, and MAWOP calculations, the 
costs associated with this rulemaking would be approximately $5 million 
industry-wide. In comparison, to remediate the approximate 8,000 wells 
with SCP at approximately $250,000 per well would cost approximately $2 
billion. The costs that are associated with this rulemaking would be 
minor when compared to SCP remediation costs and would 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 SBA will be investigated for appropriate action.

Small Business Regulatory Enforcement Fairness Act

    This proposed rule is not a major rule under 5 U.S.C. 804(2) of the 
Small Business Regulatory Enforcement Fairness Act. This proposed rule:
    a. Would not have an annual effect on the economy of $100 million 
or more.
    b. Would not cause a major increase in costs or prices for 
consumers, individual industries, Federal, State, or local government 
agencies, or geographic regions.
    c. Would 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 proposed rule would not impose an unfunded mandate on State, 
local, or tribal governments or the private sector of more than $100 
million per year. The proposed rule would 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 proposed rule does not have 
significant takings implications. The proposed 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 proposed rule does not have 
federalism implications. This proposed rule would 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 proposed rule would 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:
    (a) 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
    (b) 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 proposed 
rule and determined that it has no substantial effects on federally 
recognized Indian tribes. There are no Indian or tribal lands in the 
OCS.

Paperwork Reduction Act (PRA)

    The proposed rule contains no new reporting or recordkeeping 
requirements, and an Office of Management and Budget (OMB) submission 
under the PRA 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 proposed regulations will replace the references to NTLs 
and LTLs with specific cites to the code of federal regulations. The 
proposed 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

    We have prepared an environmental assessment to determine whether 
this rule will have a significant impact on the quality of the human 
environment under the National Environmental Policy Act of 1969.

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.

Clarity of This Regulation

    We are required by E.O. 12866, E.O. 12988, and by the Presidential 
Memorandum of June 1, 1998, to write all rules in plain language. This 
means that each rule we publish must:
    (a) Be logically organized;
    (b) Use the active voice to address readers directly;
    (c) Use clear language rather than jargon;
    (d) Be divided into short sections and sentences; and
    (e) Use lists and tables wherever possible.
    If you feel that we have not met these requirements, send us 
comments by one of the methods listed in the ADDRESSES section. To 
better help us revise the rule, your comments should be as specific as 
possible. For example, you should tell us the numbers of the sections 
or paragraphs that you find unclear, which sections or sentences are 
too long, the sections where you feel lists or tables would be useful, 
etc.

Public Availability of Comments

    Before including your address, phone number, e-mail address, or 
other personal identifying information in your comment, you should be 
aware that your entire comment--including your personal identifying 
information--may be made publicly available at any time. While you can 
ask us in your comment to withhold your personal identifying 
information from public review, we cannot guarantee that we will be 
able to do so.

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.


[[Page 38151]]


    Dated: July 15, 2009 .
Ned Farquhar,
Acting Assistant Secretary--Land and Minerals Management.

    For the reasons stated in the preamble, the Minerals Management 
Service (MMS) proposes to amend 30 CFR part 250 as follows:

PART 250--OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER 
CONTINENTAL SHELF

    1. The authority citation for part 250 continues to read as 
follows:

    Authority: 31 U.S.C. 9701, 43 U.S.C. 1334.

    2. In Sec.  250.198, add the following document incorporated by 
reference to the table in paragraph (e) in alphanumerical order.


Sec.  250.198  Documents incorporated by reference.

* * * * *
    (e) * * *

------------------------------------------------------------------------
                                                        Incorporated by
                  Title of documents                      reference at
------------------------------------------------------------------------
 
                              * * * * * * *
API RP 90, Annular Casing Pressure Management for         Sec.   250.518
 Offshore Wells, First Edition, August 2006, Product
 No. G09001..........................................
 
                              * * * * * * *
------------------------------------------------------------------------

    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:

------------------------------------------------------------------------
   If you have . . .     you must equip . . .   so you can monitor . . .
------------------------------------------------------------------------
(1) Fixed platform      the wellhead.........  all annuli (A, B, C, D,
 wells,                                         etc., annuli).
(2) Subsea wells,       the tubing head......  the production casing
                                                annulus (A annulus).
(3) Hybrid \1\ 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.
------------------------------------------------------------------------
\1\ Characterized as a well drilled with a subsea wellhead and completed
  with a surface casing head, a surface tubing head, a surface tubing
  hangar, and a surface christmas tree.

* * * * *
    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 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      monthly..............  month for each casing.
 wells,
(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     daily................  day for each casing.
 under a casing
 pressure request,
(e) Wells operating     weekly...............  week for each casing.
 under a casing
 pressure request on
 an unmanned fixed
 platform,
------------------------------------------------------------------------


[[Page 38152]]

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 test if .
  If you have a . . .                          . .
------------------------------------------------------------------------
(1) Fixed platform       the casing pressure is greater than 100 psig.
 well,
(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 approved   immediately.
 term has expired,
(b) Your well, previously on gas lift, has  immediately on the
 been shut-in or returned to flowing         production casing (A
 status for more than 180 days,              annulus). The production
                                             casing (A annulus) of wells
                                             on active gas lift are
                                             exempt from diagnostic
                                             testing.
(c) Your casing pressure request becomes    within 30 days.
 invalid,
(d) A casing or riser has an increase in    within 30 days.
 pressure greater than 200 psig over the
 previous casing diagnostic test,
(e) After any corrective action has been    within 30 days.
 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
 casings (A annulus) has pressure            12 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 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;
    (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     Submit to the    Submittal must
      either:         appropriate:        include:       You must also:
------------------------------------------------------------------------
(a) A notification  District Manager  requirements of   submit an
 of corrective       and copy the      Sec.   250.526.   Application for
 action; or          Regional                            Permit to
                     Supervisor,                         Modify or
                     Field                               Corrective
                     Operations.                         Action Plan
                                                         within 30 days
                                                         of the
                                                         diagnostic
                                                         test.
(b) A casing        Regional          requirements of
 pressure request.   Supervisor,       Sec.   250.527.
                     Field
                     Operations.
------------------------------------------------------------------------


[[Page 38153]]

Sec.  250.526  What must I include in my notification of corrective 
action?

    The following information must be included in the notification of 
corrective action:
    (a) Lessee or Operator name;
    (b) Area name, 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 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 granted 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 become invalid?

    A casing pressure request becomes invalid when:
    (a) The casing or riser pressure increases by 200 psig over the 
granted 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.
    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:

------------------------------------------------------------------------
   If you have . . .     you must equip . . .   so you can monitor . . .
------------------------------------------------------------------------
(i) Fixed platform      the wellhead.........  all annuli (A, B, C, D,
 wells,                                         etc., annuli).
(ii) Subsea wells,      the tubing head......  the production casing
                                                annulus (A annulus).
(iii) Hybrid \1\        the surface wellhead.  all annuli at the surface
 wells,                                         (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.
------------------------------------------------------------------------
\1\ Characterized as a well drilled with a subsea wellhead and completed
  with a surface casing head, a surface tubing head, a surface tubing
  hangar, and a surface christmas tree.

    (2) Follow the casing pressure management requirements in subpart E 
of this part.
* * * * *
[FR Doc. E9-17874 Filed 7-30-09; 8:45 am]
BILLING CODE 4310-MR-P