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. 

[FR Doc. 2010–10325 Filed 5–3–10; 8:45 am] 

BILLING CODE 4910–13–P 

DEPARTMENT OF HOUSING AND 

URBAN DEVELOPMENT 

24 CFR Part 202 

[Docket No. FR 5356–C–03] 

RIN 2502–AI81 

Federal Housing Administration: 

Continuation of FHA Reform— 

Strengthening Risk Management 

Through Responsible FHA-Approved 

Lenders; Correction 

AGENCY: Office of General Counsel, 

HUD. 

ACTION: 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 

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.’’ 

Dated: April 29, 2010. 

Camille E. Acevedo, 

Associate General Counsel for Legislation and 

Regulations. 

[FR Doc. 2010–10424 Filed 5–3–10; 8:45 am] 

BILLING CODE 4210–67–P 

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 

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Federal Register / Vol. 75, No. 85 / Tuesday, May 4, 2010 / Rules and Regulations 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 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. 

(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: 

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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 http://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, ................... 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 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. 

* * * * * 

■ 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: 

* * * * * 

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? 

§ 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 

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subpart, you must follow the 

requirements of this subpart. 

§ 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: 

If you have * * * you must monitor * * * with a minimum one 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 casing 

pressure request on a manned 

fixed platform, 

daily, .............................................. day for each casing. 

(e) wells operating under a casing 

pressure request on an unmanned fixed platform, 

weekly, ........................................... week for each casing. 

§ 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: 

If you have a * * * you must perform a casing diagnostic 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. 

§ 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, ................ immediately. 

(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 on the production casing (A annulus). The production casing (A annulus) of wells on active gas lift are exempt from diagnostic 

testing. 

(c) your casing pressure request becomes invalid, ................................. within 30 days. 

(d) a casing or riser has an increase in pressure greater than 200 psig 

over the previous casing diagnostic test, 

within 30 days. 

(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, 

within 30 days. 

(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, 

once per year, not to exceed 12 months between tests. 

(g) your fixed platform well’s outer casing (B, C, D, etc., annuli) has a 

pressure exceeding 20 percent of its MIYP, 

once every 5 years, at a minimum. 

§ 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. 

§ 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 

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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. 

§ 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, .................... the wellhead, ................................. all annuli (A, B, C, D, etc., annuli). 

(ii) subsea wells, ............................. the tubing head, ............................. the production casing annulus (A annulus). 

WReier-Aviles on DSKGBLS3C1PROD with RULES

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 

AGENCY: Coast Guard, DHS. 

ACTION: Notice of enforcement of 

regulation. 

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. 

SUPPLEMENTARY INFORMATION: 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 

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 

DEPARTMENT OF HOMELAND 

SECURITY 

Coast Guard 

33 CFR Part 100 

[Docket No. USCG–2010–0345] 

Seattle Seafair Unlimited Hydroplane 

Race 

AGENCY: Coast Guard, DHS. 

ACTION: Notice of enforcement of 

regulation. 

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: 

WReier-Aviles on DSKGBLS3C1PROD with RULES